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Home My WebLink About20202282.tiff COLORADO ye, Department of Public Health&Environment Weld County - Clerk to the Board RECEIVED 1150 0 St PO Box 758 JUN 19 2020 Greeley, Co 80632 WELD COUNTY June 15, 2020 COMMISSIONERS Dear Sir or Madam: On June 16, 2020, the Air Pollution Control Division will begin a 30-day public notice period for DCP Operating Company, LP - Greeley Natural Gas Processing Plant. 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: Public Notice Coordinator Enclosure ilk <.0Cr /-\ 4300 Cherry Creek Drive S., Denver, CO 80246 1530 P 303-692-2000 www.colorado.gov/cdphe ,r Jared Polls,Governor I Jill Hunsaker Ryan,MPH, Executive Director CC;PL(TP),I-IL(QS)�PW(SK/ER/CH/GK� 2020-2282 Publ :c Rev:ew o603M) O7/.27/9..o 07/22./2.0 CN..r.1.1. Air Pollution Control Division �/ otice Of A Proposed Renewal Title V Operating Permit CDPHE Warranting Public Comment Website Title: DCP Operating Company, LP - Greeley Natural Gas Processing Plant - Weld County Notice Period Begins: June 16, 2020 NOTICE is hereby given that an application to renew an Operating Permit has been submitted to the Colorado Air Pollution Control Division, 4300 Cherry Creek Drive South, Denver, Colorado 80246-1530, for the following source of air pollution: Applicant: DCP Operating Company, LP 370 17th Street Suite 2500 Denver, CO 80202 Facility: Greeley Natural Gas Processing Plant 3009 49th Street Greeley, CO 80634 DCP Operating Company, LP has applied to renew the Operating Permit for the Greeley Natural Gas Processing Plant in Weld County, CO. This facility is a natural gas processing plant. The operating permit renewal for this facility includes the following changes for all points: modify permit limitations, emission factors and calculation methods to reflect the facility's current mode of operation, as requested in the renewal application, two minor modification applications and two significant modification applications, incorporate the applicable requirements of Colorado Construction Permit 15WE0939, update monitoring requirements to be consistent with recently issued permits and include the most recent version of applicable federal and state regulations. This operating permit renewal incorporates equipment previously permitted under Colorado Construction Permit 15WE0939, which includes the EG dehydration unit and plant flare. Emission limitations for these two units were not modified with the operating permit renewal. Emission limitations were decreased from the previous operating permit issuance for the engines and fugitive emissions points, as requested in the minor and significant modification applications submitted for this facility. A facility-wide HAP limit was introduced to ensure major source requirements are not triggered under federal rules. A copy of the application, including supplemental information, the Division's analysis, and a draft of the Renewal Operating Permit 95OPWE038 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 has made a preliminary determination of approval of the application. Based on the information submitted by the applicant, the Division has prepared the draft renewal operating permit for approval. Any interested person may contact Elie Chavez of the Division at 303-692-6332 to obtain additional information. Any interested person may submit written comments to the Division concerning 1) the sufficiency of the preliminary analysis, 2) whether the permit application should be approved or denied, 3) the ability of the proposed activity to comply with applicable requirements, 4) the air quality impacts of, alternatives to, and control technology required on the source or modification, and 5) any other appropriate air quality considerations. Any interested person may submit a written request to the Division for a public comment hearing before the Colorado Air Quality Control Commission (Commission) to receive comments regarding the concerns listed above as well as the sufficiency of the preliminary analysis and whether the Division should approve or deny the permit application. If requested, the hearing will be held before the Commission within 60 days of its fel, COLORADO Department of Public 1 I > Health 6 Environment receipt of the request for a hearing unless a longer time period is agreed upon by the Division and the applicant. The hearing request must: 1) identify the individual or group requesting the hearing, 2) state his or her address and phone number, and 3) state the reason(s) for the request, the manner in which the person is affected by the proceedings, and an explanation of why the person's interests are not already adequately represented. The Division will receive and consider the written public comments and requests for any hearing for thirty calendar days after the date of this Notice. Comments may be submitted using the following options: • Use the web form at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices. This page also includes guidance for public participation • Send an email to cdphe.commentsapcd@state.co.us • Send comments to our mailing address: Elie Chavez Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 Hearing requests may be submitted to the email address or the mailing address noted above. COLORA Department of Public 2 I °P E DHealth 6 Environment . O� ' Cpl ® 04,1. _=a ::* -4 'cc; * A * SINE Nlw '� 1 6 let87 Colorado Department of Public Health and Environment OPERATING PERMIT DCP Operating Company, LP Greeley Natural Gas Processing Plant First Issued: May 1 , 1999 Renewed: DRAFT AIR POLLUTION CONTROL DIVISION COLORADO OPERATING PERMIT FACILITY NAME: DCP Operating OPERATING PERMIT NUMBER Company, LP— Greeley Natural Gas Processing Plant FACILITY ID: 123/0099 95OPWE038 ISSUED: DRAFT EXPIRATION DATE: DRAFT MODIFICATIONS: See Appendix F of Permit Issued in accordance with the provisions of the Colorado Air Pollution Prevention and Control Act, 25-7-101 et sec. and applicable rules and regulations. ISSUED TO: PLANT SITE LOCATION: DCP Operating Company, LP DCP Operating Company, LP Greeley Natural Gas Processing Plant 370 17th Street 3009 49th Street Suite 2500 Weld County Denver, CO 80202 Greeley, CO 80634 INFORMATION RELIED UPON Operating Permit Renewal Application Received: May 1, 2013 And Additional Information Received: May 2, 2016; December 21, 2018; December 20, 2019; April 27, 2020 Nature of Business: Natural Gas Liquids Processing and Gathering Primary SIC: 1321 RESPONSIBLE OFFICIAL FACILITY CONTACT PERSON Name: Charles A. Job Name: Roshini Shankaran Title: General Manager, North Area Title: Senior Environmental Engineer Operations Phone: (303) 605-1964 Phone: (303) 605-2039 SUBMITTAL DEADLINES First Semi-Annual Monitoring Period: DRAFT Subsequent Semi-Annual Monitoring Periods: DRAFT Semi-Annual Monitoring Reports: DRAFT First Annual Compliance Period: DRAFT Subsequent Annual Compliance Periods: DRAFT Annual Compliance Certification: DRAFT Note that the Semi-Annual Monitoring Reports and Annual Compliance report must be received at the Division office by 5:00 p.m.on the due date.Postmarked dates will not be accepted for the purposes of determining the timely receipt of those reports. Table of Contents: SECTION I - General Activities and Summary 1 1. Permitted Activities 1 2. Alternative Operating Scenarios 3 2. Non-Attainment New Source Review (NANSR) and Prevention of Significant Deterioration (PSD) 11 3. Accidental Release Program (112(r)) 12 4. Compliance Assurance Monitoring(CAM) 12 5. Summary of Emission Units 13 SECTION II - Specific Permit Terms 15 1. C-116/C-117/C-118/C-119/C-120/C-152/C-122 —Waukesha L-7042 GSI 1,100 hp Compressor Engines,AIRS ID: 103/104/105/106/107/109/110 15 C-123 —Waukesha L-7042 GU 896 hp Compressor Engine, AIRS ID: 108 15 2. C-124—Waukesha F-11G 125 hp Compressor Engine , AIRS ID: 102 31 3. P-139-G.C. Broach Natural Gas Fired 35.1 MMBtu/hr Hot Oil Heater, AIRS ID: 120 43 4. P-132—Born Natural Gas Fired 15.0 MMBtu/hr Hot Oil Heater, AIRS ID: 113 52 5. P-133 — Fugitive Emissions from Fractionation and Natural Gas Liquids (NGL) Processing Plants, AIRS ID: 114 61 6. P-135 —Pressurized Product Truck Loadout Rack, AIRS ID: 115 67 7. P-130—Ethylene Glycol Dehydration Unit, AIRS ID: 111 71 8. FLARE—Plant Flare, AIRS ID: 122 86 9. Exempt Non-Emergency Natural Gas Fired Engines 95 10. Exempt Emergency Natural Gas Fired Engine 101 11. Facility-Wide Hazardous Air Pollutant(HAP) Emission Limitations 108 12. Facility-Wide General Requirements 111 13. Compliance Assurance Monitoring(ver 4/16/2009) 117 14. Portable Monitoring (ver. 6/26/2014) 123 SECTION III - Permit Shield 124 1. Specific Non-Applicable Requirements 124 2. General Conditions 125 3. Streamlined Conditions 125 Section IV - General Permit Conditions (ver. 1/21/2020) 126 1. Administrative Changes 126 2. Certification Requirements 126 3. Common Provisions 126 4. Compliance Requirements 130 5. Emergency Provisions 131 6. Emission Controls for Asbestos 132 7. Emissions Trading, Marketable Permits, Economic Incentives 132 8. Fee Payment 132 9. Fugitive Particulate Emissions 132 Table of Contents: 10. Inspection and Entry 133 11. Minor Permit Modifications 133 12. New Source Review 133 13. No Property Rights Conveyed 133 14. Odor 133 15. Off-Permit Changes to the Source 133 16. Opacity 134 17. Open Burning 134 18. Ozone Depleting Compounds 134 19. Permit Expiration and Renewal 134 20. Portable Sources 134 21. Prompt Deviation Reporting 134 22. Record Keeping and Reporting Requirements 135 23. Reopenings for Cause 136 24. Requirements for Major Stationary Sources 137 25. Section 502(b)(10) Changes 138 26. Severability Clause 138 27. Significant Permit Modifications 138 28. Special Provisions Concerning the Acid Rain Program 138 29. Transfer or Assignment of Ownership 139 30. Volatile Organic Compounds 139 31. Wood Stoves and Wood burning Appliances 140 APPENDIX A - Inspection Information 142 1. Directions to Plant: 142 2. Safety Equipment Require& 142 3. Facility Plot Plan: 142 4. List of Insignificant Activities: 142 APPENDIX B - Reporting Requirements and Definitions 145 APPENDIX C Required Format for Annual Compliance Certification Report(ver 8/20/2014) 156 APPENDIX D Notification Addresses 160 APPENDIX E Permit Acronyms 161 APPENDIX F Permit Modifications 163 APPENDIX G - Compliance Assurance Monitoring Plan 164 APPENDIX H—Applicability Reports 168 Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 1 SECTION I- General Activities and Summary 1. Permitted Activities 1.1 The Greeley Natural Gas Processing Plant, classified as a natural gas processing plant as set forth under Standard Industrial Classification 1321, is designed to extract natural gas liquids from field produced natural gas and recompress the processed gas prior to transmission to a sales pipeline. Field gas is first piped to a separator where liquids formed during transport to the plant are separated from the gas stream. The gas stream discharged from the separator is processed through an ethylene glycol dehydration unit (AIRS 111), where moisture contained in the gas stream is absorbed by ethylene glycol. The moisture laden glycol discharged from the contactor is regenerated in a reboiler. The glycol solution is then re- circulated to the contactor. Emissions from the dehydration unit still vent are routed to an enclosed combustor. Emissions from the dehydration unit flash tank are routed to a vapor recovery unit (VRU, AIRS 102) and routed back to the plant inlet. During periods of VRU downtime, flash tank emissions are routed to the enclosed combustor. After the moisture in the gas has been removed by the contactor, the gas stream is piped to the processing plant where it is chilled by a refrigeration system coupled with the Joule-Thompson process to create a natural gas liquid (NGL) product and a residue gas stream. A fractionation assembly separates the NGL product into ethane,propane,butane, isopentane and other NGL streams that are stored in separate pressurized bullet tanks and transported offsite by truck. The residue gas is recompressed by eight (8) compressors, powered by natural gas fired internal combustion engines (AIRS 103, 104, 105, 106, 107, 108, 109, 110) and is then routed to a sales gas pipeline. The facility operation also requires two natural gas fired hot oil heaters (AIRS 113, 120), a pressurized truck loadout rack for condensate, a pressurized NGL truck loadout rack (AIRS 115) and various pressurized storage tanks for the NGL and condensate products. The plant flare (AIRS 122) serves as a control device for facility and equipment blowdowns,as well as maintenance,malfunction, startup and shutdown emissions. Fugitive equipment leaks (AIRS 114) are also permitted at this facility. Emission control devices include: nine (9) NSCR beds to control compressor engine exhaust emissions, one (1) vapor recovery unit (VRU) permitted 5% downtime, to control the flash tank emissions from the dehydration unit, one (1) enclosed combustion device (ECD) permitted 5% downtime, to control the still vent emissions from the dehydration unit, as well as flash tank emissions during periods of VRU downtime, and one (1) plant flare,to control facility-wide process emissions. The address of the Greeley Natural Gas Processing Plant is 3009 49th Street, Greeley (SE'/4 & SW'/4 of SW'/4 of Section 25, T5N, R66W). The plant is located at the southern edge of Greeley near Highway 85. This facility is located in an Area classified as attainment/maintenance for carbon monoxide (CO). Under that classification, all SIP-approved requirements for CO will continue to apply in order to prevent backsliding under the provisions of Section 110(1) of the Federal Clean Air Act. This Area is classified as non-attainment for the 8-hr ozone standard and is part of the 8-hr Ozone Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 2 Control Area as defined in Regulation No. 7, Part A, Section II.A.1. The 8-hr Ozone Control Area has been classified as a serious non-attainment area effective January 27, 2020. Wyoming is an affected state within 50 miles of the plant. Rocky Mountain National Park and Rawah Wilderness are Federal Class I designated areas within 100 kilometers of the plant. 1.2 Until such time as this permit expires or is modified or revoked, the permittee is allowed to discharge air pollutants from this plant in accordance with the requirements, limitations, and conditions of this permit. 1.3 This Operating Permit incorporates the applicable requirements contained in the underlying construction permits, and does not affect those applicable requirements, except as modified during review of the application or as modified subsequent to permit issuance using the modification procedures found in Regulation No. 3, Part C. These Part C procedures meet all applicable substantive New Source Review requirements for purposes of this Operating Permit and shall survive reissuance. This Operating Permit incorporates the applicable requirements (except as noted in Section II) from the following Colorado Construction Permit(s): 85WE304 85WE337-1 85WE337-2 85WE337-3 85WE337-4 87WE235-1 87WE237 87WE190 90WE048-2 90WE514-1 90WE514-2 96WE289 15WE0939 1.4 All conditions in this permit are enforceable by the US Environmental Protection Agency, Colorado Air Pollution Control Division (hereinafter Division) and its agents, and citizens unless otherwise specified. State-only enforceable conditions are: Section II—Condition 1.10.1.2a(Colorado Regulation No. 7, Part E, Section I.D.2.) Section II—Conditions 3.6.3 and 4.6.3 (Colorado Regulation No. 6, Part B, Section II.C.3.) Section II—Condition 4.8 (Colorado Regulation No. 6, Part A, Subpart A) Section II—Condition 7.10.2 (Colorado Regulation No. 7, Part D, Section II.D.) Section II—Condition 12.4 (Colorado Regulation No. 7, Part D, Section II.B.) Section II—Condition 12.5 (Colorado Regulation No. 7, Part D, Section V.) Section IV—Condition 3.g(Colorado Common Provisions Regulation, Affirmative Defense) Section IV—Condition 14 (Colorado Regulation No. 2, as noted) Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 3 Section IV—Condition 18 (Colorado Regulation No. 15, as noted) Section IV—Condition 30 (Colorado Regulation No. 7, Part B, Sections I and III, as noted) 1.5 All information gathered pursuant to the requirements of this permit is subject to the Record keeping and Reporting requirements listed under Condition 22 of the General Conditions in Section IV of this permit. 2. Alternative Operating Scenarios 2.1 Glycol Circulation Pump Alternative Operating Scenarios The glycol circulation pumps for EG dehydration unit P-130 may be replaced in accordance with the alternative operating scenario provisions set forth in Section II, Condition 7.9. The facility must, contemporaneously with making a change from one operating scenario to another,maintain records at the facility of the scenario under which it is operating (Colorado Regulation No. 3, Part A, Section IV.A.1). Electronic or hard copy records are acceptable. 2.2 Natural Gas Fired Engine Alternative Operating Scenarios (ver 10/12/2012) (updated to reflect changes to Colorado Regulation No.7,NSPS,and MACT rules) 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 permittee shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.2.1 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 Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 4 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), and shall be subject to any shield afforded by this permit. 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 permittee 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, date of manufacture, model number, horsepower, and serial number of the replacement engine. In addition to the log, the permittee shall maintain a copy of all Applicability Reports required under Section 2.2.1.2 and make them available to the Division upon request. 2.2.1.1 The permittee 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 2.2.2. The permittee may temporarily replace a grandfathered or permit exempt engine or an engine that is not subject to emission limits without modifying this permit. In this circumstance, potential annual emissions of NOx and CO from the temporary replacement engine must be less than or equal to the potential annual emissions of NOx and CO from the original grandfathered or permit exempt engine or for the engine that is not subject to emission limits, as determined by applying appropriate emission factors (e.g. AP-42 or manufacturer's emission factors). 2.2.1.2 The permittee may permanently replace the existing compressor engine for the emission points specified in Table 1 with the manufacturer, model, and Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 5 horsepower engines listed in Table 1 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 2.2.2. The AOS cannot be used for the permanent replacement of an entire engine at any source that is currently a major stationary source for purposes of Prevention of Significant Deterioration or Non-Attainment Area New Source Review ("PSD/NANSR")unless the existing engine has emission limits that are below the significance levels in Reg 3, Part D, II.A.44. 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 permittee 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 in Appendix H. 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 permittee 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. Nothing in this AOS shall preclude the Division from taking an action, based on any permanent engine replacement(s), for circumvention of any state or federal PSD/NANSR requirement. Additionally, in the event that any permanent engine replacement(s) constitute(s) a circumvention of applicable PSD/NANSR requirements,nothing in this AOS shall excuse the permittee from complying with PSD/NANSR and applicable permitting requirements. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 6 2.2.2 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 permittee 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 permittee 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: https://www.colorado.gov/pacific/cdphe/portable-analyzer-monitoring-protocol. 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. For comparison with a short-term limit that is either input based (Ib/mmBtu), output based (g/hp-hr)or concentration based(ppmvd @ 15%O2)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. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 7 If the portable analyzer results indicate compliance with both the NO, 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 NO,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 NO, 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 NO,and CO emission limitations or until the engine is taken offline. 2.2.3 Applicable Regulations for Permanent Engine Replacements 2.2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § III.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 NO, 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 PMio attainment/maintenance area, RACT applies to PMio at any level of emissions and to NO,and SO2,as precursors to PMio, if the potential to emit of NO,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 SO2: Use of natural gas as fuel PMio: 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. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 8 2.2.3.2 Control Requirements and Emission Standards: Regulation No. 7,Part E, Sections I.B. and I.D (State-Only conditions). Control Requirements: Part E, Section I.B 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, Part E, section I.B, 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. 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 2.2.1.2. Emission Standards: Part E, Section ID—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: Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 9 Max Engine HP Construction or Emission Standards in G/hp-hr Relocation Date NOx CO VOC 100<Hp<500 January 1, 2008 2.0 4.0 1.0 January 1, 2011 1.0 2.0 0.7 500<Hp July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.2.1.2. 2.2.3.3 NSPS for spark ignition internal combustion engines: 40 CFR 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 2.2.1.2. 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 2.2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2.2. Note that under the provisions of Regulation No. 6, Part B, Section I.C., upon adoption of NSPS JJJJ into Regulation No.6,Part A an internal combustion engine relocated from outside of the State of Colorado into the State of Colorado shall meet the most recent emission standard required in NSPS JJJJ. Engines with a manufacturer's rated horsepower of less than 500 and with a relocation date no later than 5 years after the manufacture date are exempt from this requirement per Regulation No. 6, Part B, Section I.C.2.a. Relocation is defined in Section I.C.1.a. However, as of January 9, 2017 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 Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 10 law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. 2.2.3.4 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 requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.2.1.2.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 2.2.2, if approved in advance by the Division,provided that such test is conducted within the time frame specified in Condition 2.2.2. 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. Table 1 Internal Combustion Engine Information For AOS Emission Replacement Engine Periodic Subject to Point Monitoring CAM? C-124 Waukesha Model F-11G, 125 hp,standard rich burn,natural gas Portable Monitoring No fired engine w/AFR&NSCR Quarterly C-116 Waukesha Model L-7042 GSI, 1,100 hp, standard rich burn, Portable Monitoring Yes turbocharged,natural gas fired engine w/AFR&NSCR Quarterly C-117 Waukesha Model L-7042 GSI, 1,100 hp, standard rich burn, Portable Monitoring Yes turbocharged,natural gas fired engine w/AFR&NSCR Quarterly Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 11 Emission Replacement Engine Periodic Subject to Point Monitoring CAM? C-118 Waukesha Model L-7042 GSI, 1,100 hp, standard rich burn, Portable Monitoring Yes turbocharged,natural gas fired engine w/AFR&NSCR Quarterly C-119 Waukesha Model L-7042 GSI, 1,100 hp, standard rich burn, Portable Monitoring Yes turbocharged,natural gas fired engine w/AFR&NSCR Quarterly C-120 Waukesha Model L-7042 GSI, 1,100 hp, standard rich burn, Portable Monitoring Yes turbocharged,natural gas fired engine w/AFR&NSCR Quarterly C-123 Waukesha Model L-7042 GU,896 hp,standard rich burn,natural Portable Monitoring Yes gas fired engine w/AFR&NSCR Quarterly C-152 Waukesha Model L-7042 GSI, 1,100 hp, standard rich burn, Portable Monitoring Yes turbocharged,natural gas fired engine w/AFR&NSCR Quarterly C-122 Waukesha Model L-7042 GSI, 1,100 hp, standard rich burn, Portable Monitoring Yes turbocharged,natural gas fired engine w/AFR&NSCR Quarterly 2. Non-Attainment New Source Review (NANSR) and Prevention of Significant Deterioration (PSD) 3.1 This facility is categorized as a NANSR major stationary source (Potential to Emit of VOC or NOx≥ 50 Tons/Year). Future modifications at this facility resulting in a significant net emissions increase (see Reg 3, Part D, Sections II.A.27 and 44) for VOC or NOx or a modification which is major by itself(i.e. a Potential to Emit of ≥50 TPY of either VOC or NOx)may result in the application of the NANSR review requirements. Based on the information provided by the applicant,this source is categorized as a.minor stationary source for PSD as of the issue date of this permit. Any future modification which is major by itself(Potential to Emit of> 250 TPY) for any pollutant listed in Regulation No. 3, Part D, Section II.A.44 for which the area is in attainment or attainment/maintenance may result in the application of the PSD review requirements. 3.2 There are no other Operating Permits associated with this plant for the purposes of determining the applicability of the PSD regulations. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 12 3. Accidental Release Program (112(r)) 4.1 Based on the information provided by the applicant, the Greeley Natural Gas Processing Plant is subject to the provisions of the Accidental Release Prevention Program (Section 112(r) of the Federal Clean Air Act). 4.2 The Risk Management Plan required by the Act was submitted to the appropriate authority and/or a designated central location by June 20, 1999. 4. Compliance Assurance Monitoring (CAM) 5.1 The following emission points at this facility use a control device to achieve compliance with an emission limitation or standard to which they are subject and have pre-control emissions that exceed or are equivalent to the major source threshold. They are therefore subject to the provisions of the CAM program as set forth in 40 CFR Part 64, as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV: AIRS ID 103 (C-116)—Compressor RICE (1,100 hp) for NOx AIRS ID 104 (C-117)—Compressor RICE (1,100 hp) for NOx AIRS ID 105 (C-118)—Compressor RICE (1,100 hp) for NOx AIRS ID 106 (C-119)—Compressor RICE (1,100 hp) for NOx AIRS ID 107 (C-120)—Compressor RICE(1,100 hp) for NOx AIRS ID 108 (C-123)—Compressor RICE (896 hp) for NOx AIRS ID 109 (C-152)—Compressor RICE (1,100 hp) for NOx AIRS ID 110 (C-122)—Compressor RICE (1,100 hp) for NOx See Section II, Condition 13 for compliance assurance monitoring requirements. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 13 5. Summary of Emission Units The emissions units regulated by this permit are the following: AIRS Plant Pollution Control Construction Stack Identifier Description Permit Number Device Waukesha Model F-11G Natural Gas Fired Internal Combustion Engine, 4-Cycle, Rich Burn w/ Air/Fuel Ratio Controller, Site Non-Selective Catalytic Reduction/ 102 C-124 Rated at 125 hp,Serial No. 5367457,Drive for Vapor Recovery 85WE304 AFR Controller Unit Compressor Waukesha Model L-7042 GSI Turbocharged Natural Gas Fired Internal Combustion Engine, 4-Cycle, Rich Burn w/ Air/Fuel Non-Selective Catalytic Reduction/ 103 C-116 Ratio Controller,Site Rated at 1,100 hp,Serial No.398468,Drive 85WE337-1 AFR Controller for Refrigeration Compressor Waukesha Model L-7042 GSI Turbocharged Natural Gas Fired Internal Combustion Engine, 4-Cycle, Rich Burn w/ Air/Fuel Non-Selective Catalytic Reduction/ 104 C-117 85WE337-2 Ratio Controller,Site Rated at 1,100 hp,Serial No.337569,Drive AFR Controller for Inlet/Residue Natural Gas Compressor Waukesha Model L-7042 GSI Turbocharged Natural Gas Fired Internal Combustion Engine, 4-Cycle, Rich Burn w/ Air/Fuel Non-Selective Catalytic Reduction/ 105 C-118 Ratio Controller,Site Rated at 1,100 hp,Serial No.286434,Drive 85WE337-3 AFR Controller for Inlet/Residue Natural Gas Compressor Waukesha Model L-7042 GSI Turbocharged Natural Gas Fired Internal Combustion Engine, 4-Cycle, Rich Burn w/ Air/Fuel Non-Selective Catalytic Reduction/ 106 C-119 85WE337-4 Ratio Controller,Site Rated at 1,100 hp,Serial No.261947,Drive AFR Controller for Inlet/Residue Natural Gas Compressor Waukesha Model L-7042 GSI Turbocharged Natural Gas Fired Non-Selective Catalytic Reduction/ 107 C-120 Internal Combustion Engine, 4-Cycle, Rich Burn w/ Air/Fuel 87WE235 1 Ratio Controller,Site Rated at 1,100 hp,Serial No.388531,Drive AFR Controller for Inlet/Residue/Ethane Natural Gas Compressor Waukesha Model L-7042 GU Natural Gas Fired Internal Combustion Engine, 4-Cycle, Rich Burn w/ Air/Fuel Ratio Non-Selective Catalytic Reduction/ 108 C-123 Controller, Site Rated at 896 hp, Serial No. 336485, Drive for 87WE237 AFR Controller Refrigeration Compressor Waukesha Model L-7042 GSI Turbocharged Natural Gas Fired Internal Combustion Engine, 4-Cycle, Rich Burn w/ Air/Fuel Non-Selective Catalytic Reduction/ 109 C-152 87WE190 Ratio Controller,Site Rated at 1,100 hp,Serial No.327603,Drive AFR Controller for Inlet/Residue Natural Gas Compressor Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 14 Waukesha Model L-7042 GSI Turbocharged Natural Gas Fired Non-Selective Catalytic Reduction/ Internal Combustion Engine, 4-Cycle, Rich Burn w/ Air/Fuel 110 C-122 96WE289 Ratio Controller,Site Rated at 1,100 hp,Serial No.260928,Drive AFR Controller for Inlet/Residue/Ethane Natural Gas Compressor Custom Ethylene Glycol Dehydration Unit, Rated at 33 Flash Tank:VRU(100%CE;5%DT) 111 P-130 MMSCFD,equipped with a flash tank,cold separator,still vent ECD(95%CE;backup) 15WE0939 and two (2) Kerr Model KZ-3150 electric glycol circulation pumps rated at 6 gallons/minute each Still Vent:ECD(95%CE;5%DT) 113 P-132 Born, Inc. Hot Oil Heater, Natural Gas Fired, Rated at 15 Uncontrolled 90WE514-2 MMBtu/hr,Serial No.2278 114 P-133 Fugitive Emissions from Fractionation and Natural Gas Liquids Uncontrolled 90WE514-1 (NGL)Processing Plants Pressurized Product Truck Loadout Rack for Propane,Butane,B- 115 P-135 G Mix,Y-Grade,Isopentane,NGL and Condensate,557,180,000 Uncontrolled 90WE048-2 gallons/year throughput 120 P-139 G.C.Broach Company Hot Oil Heater,Natural Gas Fired,Rated Uncontrolled None at 35.1 MMBtu/hr John Zink Hamworthy Combustion EEF Series Plant Open Flare 122 FLARE to control emissions from maintenance and blowdown events, N/A 15WE0939 Serial No.9027692 Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 15 SECTION II - Specific Permit Terms 1. C-116/C-117/C-118/C-119/C-120/C-152/C-122 —Waukesha L-7042 GSI 1,100 hp Compressor Engines,AIRS ID: 103/104/105/106/107/109/110 C-123—Waukesha L-7042 GU 896 hp Compressor Engine,AIRS ID: 108 Permit Compliance Limits Compliance Monitoring Parameter Condition Number Annual Emission Factor Method Interval Emission&Consumption Limits' C-116,C-117,C-118,C-120&C-122—Waukesha L-7042 GSI 1,100 hp Natural Gas Fired Internal Combustion Engines NOx 24.00 tons/year 0.586 lb/MMBtu Recordkeeping and — 1.1 Twelve Month CO 26.55 tons/year 0.649 lb/MMBtu Rolling Total Calculation Monthly VOC 1.2 5.31 tons/year 0.130 lb/MMBtu Natural Gas 1.3 Fuel Meter,Twelve Consumption 78.7 MMSCF/year Month Rolling Total Emission&Consumption Limits' C-119&C-152—Waukesha L-7042 GSI 1,100 hp Natural Gas Fired Internal Combustion Engines NOx 21.24 tons/year 0.519 lb/MMBtu 1.1 Recordkeeping and CO 26.55 tons/year 0.649 lb/MMBtu Twelve Month Rolling Total VOC 1.2 5.31 tons/year 0.130 lb/MMBtu Calculation Monthly Natural Gas 1.3 78.7 MMSCF/year Fuel Meter,Twelve Consumption Month Rolling Total Emission&Consumption Limits C-123—Waukesha L-7042 GU 896 hp Natural Gas Fired Internal Combustion Engine NOx 8.65 tons/year 0.259 lb/MMBtu 1.1 Recordkeeping and CO 17.30 tons/year 0.518 lb/MMBtu Twelve Month Rolling Total VOC 1.2 4.33 tons/year 0.130 lb/MMBtu Calculation Monthly Natural Gas 1.3 Fuel Meter,Twelve Consumption 64.2 MMSCF/year Month Rolling Total Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company,LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 16 Permit Compliance Limits Monitoring Parameter Condition Compliance Number Annual Emission Factor Method Interval Other Requirements' ASTM or other Natural Gas Heat Semi- 1.4 Division Approved ContentMethod Annually Hours of Operation 1.5 Recordkeeping Monthly Not to exceed 20%,except as provided for below: Opacity 1.6 For Certain Operational Activities-Not to Fuel Restriction Natural Gas exceed 30%for a period or periods Only aggregating more than six(6)minutes in any sixty(60)consecutive minutes Control Device 1.7 See Condition 1.7 Requirements Portable Monitoring 1.8 Flue Gas Analyzer Quarterly Compliance Assurance 1.9 See Condition 1.9 Monitoring(CAM) Statewide Controls for Oil and Gas 1.10 See Condition 1.10 Operations 40 CFR 63 Subpart 1.11 See Condition 1.11 ZZZZ MACT 40 CFR 63 Subpart A General 1.12 See Condition 1.12 Provisions MACT 'Emission&Consumption Limits and Other Requirements apply to each engine individually unless otherwise specified. 1.1 NOx & CO Emission Limitations & Compliance Monitoring Emissions of Nitrogen Oxides (NOx) and Carbon Monoxide(CO) from each engine shall not exceed the limitations listed in Summary Table 1 above (Colorado Construction Permits 85WE337-1, 85WE337-2, 85WE337-3, 85WE337-4, 87WE235-1, 87WE190, 87WE237 and 96WE289, as modified under the Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 17 provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7 based on requested emissions identified on the APEN submitted on 12/20/2019 for engines C-116, C-117, C-118, C-120 and C-122 only, and Colorado Regulation No. 3, Part B, Section II.A.6 and Part C, Section X based on requested emissions identified on the APEN submitted on 12/21/2018 for C- 123 only). Except as provided for below, the emission factors listed above have been approved by the Division and shall be used to calculate emissions from these engines, as follows: 1.1.1 Monthly determination of NOx and CO emissions shall be conducted by the end of the subsequent month using the emission factors listed in Summary Table 1 above, the monthly natural gas consumption, as required by Condition 1.3 and the heat content of the natural gas obtained from the most recent analysis, as required by Condition 1.4, in the equation below: lb ) MMBT Ul MMSCF) tons l Emission Factor (MMBTU)x Heat Content (MMSCF)x Fuel Use (month J NO,or CO Emissions (month) (2000 lb) Unit Conversion ton ) Monthly emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data.Records of calculations shall be maintained and made available to the Division upon request. 1.1.2 Portable monitoring shall be conducted quarterly as required by Condition 1.8. If the results of the portable analyzer testing conducted under the provisions of Condition 1.8 show that either the NOx or CO emission rates/factors are greater than those listed above, and in the absence of subsequent testing results to the contrary (as approved by the Division), the permittee shall apply for a modification to this permit to reflect, at a minimum, the higher emission rates/factors within 60 days of the completion of the test. 1.2 VOC Emission Limitations & Compliance Monitoring Emissions of Volatile Organic Compounds(VOC)from each engine shall not exceed the limitations listed in Summary Table 1 above (Colorado Construction Permits 85WE337-1, 85WE337-2, 85WE337-3, 85WE337-4, 87WE235-1, 87WE190, 87WE237 and 96WE289, as modified under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part B, Section II.A.6 and Part C, Section X based on requested emissions identified on the APEN submitted on 12/21/2018 for C-123 only). Compliance with the annual limitation shall be monitored as follows: 1.2.1 Monthly determination of VOC emissions shall be conducted by the end of the subsequent month using the emission factors listed in Summary Table 1 above, the monthly natural gas Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 18 consumption, as required by Condition 1.3, and the heat content of the natural gas obtained from the most recent analysis, as required by Condition 1.4, in the equation below: lb MMBtu MMSCF tons ) Emission Factor (MMBtu)x Heat Content (MMSCF x Fuel Use (month VOC Emissions (month) 2000 1b) Unit Conversion ( ton I Monthly emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data.Records of calculations shall be maintained and made available to the Division upon request. 1.2.2 Facility-wide emissions of Hazardous Air Pollutants (HAP) shall not exceed the annual facility-wide limitations set forth in Condition 11 (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). Monthly emissions of each HAP from each engine shall be calculated by the end of the subsequent month using the methods set forth in Condition 11 and used in a twelve month rolling total to monitor compliance with the facility-wide HAP emission limitations. 1.3 Natural Gas Consumption Limitations & Compliance Monitoring Natural gas consumption for each engine shall not exceed the limitations listed in Summary Table 1 above (Colorado Construction Permits 85WE337-1, 85WE337-2, 85WE337-3, 85WE337-4, 87WE235-1, 87WE190, 87WE237 and 96WE289, as modified under the provisions of Section I, Condition 1.3). Facility-wide natural gas consumption shall be recorded on the first day of each month using the facility fuel meter. Allocation of natural gas to each engine shall be determined using the following equation: Btu l MMSCF HR Engine(month) (MMSCF) FCEngine month Btu Btu Btu FCFaciiity month/ z HREngine(month) (+ HRHeater(month)+ HROther( x month Where: Btu ) Btu lhr l HREngine (month) = BSFC (hp•hr)x Hours of Operation (month)x Site Rated hp(hp) Btu l Btu hr ) = Design Heat Rating (hr)x Hours o f Operation (month) HRHeater (month Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 19 And: FCEngine =Individual Engine Fuel Consumption,MMSCF/Month HREngine =Individual Engine Heat Requirement,Btu/Month HR Heater=Individual Heater Heat Requirement,Btu/Month HRother= Other Users Heat Requirement,Btu/Month FCFacillty =Facility Wide Fuel Consumption(metered),MMSCF/Month BSFC=Brake Specific Fuel Consumption,Btu/hp•hr Monthly natural gas consumption for each engine shall be used in a twelve month rolling total to monitor compliance with the annual limitation. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. Monthly natural gas consumption shall be used to monitor compliance with the NOx, CO and VOC emission limitations, as required by Condition 1.1 and 1.2. 1.4 Natural Gas Heat Content The heat content of the natural gas used to fuel these engines shall be verified semi-annually using the appropriate ASTM Methods or equivalent, if approved in advance by the Division. The heat content of the natural gas shall be based on the higher heating value (HHV) of the fuel. Results of the heat content verification shall be maintained and made available to the Division upon request. The heat content used by the Division in determining the emission limitations listed in Summary Table 1 was 1,040 Btu per standard cubic foot of natural gas (Colorado Construction Permits 85WE337-1, 85WE337-2, 85WE337- 3, 85WE337-4, 87WE235-1, 87WE190, 87WE237 and 96WE289, as modified under the provisions of Section I, Condition 1.3). The heat content indicated by the most recent analysis shall be used to monitor compliance with the NOx, CO and VOC emission limitations, as required by Condition 1.1 and 1.2. 1.5 Hours of Operation Hours of operation for each engine shall be monitored and recorded monthly. Hours of operation shall be recorded on the first day of each month. Records of the monthly hours of operation shall be maintained and made available to the Division upon request. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 20 The hours of operation shall be used to monitor compliance with the natural gas consumption limitations, as required by Condition 1.3. 1.6 Opacity The following opacity requirements apply to each engine: 1.6.1 Except as provided for in Condition 1.6.2 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 (Colorado Regulation No. 1, Section II.A.1). 1.6.2 No owner or operator of a source shall allow or cause to be emitted into the atmosphere any air pollutant resulting from the building of a new fire, cleaning of fire boxes, soot blowing, start-up, process modifications, or adjustment or occasional cleaning of control equipment which is excess of 30%opacity for a period or periods aggregating more than six(6)minutes in any sixty (60) consecutive minutes (Colorado Regulation No. 1, Section II.A.4). In the absence of credible evidence to the contrary, compliance with the opacity limit shall be presumed since only natural gas is permitted to be used as fuel for these engines. The permittee shall maintain records that verify that only natural gas is used as fuel. 1.7 Control Device Requirements The Air to Fuel Ratio (AFR) millivolt reading on each engine shall be monitored and recorded monthly to assess the air to fuel ratio controller operating condition.During those months when portable monitoring is scheduled, the millivolt reading and the oxygen concentration in the exhaust shall be monitored and recorded during the portable monitoring event. Recording of the millivolt reading shall be used to verify that the AFR controller is operated in accordance with the manufacturer's recommendations. Records of the monthly AFR millivolt reading and relevant manufacturer recommendations shall be maintained and made available to the Division upon request. 1.8 Portable Monitoring Portable monitoring shall be conducted quarterly in accordance with the requirements of Condition 14. 1.9 Compliance Assurance Monitoring (CAM) Each engine is subject to the Compliance Assurance Monitoring(CAM)requirements with respect to the annual NOx emission limitations set forth in Condition 1.1. Compliance with the CAM requirements shall be monitored in accordance with Condition 13 and the CAM Plan in Appendix G. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 21 1.10 Statewide Controls for Oil and Gas Operations 1.10.1 Colorado Regulation No. 7, Part E, Section I. Requirements: Unless otherwise indicated below, each engine is subject to the following requirements of Colorado,Regulation No. 7, Part E, Section I. "Control of Emissions from Engines": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. 1.10.1.1 All engines: Air Pollution Technology Requirements (Colorado Regulation No. 7, Part E, Section I.B.) a. For rich burn reciprocating internal combustion engines, a non-selective catalyst reduction and an air fuel controller shall be required. A rich burn reciprocating internal combustion engine is one with a normal exhaust oxygen concentration of less than 2% by volume (Colorado Regulation No. 7, Part E, Section I.B.1.). b. The emission control equipment required by this Section I.B (Condition a above) shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications (Colorado Regulation No. 7, Part E, Section I.B.3.). 1.10.1.2 Engine C-123 only: Control of emissions from new, modified, existing and relocated natural gas fired reciprocating internal combustion engines (Colorado Regulation No. 7, Part E, Section I.D.). a. [State-Only Enforceable] New, Modified and Relocated Natural Gas Fired Reciprocating Internal Combustion Engines (Colorado Regulation No. 7, Part E, Section I.D.2.). (i) Except as provided in Section I.D.2.b. (Condition (ii) below), the owner or operator of any natural gas fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state, on or after the date listed in Table 1 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 Section I.D.2.b. Table 1 Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 22 Condition (ii) below) (Colorado Regulation No. 7, Part E, Section I.D.2.a.). (ii) Actual emissions from natural gas fired reciprocating internal combustion engines shall not exceed the emission performance standards in Table 1 as expressed in units of grams per horsepower- hour(g/hp-hr) (Colorado Regulation No. 7, Part E, Section I.D.2.b.): Table 1 Maximum Construction or Relocation Date Emission Standard in g/hp-hr Engine HP NOx CO VOC On or after July 1,2007 2.0 4.0 1.0 >_500 HP On or after July 1,2010 1.0 2.0 0.7 [Compliance Demonstration: Compliance with the NOx and CO emission limitations shall be monitored by conducting portable monitoring quarterly as specified in Condition 1.8. For comparison with the short—term limits in this Condition, the results of the portable monitoring test shall be converted to units of g/hp-hr to assess compliance with the NOx and CO emission limitations in this Condition (ii).] [Compliance Demonstration: In the absence of credible evidence to the contrary, compliance with the VOC limitation is presumed provided the portable monitoring indicates compliance with the NOx and CO emission limitations in this Condition (ii).] 1.10.2 Colorado Regulation No. 7, Part E, Section II. Requirements: Each engine is subject to the following requirements of Colorado Regulation No. 7, Part E, Section II., "Control of Emissions from Stationary and Portable Combustion Equipment in the 8-Hour Ozone Control Area": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. 1.10.2.1 Exemptions (Colorado Regulation No. 7, Part E, Section II.A.2.) The following stationary combustion equipment are exempt from the emission limitation requirements of Section II.A.4., the compliance demonstration requirements in Section II.A.5., and the related recordkeeping and reporting Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 23 requirements of Sections II.A.7.a-e. and II.A.8, but these sources must maintain any and all records necessary to demonstrate that an exemption applies(Condition 1.10.2.3b). These records must be maintained for a minimum of five years and made available to the Division upon request. Qualifying for an exemption in this section does not preclude the combustion process adjustment requirements of Section II.A.6. (Condition 1.10.2.2), when required by II.A.6.a (Condition 1.10.2.2a). Once stationary combustion equipment no longer qualifies for any exemption,the owner or operator must comply with the applicable requirements of this Section II.A. as expeditiously as practicable but no later than 36 months after any exemption no longer applies.Additionally,once stationary combustion equipment that is not equipped with CEMS or CERMS no longer qualifies for any exemption, the owner or operator must conduct a performance test using EPA test methods within 180 days and notify the Division of the results and whether emission controls will be required to comply with the emission limitations of Section II.A.4. a. Any natural gas-fired reciprocating internal combustion engines subject to a work practice or emission control requirement contained in this Regulation 7, Part E, Section I.A. or B. (Condition 1.10.1.1) (Colorado Regulation No. 7, Part E, Section II.A.2.e.). 1.10.2.2 Combustion Process Adjustment (Colorado Regulation No. 7, Part E, Section II.A.6.). a. As of January 1, 2017, this Section II.A.6. (Condition 1.10.2.2) applies to boilers, duct burners, process heaters, stationary combustion turbines, and stationary reciprocating internal combustion engines with uncontrolled actual emissions of NOx equal to or greater than five (5)tons per year that existed at major sources of NOx (greater than or equal to 100 tpy NOx) as of June 3, 2016. (Colorado Regulation No. 7, Part E, Section II.A.6.a.(i)). b. The owner or operator of a stationary internal combustion engine must conduct the following inspections and adjustments,as applicable(Colorado Regulation No. 7, Part E, Section II.A.6.b.(iv)): (i) Change oil and filters as necessary(Colorado Regulation No. 7,Part E, Section II.A.6.b.(iv)(A)). (ii) Inspect air cleaners,fuel filters,hoses,and belts and clean or replace as necessary (Colorado Regulation No. 7, Part E, Section II.A.6.b.(iv)(B)). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 24 (iii) Inspect spark plugs and replace as necessary(Colorado Regulation No. 7, Part E, Section II.A.6.b.(iv)(C)). c. The owner or operator must operate and maintain the boiler, duct burner, process heater, stationary combustion turbine, stationary internal combustion engine, dryer, furnace or ceramic kiln consistent with manufacturer's specifications, if available, or good engineering and maintenance practices (Colorado Regulation No. 7, Part E, Section II.A.6.b.(vii)). d. Frequency (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)) (i) The owner or operator of boilers, duct burners, process heaters, stationary combustion turbines, and stationary reciprocating internal combustion engines with uncontrolled actual emissions of NOx equal to or greater than five (5)tons per year that existed at major sources of NOx (greater than or equal to 100 tpy NOx) as of June 3, 2016, must conduct the initial combustion process adjustment by April 1,2017.An owner or operator may rely on a combustion process adjustment conducted in accordance with applicable requirements and schedule of a New Source Performance Standard in 40 CFR Part 60 or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 to satisfy the requirement to conduct an initial combustion process adjustment by April 1, 2017 (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)(A)). (ii) The owner or operator must conduct subsequent combustion process adjustments at least once every twelve (12) months after the initial combustion adjustment, or on the applicable schedule according to Sections II.A.6.c.(i). (Condition e(i)) or II.A.6.c.(ii). (Condition e(ii)) (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)(C)). e. As an alternative to the requirements described in Sections II.A.6.b.(iv) (Condition b) through II.A.6.b.(viii) (Condition d) (Colorado Regulation No. 7, Part E, Section II.A.6.c.): (i) The owner or operator may conduct the combustion process adjustment according to the manufacturer recommended procedures and schedule (Colorado Regulation No. 7, Part E, Section II.A.6.c.(i)); or (ii) The owner or operator of combustion equipment that is subject to and required to conduct a periodic tune-up or combustion adjustment by the applicable requirements of a New Source Performance Standard in 40 Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit#95OPWE038 Page 25 CFR Part 60 (December 19, 2019) or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 (December 19, 2019)may conduct tune-ups or adjustments according to the schedule and procedures of the applicable requirements of 40 CFR Part 60(December 19, 2019) or 40 CFR Part 63 (December 19, 2019) (Colorado Regulation No. 7, Part E, Section II.A.6.c.(ii)). 1.10.2.3 Recordkeeping. The following records must be kept for a period of five years and made available to the Division upon request (Colorado Regulation No. 7, Part E, Section II.A.7.): a. For stationary combustion equipment subject to the combustion process adjustment requirements in Section II.A.6. (Condition 1.10.2.2),the following recordkeeping requirements apply(Colorado Regulation No. 7,Part E, Section II.A.7.f.): (i) The owner or operator must create a record once every calendar year identifying the combustion equipment at the source subject to Section II.A. (Condition 1.10.2.2a) and including for each combustion equipment(Colorado Regulation No. 7, Part E, Section II.A.7.(f).(i)): (A) The date of the adjustment(Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(A)); (B) Whether the combustion process adjustment under Sections II.A.6.b.(iv) (Condition 1.10.2.2b)was followed, and what procedures were performed (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(B)); (C) Whether a combustion process adjustment under Sections II.A.6.c.(i). (Condition 1.10.2.2e(i)) and II.A.6.c.(ii). (Condition 1.10.2.2e(ii)). was followed, what procedures were performed, and what New Source Performance or National Emission Standard for Hazardous Air Pollutants applied, if any (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(C)); and (D) A description of any corrective action taken (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(D)). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 26 (E) If the owner or operator conducts the combustion process adjustment according to the manufacturer recommended procedures and schedule and the manufacturer specifies a combustion process adjustment on an operation time schedule, the hours of operation. (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(E)). (ii) The owner or operator must retain manufacturer recommended procedures, specifications, and maintenance schedule if utilized under Section II.A.6.c.(i). (Condition 1.10.2.2e(i)) for the life of the equipment(Colorado Regulation No. 7, Part E, Section II.A.7.f.(ii)). (iii) As an alternative to the requirements described in Section II.A.7.f.(i) (Condition (i) above), the owner or operator may comply with applicable recordkeeping requirements related to combustion process adjustments conducted according to a New Source Performance Standard in 40 CFR Part 60 or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 (Colorado Regulation No. 7, Part E, Section II.A.7.f.(iii)). b. All sources qualifying for an exemption under Section II.A.2. (Condition 1.10.2.1)must maintain all records necessary to demonstrate that an exemption applies (Colorado Regulation No. 7, Part E, Section II.A.7.g.). 1.11 40 CFR Part 63 Subpart ZZZZ MACT Each engine is subject to the National Emissions Standards for Hazardous Air Pollutants requirements of Regulation No. 8, Part E, Subpart ZZZZ (40 CFR Part 63, Subpart ZZZZ)"National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines", including, but not limited to,the following: The requirements below reflect the current rule language as of the revisions to 40 CFR Part 63 Subpart ZZZZ published in the Federal Register on 2/27/2014. However, if revisions to this Subpart are published at a later date, the owner or operator is subject to the requirements contained in the revised version of 40 CFR Part 63 Subpart ZZZZ. Note that as of the date of revised permit issuance XX/XX/XXXX, the requirements in 40 CFR Part 63 Subpart ZZZZ promulgated on March 3, 2010 and later have not been adopted into Colorado Regulation No. 8, Part E by the Division and are therefore not state-enforceable. In the event that the Division adopts these requirements, they will become both state and federally enforceable. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 27 General Requirements 1.11.1 You must be in compliance with the emission limitations, operating limitations, and other requirements in this subpart that apply to you at all times (§63.6605(a)). 1.11.2 At all times you must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. The general duty to minimize emissions does not require you to make any further efforts to reduce emissions if levels required by this standard have been achieved. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source (§63.6605(b)). Emission Limitations 1.11.3 If you own or operate an existing stationary RICE located at an area source of HAP emissions, you must comply with the requirements in Table 2d to this subpart that apply to you (§63.6603(a)): 1.11.3.1 Non-emergency, non-black start 4SRB stationary RICE >500 HP that are not remote stationary RICE and that operate more than 24 hours per calendar year shall install NSCR to reduce HAP emissions from the stationary RICE (Table 2d, Item 12). Monitoring, Installation, Collection, Operation and Maintenance Requirements 1.11.4 If you operate a new, reconstructed, or existing stationary engine, you must minimize the engine's time spent at idle during startup and minimize the engine's startup time to a period needed for appropriate and safe loading of the engine, not to exceed 30 minutes, after which time the emission standards applicable to all times other than startup in Table 2d (Condition 1.11.3.1)to this subpart apply (§63.6625(h)). Data Collection for Continuous Compliance 1.11.5 Except for monitor malfunctions, associated repairs, required performance evaluations, and required quality assurance or control activities, you must monitor continuously at all times that the stationary RICE is operating. A monitoring malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring to provide valid data.Monitoring failures Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 28 that are caused in part by poor maintenance or careless operation are not malfunctions (§63.6635(b)). 1.11.6 You may not use data recorded during monitoring malfunctions, associated repairs, and required quality assurance or control activities in data averages and calculations used to report emission or operating levels. You must, however, use all the valid data collected during all other periods (§63.6635(c)). Continuous Compliance Demonstration 1.11.7 You must demonstrate continuous compliance with each emission limitation and other requirements in Table 2d (Condition 1.11.3.1) to this subpart that apply to you according to methods specified in Table 6 to this subpart(§63.6640(a)): 1.11.7.1 Existing non-emergency 4SRB stationary RICE>500 HP located at an area source of HAP that are not remote stationary RICE and that are operated more than 24 hours per calendar year shall: a. Conduct annual compliance demonstrations as specified in §63.6640(c) (Condition 1.11.7.3)to show that the average reduction of emissions of CO is 75 percent or more, the average CO concentration is less than or equal to 270 ppmvd at 15 percent O2, or the average reduction of emissions of THC is 30 percent or more (Table 6, Item 15.a.i); and b. Immediately shut down the engine if the catalyst inlet temperature exceeds 1250°F (Table 6, Item 15.a.iii). 1.11.7.2 You must report each instance in which you did not meet each emission limitation or operating limitation in Table 2d (Condition 1.11.3.1) to this subpart that apply to you. These instances are deviations from the emission and operating limitations in this subpart. These deviations must be reported according to the requirements in §63.6650 (Conditions 1.11.9 through 1.11.13). If you change your catalyst,you must reestablish the values of the operating parameters measured during the initial performance test. When you reestablish the values of your operating parameters, you must also conduct a performance test to demonstrate that you are meeting the required emission limitation applicable to your stationary RICE (§63.6640(b)). 1.11.7.3 The annual compliance demonstration required for existing non-emergency 4SRB stationary RICE with a site rating of more than 500 HP located at an area source of HAP that are not remote stationary RICE and that are operated more than 24 hours per calendar year must be conducted according to the requirements of Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit#95OPWE038 Page 29 §63.6640(c)(1)through (c)(7) (§63.6640(c)). 1.11.7.4 You must also report each instance in which you did not meet the requirements in Table 8 (Condition 1.12)to this subpart that apply to you (§63.6640(e)). Notification Requirements 1.11.8 You must submit all of the notifications in §63.9(b) through (e), and (h) (Condition 1.12.2) that apply to you by the dates specified(§63.6645(a)). Reporting Requirements 1.11.9 You must submit each report in Table 7 of this subpart that applies to you(§63.6650(a)): 1.11.9.1 Existing non-emergency, non-black start 4SRB stationary RICE>500 HP located at an area source of HAP that are not remote stationary RICE and that operate more than 24 hours per calendar year shall: a. Submit a compliance report containing the results of the annual compliance demonstration, if conducted during the reporting period, annually, according to the requirements in §63.6650(h)(2)-(3) of this subpart(Table 7, Item 3.a.i). 1.11.10 Unless the Administrator has approved a different schedule for submission of reports under §63.10(a) (Condition 1.12.3), you must submit each report by the date in Table 7 (Condition 1.11.9.1) of this subpart and according to the requirements in paragraphs §63.6650(b)(1) through (b)(9) of this subpart(§63.6650(b)). 1.11.11 The Compliance report must contain the information in paragraphs §63.6650(c)(1) through (5) of this subpart(§63.6650(c)). 1.11.12 For each deviation from an emission or operating limitation (Condition 1.11.3.1) that occurs for a stationary RICE where you are not using a CMS to comply with the emission or operating limitations in this subpart,the Compliance report must contain the information in paragraphs §63.6650(c)(1) through (4) of this subpart and the information in paragraphs §63.6650(d)(1) and (2) of this subpart(§63.6650(d)). 1.11.13 Each affected source that has obtained a title V operating permit pursuant to 40 CFR part 70 or 71 must report all deviations as defined in this subpart (Condition 1.11.7.2) in the semiannual monitoring report required by 40 CFR 70.6 (a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A). If an affected source submits a Compliance report pursuant to Table 7 (Condition 1.11.9) of this subpart along with, or as part of, the semiannual monitoring report required by 40 CFR 70.6(a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A), and the Compliance Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 30 report includes all required information concerning deviations from any emission or operating limitation (Condition 1.11.3.1) in this subpart, submission of the Compliance report shall be deemed to satisfy any obligation to report the same deviations in the semiannual monitoring report. However, submission of a Compliance report shall not otherwise affect any obligation the affected source may have to report deviations from permit requirements to the permit authority (§63.6650(f)). Recordkeeping Requirements 1.11.14 If you must comply with the emission and operating limitations (Condition 1.11.3.1), you must keep the records described in paragraphs §63.6655(a)(1) through (a)(5) of this subpart (§63.6655(a)). 1.11.15 You must keep the records required in Table 6 (Condition 1.11.7.1) of this subpart to show continuous compliance with each emission or operating limitation that applies to you (§63.6655(d)). 1.11.16 Your records must be in a form suitable and readily available for expeditious review according to §63.10(b)(1) (Condition 1.12.3) (§63.6660(a)). 1.11.17 As specified in §63.10(b)(1) (Condition 1.12.3), you must keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record (§63.6660(b)). 1.11.18 You must keep each record readily accessible in hard copy or electronic form for at least 5 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to §63.10(b)(1) (Condition 1.12.3) (§63.6660(c)). 1.12 40 CFR Part 63 Subpart A MACT Each engine is subject to the requirements in 40 CFR Part 63 Subpart A"General Provisions",as adopted by reference in Colorado Regulation No. 8,Part E, Section I as specified in 40 CFR Part 63 Subpart ZZZZ §63.6665. These requirements include, but are not limited to the following: 1.12.1 Prohibited Activities and Circumvention (§63.4) 1.12.2 Notification Requirements (§63.9) 1.12.3 Recordkeeping and Reporting Requirements (§63.10) Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 31 2. C-124—Waukesha F-11G 125 hp Compressor Engine,AIRS ID: 102 Permit Compliance Monitoring Parameter Condition Compliance Limits Number Emission Factor Method Interval Emission&Consumption Limits C-124—Waukesha F-11G 125 hp Natural Gas Fired Internal Combustion Engine NOx 3.02 tons/year 0.696 lb/MMBtu Recordkeeping and 2.1 Twelve Month Rolling Total CO 4.22 tons/year 0.973 lb/MMBtu Calculation Monthly Natural Gas 2.2 Fuel Meter,Twelve Consumption 8.3 MMSCF/year Month Rolling Total Other Requirements Natural Gas Heat ASTM or other Semi- 2.3 Content Division Approved Annually Method Hours of Operation 2.4 Recordkeeping Monthly Not to exceed 20%,except as provided for below: Opacity 2.5 For Certain Operational Activities-Not to Fuel Restriction—Natural Gas exceed 30%for a period or periods Only aggregating more than six(6)minutes in any sixty(60)consecutive minutes Control Device 2.6 See Condition 2.6 Requirements Portable Monitoring 2.7 Flue Gas Analyzer Quarterly Statewide Controls for Oil and Gas 2.8 See Condition 2.8 Operations 40 CFR 63 Subpart 2.9 See Condition 2.9 ZZZZ MACT 40 CFR 63 Subpart A General 2.10 See Condition 2.10 Provisions MACT Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 32 2.1 NOx and CO Emission Limitations & Compliance Monitoring Emissions of Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from this engine shall not exceed the limitations listed in Summary Table 2 above(Colorado Construction Permit 85WE304,as modified under the provisions of Section I, Condition 1.3). Except as provided for below, the emission factors listed above have been approved by the Division and shall be used to calculate emissions from this engine as follows: 2.1.1 Monthly determination of NOx and CO emissions shall be conducted by the end of the subsequent month using the emission factors listed in Summary Table 2 above, the monthly natural gas consumption, as required by Condition 2.2,and the heat content of the natural gas obtained from the most recent analysis, as required by Condition 2.3, in the equation below: ( lb l (MMBtu MMSCF tons l Emission Factor MMBtu/ x Heat Content MMSCF)x Fuel Use month NOx or CO Emissions (month/ 2000 lb ) Unit Conversion ( ton Monthly emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data.Records of calculations shall be maintained and made available to the Division upon request. 2.1.2 Portable monitoring shall be conducted quarterly as required by Condition 2.7. If the results of the portable analyzer testing conducted under the provisions of Condition 2.7 show that either the NOx or CO emission rates/factors are greater than those listed above, and in the absence of subsequent testing results to the contrary (as approved by the Division), the permittee shall apply for a modification to this permit to reflect, at a minimum, the higher emission rates/factors within 60 days of the completion of the test. 2.1.3 Facility-wide emissions of Hazardous Air Pollutants (HAP) shall not exceed the annual facility-wide limitations set forth in Condition 11 (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). Monthly emissions of each HAP shall be calculated by the end of the subsequent month using the methods set forth in Condition 11 and used in a twelve month rolling total to monitor compliance with the facility-wide HAP emission limitations. 2.2 Natural Gas Consumption Limitations & Compliance Monitoring Natural gas consumption for this engine shall not exceed the limitations listed in Summary Table 2 above (Colorado Construction Permit 85WE304, as modified under the provisions of Section I, Condition 1.3). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 33 Facility-wide natural gas consumption shall be recorded on the first day of each month using the facility fuel meter. Allocation of natural gas to this engine shall be determined using the following equation: Btu l MMSCF) HREngine(month) MMSCF FCEngine(month/ Btu (month) ( Btu )X FCFaciiity 1r HREngine(( +E HRHeater + HRother (month (month) (month )month) Where: Btu hr HREngine (month) = BSFC (hp Btu• r)x Hours o f Operation (month) x Site Rated HP(hp) Btu Btu hr HRHeater (month)= Design Heat Rating (hr)x Hours of Operation (month) And: FCEngine =Individual Engine Fuel Consumption,MMSCF/Month HREngine =Individual Engine Heat Requirement,Btu/Month HRHeater=Individual Heater Heat Requirement,Btu/Month 'Mother=Other Users Heat Requirement,Btu/Month FCFaciiity =Facility Wide Fuel Consumption(metered),MMSCF/Month BSFC=Brake Specific Fuel Consumption,Btu/hp•hr Monthly natural gas consumption for this engine shall be used in a twelve month rolling total to monitor compliance with the annual limitation. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. Monthly natural gas consumption shall be used to monitor compliance with the NOx and CO emission limitations, as required by Condition 2.1. 2.3 Natural Gas Heat Content The heat content of the natural gas used to fuel this engine shall be verified semi-annually using the appropriate ASTM Methods or equivalent, if approved in advance by the Division. The heat content of the natural gas shall be based on the higher heating value (HHV) of the fuel. Results of the heat content verification shall be maintained and made available to the Division upon request. The heat content used Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 34 by the Division in determining the emission limitations listed in Summary Table 2 was 1,040 Btu per standard cubic foot of natural gas (Colorado Construction Permit 85WE304, as modified under the provisions of Section I, Condition 1.3). The heat content indicated on the most recent analysis shall be used to monitor compliance with the NOx and CO emission limitations, as required by Condition 2.1. 2.4 Hours of Operation Hours of operation for this engine shall be monitored and recorded monthly. Hours of operation shall be recorded on the first day of each month. Records of the monthly hours of operation shall be maintained and made available to the Division upon request. The hours of operation shall be used to monitor compliance with the natural gas consumption limitation, as required by Condition 2.2. 2.5 Opacity The following opacity requirements apply to this engine: 2.5.1 Except as provided for in Condition 2.5.2 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 (Colorado Regulation No. 1, Section II.A.1). 2.5.2 No owner or operator of a source shall allow or cause to be emitted into the atmosphere any air pollutant resulting from the building of a new fire, cleaning of fire boxes, soot blowing, start-up, process modifications, or adjustment or occasional cleaning of control equipment which is excess of 30%opacity for a period or periods aggregating more than six(6) minutes in any sixty (60) consecutive minutes (Colorado Regulation No. 1, Section II.A.4). In the absence of credible evidence to the contrary, compliance with the opacity limit shall be presumed since only natural gas is permitted to be used as fuel for this engine. The permittee shall maintain records that verify that only natural gas is used as fuel. 2.6 Control Device Requirements 2.6.1 The Air to Fuel Ratio (AFR)millivolt reading on this engine shall be monitored and recorded monthly to assess the air to fuel ratio controller operating condition. During those months when portable monitoring is scheduled,the millivolt reading and the oxygen concentration in the exhaust shall be monitored and recorded during the portable monitoring event. Recording Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 35 of the millivolt reading shall be used to verify that the AFR controller is operated in accordance with the manufacturer's recommendations.Records of the monthly AFR millivolt reading and relevant manufacturer recommendations shall be maintained and made available to the Division upon request. 2.6.2 The catalytic converter (NSCR) shall have the inlet temperature, inlet pressure and outlet pressure measured at least once per calendar month. The results shall be recorded and kept on-site for Division review upon request. Any replacement, servicing,or modifications of the NSCR shall be recorded. Manufacturer's recommendations shall be followed as to the temperature and pressure change needed across the NSCR to ensure proper performance. The manufacturer's values or range of values shall be indicated along with the record of the monthly readings for immediate reference. 2.7 Portable Monitoring Portable monitoring shall be conducted quarterly in accordance with the requirements of Condition 14. 2.8 Statewide Controls for Oil and Gas Operations 2.8.1 Colorado Regulation No. 7, Part E, Section II. Requirements: This engine is subject to the following requirements of Colorado Regulation No. 7, Part E, Section II., "Control of Emissions from Stationary and Portable Combustion Equipment in the 8-Hour Ozone Control Area": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. 2.8.1.1 Exemptions (Colorado Regulation No. 7, Part E, Section II.A.2) a. The following stationary combustion equipment are exempt from the emission limitation requirements of Section II.A.4., the compliance demonstration requirements in Section II.A.5., and the related recordkeeping and reporting requirements of Sections II.A.7.a-e. and II.A.8, but these sources must maintain any and all records necessary to demonstrate that an exemption applies(Condition 2.8.1.3b).These records must be maintained for a minimum of five years and made available to the Division upon request. Qualifying for an exemption in this section does not preclude the combustion process Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 36 adjustment requirements of Section II.A.6. (Condition 2.8.1.2), when required by II.A.6.a(Condition 2.8.1.2a). Once stationary combustion equipment no longer qualifies for any exemption, the owner or operator must comply with the applicable requirements of this Section II.A. as expeditiously as practicable but no later than 36 months after any exemption no longer applies. Additionally, once stationary combustion equipment that is not equipped with CEMS or CERMS no longer qualifies for any exemption, the owner or operator must conduct a performance test using EPA test methods within 180 days and notify the Division of the results and whether emission controls will be required to comply with the emission limitations of Section II.A.4. (i) Any stationary combustion equipment subject to a federally enforceable work practice or emission control requirement contained in this Regulation 7, Part E, Section III.A.-B or Regulation 3, Part F (Colorado Regulation No. 7, Part E, Section II.A.2.f.). 2.8.1.2 Combustion Process Adjustment (Colorado Regulation No. 7, Part E, Section II.A.6.) a. As of January 1, 2017, this Section II.A.6.(Condition 2.8.1.2) applies to boilers, duct burners, process heaters, stationary combustion turbines, and stationary reciprocating internal combustion engines with uncontrolled actual emissions of NOx equal to or greater than five (5)tons per year that existed at major sources of NOx (greater than or equal to 100 tpy NOx) as of June 3, 2016. (Colorado Regulation No. 7, Part E, Section II.A.6.a.(i)). b. The owner or operator of a stationary internal combustion engine must conduct the following inspections and adjustments,as applicable(Colorado Regulation No. 7, Part E, Section II.A.6.b.(iv)): (i) Change oil and filters as necessary(Colorado Regulation No. 7,Part E, Section II.A.6.b.(iv)(A)). (ii) Inspect air cleaners,fuel filters,hoses,and belts and clean or replace as necessary (Colorado Regulation No. 7, Part E, Section II.A.6.b.(iv)(B)). (iii) Inspect spark plugs and replace as necessary(Colorado Regulation No. 7, Part E, Section II.A.6.b.(iv)(C)). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 37 c. The owner or operator must operate and maintain the boiler, duct burner, process heater, stationary combustion turbine, stationary internal combustion engine, dryer, furnace, or ceramic kiln consistent with manufacturer's specifications, if available, or good engineering and maintenance practices (Colorado Regulation No. 7, Part E, Section II.A.6.b.(vii)). d. Frequency (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)) (i) The owner or operator of boilers, duct burners, process heaters, stationary combustion turbines, and stationary reciprocating internal combustion engines with uncontrolled actual emissions of NOx equal to or greater than five (5)tons per year that existed at major sources of NOx (greater than or equal to 100 tpy NOx) as of June 3, 2016, must conduct the initial combustion process adjustment by April 1,2017.An owner or operator may rely on a combustion process adjustment conducted in accordance with applicable requirements and schedule of a New Source Performance Standard in 40 CFR Part 60 or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 to satisfy the requirement to conduct an initial combustion process adjustment by April 1, 2017 (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)(A)). (ii) The owner or operator must conduct subsequent combustion process adjustments at least once every twelve (12) months after the initial combustion adjustment, or on the applicable schedule according to Sections II.A.6.c.(i). (Condition e(i)) or II.A.6.c.(ii). (Condition e(ii)) (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)(C)). e. As an alternative to the requirements described in Sections II.A.6.b.(iv) (Condition b) through II.A.6.b.(viii) (Condition d) (Colorado Regulation No. 7, Part E, Section II.A.6.c.): (i) The owner or operator may conduct the combustion process adjustment according to the manufacturer recommended procedures and schedule (Colorado Regulation No. 7, Part E, Section II.A.6.c.(i)); or (ii) The owner or operator of combustion equipment that is subject to and required to conduct a periodic tune-up or combustion adjustment by the applicable requirements of a New Source Performance Standard in 40 CFR Part 60 (December 19, 2019) or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 (December 19, 2019)may conduct tune-ups or adjustments according to the schedule and Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 38 procedures of the applicable requirements of 40 CFR Part 60 (December 19, 2019) or 40 CFR Part 63 (December 19, 2019) (Colorado Regulation No. 7, Part E, Section II.A.6.c.(ii)). 2.8.1.3 Recordkeeping. The following records must be kept for a period of five years and made available to the Division upon request (Colorado Regulation No. 7, Part E, Section II.A.7.): a. For stationary combustion equipment subject to the combustion process adjustment requirements in Section II.A.6. (Condition 2.8.1.2), the following recordkeeping requirements apply(Colorado Regulation No. 7,Part E, Section II.A.7.f.): (i) The owner or operator must create a record once every calendar year identifying the combustion equipment at the source subject to Section II.A. (Condition 2.8.1.1a) and including for each combustion equipment(Colorado Regulation No. 7,Part E, Section II.A.7.(f).(i)): (A) The date of the adjustment(Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(A)); (B) Whether the combustion process adjustment under Sections II.A.6.b.(iv) (Condition 2.8.1.2b) was followed, and what procedures were performed (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(B)); (C) Whether a combustion process adjustment under Sections II.A.6.c.(i). (Condition 2.8.1.2e(i)) and II.A.6.c.(ii). (Condition 2.8.1.2e(ii)). was followed, what procedures were performed, and what New Source Performance or National Emission Standard for Hazardous Air Pollutants applied, if any (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(C)); and (D) A description of any corrective action taken (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(D)). (E) If the owner or operator conducts the combustion process adjustment according to the manufacturer recommended procedures and schedule and the manufacturer specifies a combustion process adjustment on an operation time schedule, Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 39 the hours of operation. (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(E)). (ii) The owner or operator must retain manufacturer recommended procedures, specifications, and maintenance schedule if utilized under Section II.A.6.c.(i). (Condition 2.8.1.2e(i))for the life of the equipment (Colorado Regulation No. 7, Part E, Section II.A.7.f.(ii)). (iii) As an alternative to the requirements described in Section II.A.7.f.(i) • (Condition (i) above), the owner or operator may comply with applicable recordkeeping requirements related to combustion process adjustments conducted according to a New Source Performance Standard in 40 CFR Part 60 or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 (Colorado Regulation No. 7, Part E, Section II.A.7.f.(iii)). b. All sources qualifying for an exemption under Section II.A.2. (Condition 2.8.1.1)must maintain all records necessary to demonstrate that an exemption applies (Colorado Regulation No. 7, Part E, Section II.A.7.g.). 2.9 40 CFR Part 63 Subpart ZZZZ MACT This engine is subject to the National Emissions Standards for Hazardous Air Pollutants requirements of Regulation No. 8,Part E, Subpart ZZZZ(40 CFR Part 63, Subpart ZZZZ)"National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines", including, but not limited to, the following: The requirements below reflect the current rule language as of the revisions to 40 CFR Part 63 Subpart ZZZZ published in the Federal Register on 2/27/2014. However, if revisions to this Subpart are published at a later date, the owner or operator is subject to the requirements contained in the revised version of 40 CFR Part 63 Subpart ZZZZ. Note that as of the date of revised permit issuance XX/XX/XXXX, the requirements in 40 CFR Part 63 Subpart ZZZZ promulgated on March 3, 2010 and later have not been adopted into Colorado Regulation No. 8,Part E by the Division and are therefore not state-enforceable. In the event that the Division adopts these requirements,they will become both state and federally enforceable. General Requirements 2.9.1 You must be in compliance with the emission limitations, operating limitations, and other requirements in this subpart that apply to you at all times (§63.6605(a)). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 40 2.9.2 At all times you must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. The general duty to minimize emissions does not require you to make any further efforts to reduce emissions if levels required by this standard have been achieved. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source (§63.6605(b)). Emission Limitations, Operating Limitations and Work Practices 2.9.3 If you own or operate an existing stationary RICE located at an area source of HAP emissions, you must comply with the requirements in Table 2d to this subpart that apply to you (§63.6603(a)): 2.9.3.1 Non-emergency, non-black start 4SRB stationary RICE<500 HP shall: a. Change oil and filter every 1,440 hours of operation or annually, whichever comes first (Table 2d, Item 10.a) b. Inspect spark plugs every 1,440 hours of operation or annually, whichever comes first, and replace as necessary(Table 2d, Item 10.b); and c. Inspect all hoses and belts every 1,440 hours of operation or annually, whichever comes first, and replace as necessary (Table 2d, Item 10.c). Monitoring, Installation, Collection, Operation and Maintenance Requirements 2.9.4 You must operate and maintain the stationary RICE and after-treatment control device(if any) according to the manufacturer's emission-related written instructions or develop your own maintenance plan which must provide to the extent practicable for the maintenance and operation of the engine in a manner consistent with good air pollution control practice for minimizing emissions (§63.6625(e)). 2.9.5 If you operate a new, reconstructed, or existing stationary engine, you must minimize the engine's time spent at idle during startup and minimize the engine's startup time to a period needed for appropriate and safe loading of the engine, not to exceed 30 minutes, after which time the emission standards applicable to all times other than startup in Table 2d (Condition 2.9.3.1)to this subpart apply (§63.6625(h)). Continuous Compliance Demonstration Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 41 2.9.6 You must demonstrate continuous compliance with each emission limitation, operating limitation, and other requirements in Table 2d to this subpart that apply to you according to methods specified in Table 6 to this subpart(§63.6640(a)): 2.9.6.1 Existing 4SRB stationary RICE<500 HP located at an area source of HAP shall: a. Operate and maintain the stationary RICE according to the manufacturer's emission-related operation and maintenance instructions (Table 6, Item 9.a.i); or b. Develop and follow your own maintenance plan which must provide to the extent practicable for the maintenance and operation of the engine in a manner consistent with good air pollution control practice for minimizing emissions (Table 6, Item 9.a.ii). 2.9.7 You must report each instance in which you did not meet each emission limitation or operating limitation in Table 2d (Condition 2.9.3.1) to this subpart that apply to you. These instances are deviations from the emission and operating limitations in this subpart. These deviations must be reported according to the requirements in §63.6650 (Condition 2.9.9). If you change your catalyst, you must reestablish the values of the operating parameters measured during the initial performance test. When you reestablish the values of your operating parameters, you must also conduct a performance test to demonstrate that you are meeting the required emission limitation applicable to your stationary RICE (§63.6640(b)). 2.9.8 You must also report each instance in which you did not meet the requirements in Table 8 (Condition 2.10)to this subpart that apply to you (§63.6640(e)). Reporting Requirements 2.9.9 Each affected source that has obtained a title V operating permit pursuant to 40 CFR part 70 or 71 must report all deviations as defined in this subpart(Condition 2.9.7) in the semiannual monitoring report required by 40 CFR 70.6 (a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A) (§63.6650(f)). Recordkeeping Requirements 2.9.10 If you must comply with the emission and operating limitations(Condition 2.9.3.1),you must keep the records described in paragraphs §63.6655(a)(1) through (a)(5) of this subpart (§63.6655(a)). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 42 2.9.11 You must keep the records required in Table 6 (Condition 2.9.6.1) of this subpart to show continuous compliance with each emission or operating limitation that applies to you (§63.6655(d)). 2.9.12 You must keep records of the maintenance conducted on the stationary RICE in order to demonstrate that you operated and maintained the stationary RICE and after-treatment control device (if any) according to your own maintenance plan (§63.6655(e)). 2.9.13 Your records must be in a form suitable and readily available for expeditious review according to §63.10(b)(1) (Condition 2.10.2) (§63.6660(a)). 2.9.14 As specified in §63.10(b)(1) (Condition 2.10.2), you must keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record (§63.6660(b)). 2.9.15 You must keep each record readily accessible in hard copy or electronic form for at least 5 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to §63.10(b)(1) (Condition 2.10.2) (§63.6660(c)). 2.10 40 CFR Part 63 Subpart A MACT This engine is subject to the requirements in 40 CFR Part 63 Subpart A"General Provisions", as adopted by reference in Colorado Regulation No. 8,Part E, Section I as specified in 40 CFR Part 63 Subpart ZZZZ §63.6665. These requirements include, but are not limited to the following: 2.10.1 Prohibited Activities and Circumvention (§63.4) 2.10.2 Recordkeeping and Reporting Requirements (§63.10) Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 43 3. P-139—G.C. Broach Natural Gas Fired 35.1 MMBtu/hr Hot Oil Heater, AIRS ID: 120 Permit Compliance Monitoring Parameter Condition Compliance Limits Emission Number Factor Method Interval Emission&Consumption Limits NOx 14.64 tons/year 100 Ib/MMSCF Recordkeeping and Twelve 3.1 Month Rolling Total Monthly CO 12.30 tons/year 84 lb/MMSCF Calculation PM 3.2 Fuel Restriction—Natural Gas Only Natural Gas Fuel Meter and Twelve Consumption 3.3 292.83 MMSCF/year Month Rolling Total Monthly Calculation Other Requirements Natural Gas ASTM or other Division Semi- Heat Content 3'4 Approved Method Annually Hours of 3.5 Recordkeeping Monthly Operation Opacity 3.6 Not to exceed 20% Fuel Restriction—Natural Gas Only 3.See Condition 3.6 Statewide Controls for Oil and Gas 3.7 See Condition 3.7 Operations 40 CFR 60 Subpart Dc 3.8 See Condition 3.8 NSPS 40 CFR 60 Subpart A 3.9 See Condition 3.9 NSPS 3.1 NOx and CO Emission Limitations & Compliance Monitoring Emissions of Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from this heater shall not exceed the limitations listed in Summary Table 3 above. Compliance with the emission limitations shall be monitored as follows: 3.1.1 Monthly determination of NOx and CO emissions shall be conducted by the end of the subsequent month using the emission factors listed in Summary Table 3 above and the monthly natural gas consumption, as required by Condition 3.3, in the equation below: Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 44 lb MMSCF NOx or CO Emissions (month l _ EF (MMSCF x FRFuet (month lmonthl Unit Conversion (2000 lb) ton Where: EF=Emission Factor,lb/MMSCF FRFuet =Flow Rate of Fuel Gas,MMSCF/month Monthly emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data.Records of calculations shall be maintained and made available to the Division upon request. 3.1.2 Facility-wide emissions of Hazardous Air Pollutants (HAP) shall not exceed the annual facility-wide limitations set forth in Condition 11 (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). Monthly emissions of each HAP shall be calculated by the end of the subsequent month using the methods set forth in Condition 11 and used in a twelve month rolling total to monitor compliance with the facility-wide HAP emission limitations. 3.2 Particulate Matter Emission Limitations & Compliance Monitoring Emissions of Particulate Matter(PM)from this heater shall not exceed the limitation required by Colorado Regulation No. 1, Section III.A.1.b. The numeric PM limitation, for the purposes of Colorado Regulation No. 1, Section III.A.I.b., was determined using the design heat rate (fuel input) for this heater in the following equation: PE(MMBtulb \I =0.5 x F/-0.26 Where: PE (MMBtu) =Particulate Emission Fl (MMBtu) =Fuel Input hr In the absence of credible evidence to the contrary, compliance with the particulate matter emission limitation set forth in Colorado Regulation No. 1, Section III.A.I.b. shall be presumed since only natural gas is permitted to be used as fuel for this heater.The permittee shall maintain records that verify that only natural gas is used as fuel. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 45 3.3 Natural Gas Consumption Limitations & Compliance Monitoring Natural gas consumption for this heater shall not exceed the limitations listed in Summary Table 3 above. Facility-wide natural gas consumption shall be recorded on the first day of each month using the facility fuel meter. Allocation of natural gas to this heater shall be determined using the following equation: Btu MMSCF HRHeater MMSCF __ month FCHeater month Btu Btu ( Btu x FCFaciiity r l Engine Heater(( + HRother \month 1 HR (month)+ HR lmonth� lmonth� Where: HREngine ( Btu ) = BSFC ( Btu )x Hours of Operation (month))x Site Rated HP(hp) month) hp hr month HRHeater (month)= Design Heat Rating (B ru)x Hours of Operation (month) And: FCHeater=Individual Heater Fuel Consumption,MMSCF/Month HREngine =Individual Engine Heat Requirement,Btu/Month HRHeater=Individual Heater Heat Requirement,Btu/Month HRother= Other Users Heat Requirement,Btu/Month FCFaciiity=Facility Wide Fuel Consumption(metered),MMSCF/Month BSFC=Brake Specific Fuel Consumption,Btu/hp•hr Monthly natural gas consumption for this heater shall be used in a twelve month rolling total to monitor compliance with the annual limitation. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. Monthly natural gas consumption shall be used to monitor compliance with the NOx and CO emission limitations, as required by Condition 3.1. 3.4 Natural Gas Heat Content Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 46 The heat content of the natural gas used to fuel this heater shall be verified semi-annually using the appropriate ASTM Methods or equivalent, if approved in advance by the Division. The heat content of the natural gas shall be based on the higher heating value (HHV) of the fuel. Results of the heat content verification shall be retained and made available to the Division upon request. The heat content used by the Division in determining the emission limitations listed in Summary Table 3 was 1,040 Btu per standard cubic foot of natural gas. 3.5 Hours of Operation Hours of operation for this heater shall be monitored and recorded monthly. Hours of operation shall be recorded on the first day of each month. Records of the monthly hours of operation shall be maintained and made available to the Division upon request. The hours of operation shall be used to monitor compliance with the natural gas consumption limitation, as required by Condition 3.3. 3.6 Opacity The following opacity requirements apply to this heater: 3.6.1 Except as provided for in Condition 3.6.2 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 (Colorado Regulation No. 1, Section II.A.1). 3.6.2 No owner or operator of a source shall allow or cause to be emitted into the atmosphere any air pollutant resulting from the building of a new fire, cleaning of fire boxes, soot blowing, start-up, process modifications, or adjustment or occasional cleaning of control equipment which is excess of 30% opacity for a period or periods aggregating more than six (6) minutes in any sixty (60) consecutive minutes (Colorado Regulation No. 1, Section II.A.4). 3.6.3 [State-Only Enforceable]: No owner or operator shall discharge, or cause the discharge, into the atmosphere of any particulate matter which is greater than twenty percent(20%)opacity(Colorado Regulation No. 6, Part B, Section II.C.3). Note that this opacity standard applies at all times except during periods of startup, shutdown, and malfunction (40 CFR Part 60, Subpart A, §60.11(c), as adopted by reference in Colorado Regulation No. 6, Part B, Section I.A). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 47 Note that this opacity requirement is more stringent than the opacity requirement in Condition 3.6.2 above during periods of fire building, cleaning of fire boxes, soot blowing, process modification, or adjustment or occasional cleaning of control equipment. In the absence of credible evidence to the contrary, compliance with the opacity limit shall be presumed since only natural gas is permitted to be used as fuel for this heater. The permittee shall maintain records that verify that only natural gas is used as fuel. 3.7 Statewide Controls for Oil and Gas Operations Colorado Regulation No. 7, Part E, Section II. Requirements: This heater is subject to the following requirements of Colorado Regulation No. 7, Part E, Section II, "Control of Emissions from Stationary and Portable Combustion Equipment in the 8-Hour Ozone Control Area": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. Combustion Process Adjustment 3.7.1 As of January 1, 2017, this Section II.A.6. (Condition 3.7.2) applies to boilers, duct burners, process heaters, stationary combustion turbines, and stationary reciprocating internal combustion engines with uncontrolled actual emissions of NOx equal to or greater than five (5)tons per year that existed at major sources of NOx (greater than or equal to 100 tpy NOx) as of June 3, 2016. (Colorado Regulation No. 7, Part E, Section II.A.6.a.(i)). 3.7.2 Combustion Process Adjustment(Colorado Regulation No. 7, Part E, Section II.A.6.b.) 3.7.2.1 When burning the fuel that provides the majority of the heat input since the last combustion process adjustment and when operating at a firing rate typical of normal operation, the owner or operator must conduct the following inspections and adjustments of boilers and process heaters,as applicable(Colorado Regulation No. 7, Part E, Section II.A.6.b.(i)): a. Inspect the burner and combustion controls and clean or replace components as necessary (Colorado Regulation No. 7, Part E, Section II.A.6.b.(i)(A)). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 48 b. Inspect the flame pattern and adjust the burner or combustion controls as necessary to optimize the flame pattern (Colorado Regulation No. 7, Part E, Section II.A.6.b.(i)(B)). c. Inspect the system controlling the air-to-fuel ratio and ensure that it is correctly calibrated and functioning properly (Colorado Regulation No. 7, Part E, Section II.A.6.b.(i)(C)). d. Measure the concentration in the effluent stream of carbon monoxide and nitrogen oxide in ppm,by volume,before and after the adjustments in Sections II.A.6.b.(i)(A) (Condition a above) through (C) (Condition c above). Measurements may be taken using a portable analyzer (Colorado Regulation No. 7, Part E, Section II.A.6.b.(i)(D)). 3.7.2.2 The owner or operator must operate and maintain the boiler, duct burner, process heater, stationary combustion turbine, stationary internal combustion engine, dryer, furnace or ceramic kiln consistent with manufacturer's specifications, if available, or good engineering and maintenance practices (Colorado Regulation No. 7, Part E, Section II.A.6.b.(vii)). 3.7.2.3 Frequency (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)) a. The owner or operator of boilers, duct burners, process heaters, stationary combustion turbines,and stationary reciprocating internal combustion engines with uncontrolled actual emissions of NOx equal to or greater than five (5) tons per year that existed at major sources of NOx(greater than or equal to 100 tpy NOx) as of June 3, 2016, must conduct the initial combustion process adjustment by April 1, 2017. An owner or operator may rely on a combustion process adjustment conducted in accordance with applicable requirements and schedule of a New Source Performance Standard in 40 CFR Part 60 or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 to satisfy the requirement to conduct an initial combustion process adjustment by April 1, 2017 (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)(A)). b. The owner or operator must conduct subsequent combustion process adjustments at least once every twelve(12)months after the initial combustion adjustment, or on the applicable schedule according to Sections II.A.6.c.(i). (Condition 3.7.3.1) or II.A.6.c.(ii). (Condition 3.7.3.2) (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)(C)). Alternative Requirements Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 49 3.7.3 As an alternative to the requirements described in Sections II.A.6.b.(i) (Condition 3.7.2.1) through II.A.6.b.(viii) (Condition 3.7.2.3) (Colorado Regulation No. 7, Part E, Section II.A.6.c.): 3.7.3.1 The owner or operator may conduct the combustion process adjustment according to the manufacturer recommended procedures and schedule(Colorado Regulation No. 7, Part E, Section II.A.6.c.(i)); or 3.7.3.2 The owner or operator of combustion equipment that is subject to and required to conduct a periodic tune-up or combustion adjustment by the applicable requirements of a New Source Performance Standard in 40 CFR Part 60 (December 19,2019) or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 (December 19, 2019) may conduct tune-ups or adjustments according to the schedule and procedures of the applicable requirements of 40 CFR Part 60 (December 19, 2019) or 40 CFR Part 63 (December 19, 2019) (Colorado Regulation No. 7, Part E, Section II.A.6.c.(ii)). Recordkeeping 3.7.4 Recordkeeping. The following records must be kept for a period of five years and made available to the Division upon request(Colorado Regulation No. 7, Part E, Section II.A.7.): 3.7.4.1 For stationary combustion equipment subject to the combustion process adjustment requirements in Section II.A.6. (Condition 3.7.2), the following recordkeeping requirements apply (Colorado Regulation No. 7, Part E, Section ILA.7.f): a. The owner or operator must create a record once every calendar year identifying the combustion equipment at the source subject to Section II.A. (Condition 3.7.1) and including for each combustion equipment (Colorado Regulation No. 7, Part E, Section II.A.7.(f).(i)): (i) The date of the adjustment(Colorado Regulation No. 7,Part E, Section II.A.7.f.(i)(A)); (ii) Whether the combustion process adjustment under Section II.A.6.b.(i) (Condition 3.7.2.1) was followed, and what procedures were performed(Colorado Regulation No. 7,Part E, Section II.A.7.f.(i)(B)); (iii) Whether a combustion process adjustment under Sections II.A.6.c.(i). (Condition 3.7.3.1)and II.A.6.c.(ii).(Condition 3.7.3.2).was followed, what procedures were performed, and what New Source Performance Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 50 or National Emission Standard for Hazardous Air Pollutants applied, if any (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(C)); and (iv) A description of any corrective action taken(Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(D)). (v) If the owner or operator conducts the combustion process adjustment according to the manufacturer recommended procedures and schedule and the manufacturer specifies a combustion process adjustment on an operation time schedule, the hours of operation. (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(E)). b. The owner or operator must retain manufacturer recommended procedures, specifications, and maintenance schedule if utilized under Section II.A.6.c.(i). (Condition 3.7.3.1) for the life of the equipment (Colorado Regulation No. 7, Part E, Section II.A.7.f.(ii)). c. As an alternative to the requirements described in Section II.A.7.f.(i) (Condition a above), the owner or operator may comply with applicable recordkeeping requirements related to combustion process adjustments conducted according to a New Source Performance Standard in 40 CFR Part 60 or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 (Colorado Regulation No. 7, Part E, Section II.A.7.f.(iii)). 3.8 40 CFR Part 60 Subpart Dc NSPS This heater is subject to the New Source Performance Standards requirements of Colorado Regulation No. 6, Part A, Subpart Dc (40 CFR Part 60, Subpart Dc) "Standards of Performance for Small Industrial- Commercial-Institutional Steam Generating Units", including, but not limited to, the following: The requirements below reflect the current rule language as of the revisions to 40 CFR Part 60 Subpart Dc published in the Federal Register on 2/16/2012. However, if revisions to this Subpart are published at a later date, the owner or operator is subject to the requirements contained in the revised version of 40 CFR Part 60 Subpart Dc. Reporting and Recordkeeping Requirements 3.8.1 Except as provided under paragraphs(g)(2) (Condition 3.8.2)of this section,the owner or operator of each affected facility shall record and maintain records of the amount of each fuel combusted during each operating day (§60.48c(g)(1)). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 51 3.8.2 As an alternative to meeting the requirements of paragraph(g)(1) (Condition 3.8.1)of this section, the owner or operator of an affected facility that combusts only natural gas, wood, fuels using fuel certification in §60.48c(f) to demonstrate compliance with the SO2 standard, fuels not subject to an emissions standard (excluding opacity), or a mixture of these fuels may elect to record and maintain records of the amount of each fuel combusted during each calendar month (§60.48c(g)(2)). 3.9 40 CFR Part 60 Subpart A NSPS This heater is subject to the requirements in 40 CFR Part 60 Subpart A "General Provisions", as adopted by reference in Colorado Regulation No. 6, Part A, Subpart A as specified in 40 CFR Part 60 Subpart Dc. These requirements include, but are not limited to the following: 3.9.1 Notification and recordkeeping (§60.7(b)) 3.9.2 Compliance with standards and maintenance requirements (§60.11(d)) 3.9.3 Circumvention (§60.12) Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 52 4. P-132—Born Natural Gas Fired 15.0 MMBtu/hr Hot Oil Heater,AIRS ID: 113 Parameter Permit Compliance Limits Compliance Monitoring Condition Emission Number Factor Method Interval Emission&Consumption Limits NOx 6.32 tons/year 100 lb/MMSCF Recordkeeping and 4.1 Twelve Month Rolling Monthly CO 5.31 tons/year 84 lb/MMSCF Total Calculation PM 4.2 Fuel Restriction—Natural Gas Only Fuel Meter and Natural Gas 4.3 126.35 MMSCF/year Twelve Month Rolling Monthly Consumption Total Calculation Other Requirements Natural Gas ASTM or other Semi- Heat Content 4.4 Division Approved Annually Method Flours of 4.5 Recordkeeping Monthly Operation Opacity 4.6 Not to exceed 20% Fuel Restriction—Natural Gas Only 4.See Condition 4.6 Statewide Controls for 4.7 See Condition 4.7 Oil and Gas Operations 40 CFR 60 Subpart A 4.8 See Condition 4.8 NSPS General Provisions 4.1 NOx and CO Emission Limitations & Compliance Monitoring Emissions of Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from this heater shall not exceed the limitations listed in Summary Table 4 above (Colorado Construction Permit 90WE514-2, as modified under the provisions of Section I, Condition 1.3). Compliance with the emission limitations shall be monitored as follows: Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 53 4.1.1 Monthly determination of NOx and CO emissions shall be conducted by the end of the subsequent month using the emission factors listed in Summary Table 4 above and the monthly natural gas consumption, as required by Condition 4.3, in the equation below: lb MMSCF r tons l_ EF (MMSCF x FRFUei (month NOx or CO Emissions \month/ Unit Conversion (2000 Ib) ton Where: EF=Emission Factor,lb/MMSCF FR Fuel =Flow Rate of Fuel Gas,MMSCF/month Monthly emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data.Records of calculations shall be maintained and made available to the Division upon request. 4.1.2 Facility-wide emissions of Hazardous Air Pollutants (HAP) shall not exceed the annual facility-wide limitations set forth in Condition 11 (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). Monthly emissions of each HAP shall be calculated by the end of the subsequent month using the methods set forth in Condition 11 and used in a twelve month rolling total to monitor compliance with the facility-wide HAP emission limitations. 4.2 Particulate Matter Emission Limitations & Compliance Monitoring Emissions of Particulate Matter(PM)from this heater shall not exceed the limitation required by Colorado Regulation No. 1, Section III.A.1.b. The numeric PM limitation, for the purposes of Colorado Regulation No. 1, Section III.A.1.b., listed in the table above was determined using the design heat rate (fuel input) for this heater in the following equation: PE( lb ll _ MMBtu/ = 0.5 x F1-°26 Where: PE ( lb ll MMBtu I=Particulate Emission MMBtu) =Fuel Input hr Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 54 In the absence of credible evidence to the contrary, compliance with the particulate matter emission limitation set forth in Colorado Regulation No. 1, Section III.A.1.b. shall be presumed since only natural gas is permitted to be used as fuel for this heater.The permittee shall maintain records that verify that only natural gas is used as fuel. 4.3 Natural Gas Consumption Limitations & Compliance Monitoring Natural gas consumption for this heater shall not exceed the limitations listed in Summary Table 4 above (Colorado Construction Permit 90WE514-2,as modified under the provisions of Section I,Condition 1.3). Facility-wide natural gas consumption shall be recorded on the first day of each month using the facility fuel meter. Allocation of natural gas to this heater shall be determined using the following equation: Btu MMSCF HRHeater( ) MMSCF __ month l FCyeater month (month) + ( Btu / Btu )x FC • Facliity (month) HR Engine month) HRHeater(month)+E HRother`month Where: HREngine ( Btu ) = BSFC ( Btu )x Hours of Operation (month))x Site Rated HP(hp) month) hp•hr month Btu Btu hr HRHeater (month) = Design Heat Rating (hr)x Hours of Operation (month) And: FCyeater=Individual Heater Fuel Consumption,MMSCF/Month HREngine =Individual Engine Heat Requirement,Btu/Month HRHeater=Individual Heater Heat Requirement,Btu/Month HRother= Other Users Heat Requirement,Btu/Month FCFacility =Facility Wide Fuel Consumption(metered),MMSCF/Month BSFC=Brake Specific Fuel Consumption,Btu/hp•hr Monthly natural gas consumption for this heater shall be used in a twelve month rolling total to monitor compliance with the annual limitation. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 55 Monthly natural gas consumption shall be used to monitor compliance with the NOx and CO emission limitations, as required by Condition 4.1. 4.4 Natural Gas Heat Content The heat content of the natural gas used to fuel this heater shall be verified semi-annually using the appropriate ASTM Methods or equivalent, if approved in advance by the Division. The heat content of the natural gas shall be based on the higher heating value (HHV) of the fuel. Results of the heat content verification shall be retained and made available to the Division upon request. The heat content used by the Division in determining the emission limitations listed in Summary Table 4 was 1,040 Btu per standard cubic foot of natural gas. 4.5 Hours of Operation Hours of operation for this heater shall be monitored and recorded monthly. Hours of operation shall be recorded on the first day of each month. Records of the monthly hours of operation shall be maintained and made available to the Division upon request. The hours of operation shall be used to monitor compliance with the natural gas consumption limitation, as required by Condition 4.3. 4.6 Opacity The following opacity requirements apply to this heater: 4.6.1 Except as provided for in Condition 4.6.2 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 (Colorado Regulation No. 1, Section II.A.1). 4.6.2 No owner or operator of a source shall allow or cause to be emitted into the atmosphere any air pollutant resulting from the building of a new fire, cleaning of fire boxes, soot blowing, start-up, process modifications, or adjustment or occasional cleaning of control equipment which is excess of 30%opacity for a period or periods aggregating more than six (6)minutes in any sixty (60) consecutive minutes (Colorado Regulation No. 1, Section II.A.4). 4.6.3 [State-Only Enforceable]:No owner or operator shall discharge,or cause the discharge, into the atmosphere of any particulate matter which is greater than twenty percent (20%) opacity (Colorado Regulation No. 6, Part B, Section II.C.3). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 56 Note that this opacity standard applies at all times except during periods of startup, shutdown, and malfunction (40 CFR Part 60, Subpart A, §60.11(c), as adopted by reference in Colorado Regulation No. 6, Part B, Section I.A). Note that this opacity requirement is more stringent than the opacity requirement in Condition 4.6.2 above during periods of fire building, cleaning of fire boxes, soot blowing, process modification, or adjustment or occasional cleaning of control equipment. In the absence of credible evidence to the contrary, compliance with the opacity limit shall be presumed since only natural gas is permitted to be used as fuel for this heater. The permittee shall maintain records that verify that only natural gas is used as fuel. 4.7 Statewide Controls for Oil and Gas Operations Colorado Regulation No. 7, Part E, Section II. Requirements: This heater is subject to the following requirements of Colorado Regulation No. 7, Part E, Section II, "Control of Emissions from Stationary and Portable Combustion Equipment in the 8-Hour Ozone Control Area": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit,but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. Combustion Process Adjustment 4.7.1 As of January 1, 2017, this Section II.A.6. (Condition 4.7.2) applies to boilers, duct burners, process heaters, stationary combustion turbines, and stationary reciprocating internal combustion engines with uncontrolled actual emissions of NOx equal to or greater than five (5)tons per year that existed at major sources of NOx(greater than or equal to 100 tpy NOx) as of June 3, 2016. (Colorado Regulation No. 7, Part E, Section II.A.6.a.(i)). 4.7.2 Combustion Process Adjustment (Colorado Regulation No. 7, Part E, Section II.A.6.b.) 4.7.2.1 When burning the fuel that provides the majority of the heat input since the last combustion process adjustment and when operating at a firing rate typical of normal operation, the owner or operator must conduct the following inspections and adjustments of boilers and process heaters,as applicable(Colorado Regulation No. 7, Part E, Section II.A.6.b.(i)): Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 57 a. Inspect the burner and combustion controls and clean or replace components as necessary (Colorado Regulation No. 7, Part E, Section II.A.6.b.(i)(A)). b. Inspect the flame pattern and adjust the burner or combustion controls as necessary to optimize the flame pattern (Colorado Regulation No. 7, Part E, Section II.A.6.b.(i)(B)). c. Inspect the system controlling the air-to-fuel ratio and ensure that it is correctly calibrated and functioning properly (Colorado Regulation No. 7, Part E, Section II.A.6.b.(i)(C)). d. Measure the concentration in the effluent stream of carbon monoxide and nitrogen oxide in ppm,by volume,before and after the adjustments in Sections II.A.6.b.(i)(A) (Condition a above) through (C) (Condition c above). Measurements may be taken using a portable analyzer (Colorado Regulation No. 7, Part E, Section II.A.6.b.(i)(D)). 4.7.2.2 The owner or operator must operate and maintain the boiler, duct burner, process heater, stationary combustion turbine, stationary internal combustion engine, dryer, furnace or ceramic kiln consistent with manufacturer's specifications, if available, or good engineering and maintenance practices (Colorado Regulation No. 7, Part E, Section II.A.6.b.(vii)). 4.7.2.3 Frequency (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)) a. The owner or operator of boilers, duct burners, process heaters, stationary combustion turbines,and stationary reciprocating internal combustion engines with uncontrolled actual emissions of NOx equal to or greater than five (5) tons per year that existed at major sources of NOx(greater than or equal to 100 tpy NOx) as of June 3, 2016, must conduct the initial combustion process adjustment by April 1, 2017. An owner or operator may rely on a combustion process adjustment conducted in accordance with applicable requirements and schedule of a New Source Performance Standard in 40 CFR Part 60 or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 to satisfy the requirement to conduct an initial combustion process adjustment by April 1, 2017 (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)(A)). b. The owner or operator must conduct subsequent combustion process adjustments at least once every twelve(12)months after the initial combustion adjustment, or on the applicable schedule according to Sections II.A.6.c.(i). (Condition 4.1.3.1) or II.A.6.c.(ii). (Condition 4.7.3.2) (Colorado Regulation No. 7, Part E, Section II.A.6.b.(viii)(C)). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 58 Alternative Requirements 4.7.3 As an alternative to the requirements described in Sections II.A.6.b.(i) (Condition 4.7.2.1) through II.A.6.b.(viii) (Condition 4.7.2.3) (Colorado Regulation No. 7, Part E, Section II.A.6.c.): 4.7.3.1 The owner or operator may conduct the combustion process adjustment according to the manufacturer recommended procedures and schedule (Colorado Regulation No. 7, Part E, Section II.A.6.c.(i)); or 4.7.3.2 The owner or operator of combustion equipment that is subject to and required to conduct a periodic tune-up or combustion adjustment by the applicable requirements of a New Source Performance Standard in 40 CFR Part 60 (December 19, 2019)or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 (December 19, 2019) may conduct tune-ups or adjustments according to the schedule and procedures of the applicable requirements of 40 CFR Part 60 (December 19, 2019) or 40 CFR Part 63 (December 19, 2019) (Colorado Regulation No. 7, Part E, Section II.A.6.c.(ii)). Recordkeeping 4.7.4 Recordkeeping. The following records must be kept for a period of five years and made available to the Division upon request (Colorado Regulation No. 7, Part E, Section II.A.7.): 4.7.4.1 For stationary combustion equipment subject to the combustion process adjustment requirements in Section II.A.6. (Condition 4.7.2), the following recordkeeping requirements apply (Colorado Regulation No. 7, Part E, Section II.A.7.f): a. The owner or operator must create a record once every calendar year identifying the combustion equipment at the source subject to Section II.A. (Condition 4.7.1) and including for each combustion equipment (Colorado Regulation No. 7, Part E, Section II.A.7.(f).(i)): (i) The date of the adjustment(Colorado Regulation No. 7,Part E, Section II.A.7.f.(i)(A)); (ii) Whether the combustion process adjustment under Section II.A.6.b.(i) (Condition 4.7.2.1) was followed, and what procedures were performed(Colorado Regulation No. 7,Part E, Section II.A.7.f.(i)(B)); (iii) Whether a combustion process adjustment under Sections II.A.6.c.(i) (Condition 4.7.3.1) and II.A.6.c.(ii) (Condition 4.7.3.2).was followed, Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 59 what procedures were performed, and what New Source Performance or National Emission Standard for Hazardous Air Pollutants applied, if any (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(C)); and (iv) A description of any corrective action taken(Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(D)). (v) If the owner or operator conducts the combustion process adjustment according to the manufacturer recommended procedures and schedule and the manufacturer specifies a combustion process adjustment on an operation time schedule,the hours of operation. (Colorado Regulation No. 7, Part E, Section II.A.7.f.(i)(E)). b. The owner or operator must retain manufacturer recommended procedures, specifications,and maintenance schedule if utilized under Section II.A.6.c.(i). (Condition 4.7.3.1) for the life of the equipment (Colorado Regulation No. 7, Part E, Section II.A.7.f.(ii)). c. As an alternative to the requirements described in Section II.A.7.f.(i) (Condition a above), the owner or operator may comply with applicable recordkeeping requirements related to combustion process adjustments conducted according to a New Source Performance Standard in 40 CFR Part 60 or National Emission Standard for Hazardous Air Pollutants in 40 CFR Part 63 (Colorado Regulation No. 7, Part E, Section II.A.7.f.(iii)). 4.8 40 CFR Part 60 Subpart A General Provisions [State-Only Enforceable]: This heater is subject to the requirements in Colorado Regulation No. 6, Part B, Section I.A. Specifically, this unit is subject to the following requirements: 4.8.1 Any owner or operator subject to the provisions of this part shall maintain records of the occurrence and duration of any startup, shutdown, or malfunction in the operation of an affected facility;any malfunction of the air pollution control equipment;or any periods during which a continuous monitoring system or monitoring device is inoperative (§60.7(b), as adopted by reference in Colorado Regulation No. 6, Parts A, Subparts A and B, Section I.A). 4.8.2 At all times, including periods of startup, shutdown, and malfunction, owners and operators shall,to the extent practicable,maintain and operate any affected facility including associated air pollution control equipment in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Administrator which Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 60 may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source (§60.11(d), as adopted by reference in Colorado Regulation No. 6, Parts A, Subparts A and B, Section I.A). 4.8.3 No owner or operator subject to the provisions of this part shall build,erect, install, or use any article, machine, equipment or process, the use of which conceals an emission which would otherwise constitute a violation of an applicable standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based on the concentration of a pollutant in the gases discharged to the atmosphere (§60.12, as adopted by reference in Colorado Regulation No. 6, Parts A, Subpart A and B, Section I.A). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 61 5. P-133—Fugitive Emissions from Fractionation and Natural Gas Liquids (NGL) Processing Plants, AIRS ID: 114 Permit Monitoring Parameter Condition Compliance Limits Compliance Emission Factor Number Method Interval Emission Limits VOC 5.1 By Component-EPA Protocol Recordkeeping and 10.4 tons/year for Equipment Leak Estimates Calculation Annually Other Requirements Running Total and Component Count 5.2 See Condition 5.2 Hard Count Extended Gas Analysis 5.3 ASTM Methods or Annually Equivalent Statewide Controls for Oil Complies by meeting 40 CFR 60 Subpart OOOO NSPS 5.4 and Gas Operations See Condition 5.4 40 CFR Part 60 Subpart 5.5 See Condition 5.5 KKK NSPS 40 CFR Part 60 Subpart 5.6 See Condition 5.6 OOOO NSPS 40 CFR Part 60 Subpart A 5.7 See Condition 5.7 NSPS 5.1 VOC Emission Limitations & Compliance Monitoring Emissions of Volatile Organic Compounds (VOC) from equipment leaks shall not exceed the limitation listed in Summary Table 5 above (Colorado Construction Permit 90WE048-1, as modified under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part B, Section II.A.6 and Part C, Section X based on requested emissions identified on the APEN submitted on 12/20/2019). Compliance with the emission limitation shall be monitored as follows: 5.1.1 The following emission factors to be used in the listed equations are derived from the Total Organic Compound (TOC) Emission Factors (EF) for individual types of components in Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 62 lb/component-hr (EPA - 453/R 95-017, "EPA's Protocol for Equipment Leak Emission Estimates", Table 2-4,November 1995). Emission Factors (lb/component-hr) Component Gas Service Light Liquid Heavy Liquid Connectors 4.41 x 10-4 4.63 x 10-4 1.65 x 10-5 Flanges 8.60 x 10-4 2.43 x 10-4 8.60 x 10-7 Open-Ends 4.41 x 10-3 3.09 x 10-3 3.09 x 10-4 Pump Seals 5.29 x 10-3 2.87 x 10.2 N/A Valves 9.92 x 10-3 5.51 x 10-3 1.85 x 10-5 Other* 1.94 x 10-2 1.65 x 10-2 7.05 x 10-5 *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms,hatches,instruments,meters,polished rods,and vents. 5.1.2 The following component-specific control factors have been approved by the Division for use in determining compliance with the annual emission limitations for fugitive emissions at this facility (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part B, Section II.A.6 and Part C, Section X based on requested emissions identified on the APEN submitted on 12/20/2019): Control Factor Component Gas Light Liquid Heavy Liquid Connectors 81% 81% 30% Flanges 81% 81% 30% Open-Ends N/A N/A N/A Pump Seals N/A 88% 75% Valves 96% 95% 75% Other* 75% 75% 75% *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms,hatches,instruments,meters,polished rods,and vents. 5.1.3 Monthly determination of VOC emissions shall be calculated by the end of the subsequent month using the appropriate emission factors (EF), as required by Condition 5.1.1, control factors (CF), as required by Condition 5.1.2, the values from the most recent component Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 63 count,as required by Condition 5.2,and the most recent extended gas analysis,as required by Condition 5.3, in the equation below: 8,760 hrs lb ( _CF(%)) VOC Content(wt%) x Component Count(qty)x Operating Hours tons ( year x EF((component—hr)x 1 100 J VOC Emissions l year/ Unit Conversion ( r2000 lb) ri Total fugitive emissions shall be the sum of emissions from each component type for each applicable service. Records of this calculation shall be maintained and made available to the Division upon request. 5.1.4 Facility-wide emissions of Hazardous Air Pollutants (HAP) shall not exceed the annual facility-wide limitations set forth in Condition 11 (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). Monthly emissions of each HAP shall be calculated by the end of the subsequent month using the same method as indicated above for VOC, except that the HAP content indicated by the most recent extended gas analysis,as required by Condition 5.3, shall replace the VOC content in the equation above. Calculated monthly emissions of each HAP shall be used in a twelve month rolling total to monitor compliance with the facility-wide HAP emission limitations. 5.2 Component Count A physical hard-count of facility components shall be conducted at least once every five years. This hard count shall distinguish between components in gas, light liquid and heavy liquid services. In the interim, a running total of all additions and subtractions to the component count shall be maintained. The hard component count and running total of all component additions/subtractions shall be made available for the Division upon request. The most recent running total component count, in conjunction with the most recent five-year hard count shall be used to monitor compliance with the VOC emission limitation, as required by Condition 5.1. 5.3 Extended Gas Analysis An extended gas analysis of the plant inlet gas shall be performed according to appropriate ASTM approved methods, or equivalent, if approved in advance by the Division, at least once per calendar year. The dates of the annual inlet gas analyses shall be separated by at least two calendar months.The extended gas analysis shall identify the relevant VOC and HAP constituents of the wet gas, including any BTEX components. Results of the wet gas analysis shall be maintained and made available to the Division upon request. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 64 The VOC content(weight%)obtained from the most recent extended gas analysis shall be used to monitor compliance with the VOC emission limitation, as required by Condition 5.1. For components in light and heavy liquid service, it is permissible to assume that fugitive emissions are composed of 100%VOC and are of the same HAP composition as indicated on the extended analysis for the inlet gas sample. 5.4 Statewide Controls for Oil and Gas Operations Colorado Regulation No. 7, Part D, Section I.G. Requirements: This facility is subject to the following requirements for gas-processing plants located in the 8-hour Ozone Control Area of Colorado Regulation No. 7, Part D, Section I, "Volatile Organic Compound Emissions from Oil and Gas Operations", as required by Condition 12.2.1: 5.4.1 For fugitive volatile organic compound emissions from leaking equipment,the leak detection and repair (LDAR) program as provided at 40 CFR Part 60, Subpart OOOO (July 1, 2017; Condition 5.6) applies, regardless of the date of construction of the affected facility, unless subject to the LDAR program provided at 40 CFR Part 60, Subpart 0000a (July 1, 2017). (Colorado Regulation No. 7, Part D, Section I.G.1.). 5.4.2 Natural gas processing plants within the 8-hour Ozone Control Area constructed before January 1, 2018 must comply with the requirements of Section I.G. (Condition 5.4.1) beginning January 1, 2019 (Colorado Regulation No. 7, Part D, Section I.G.3.). 5.5 40 CFR Part 60 Subpart KKK NSPS This facility, with respect to fugitive emissions, is subject to the New Source Performance Standards requirements of Colorado Regulation No. 6, Part A, Subpart KKK (40 CFR Part 60, Subpart KKK) "Standards of Performance for Equipment Leaks of VOC From Onshore Natural Gas Processing Plants for Which Construction, Reconstruction or Modification Commenced After January 20, 1984, and on or Before August 23, 2011", including, but not limited to, the following: The requirements below reflect the current rule language as of the revisions to 40 CFR Part 60 Subpart KKK published in the Federal Register on 8/16/2012. However, if revisions to this Subpart are published at a later date,the owner or operator is required to comply with the requirements contained in the revised version of 40 CFR Part 60 Subpart KKK. 5.5.1 For all equipment types, except for affected compressors only, compliance with NSPS KKK is presumed, provided the requirements of NSPS OOOO (Condition 5.6) are met. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 65 5.5.2 Affected compressors only are subject to the following applicable requirements: 5.5.2.1 Standards, as required by §60.632 5.5.2.2 Exceptions, as required by §60.633 5.5.2.3 Recordkeeping Requirements, as required by §60.635 5.5.2.4 Reporting Requirements, as required by §60.636 5.6 40 CFR Part 60 Subpart OOOO NSPS This facility, with respect to fugitive emissions, is required to comply with the New Source Performance Standards requirements of Colorado Regulation No. 6, Part A, Subpart OOOO (40 CFR Part 60, Subpart OOOO) "Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution for which Construction, Modification or Reconstruction Commenced After August 23, 2011, and on or before September 18, 2015", as required by Condition 5.4.1, including, but not limited to, the following: The requirements below reflect the current rule language as of the revisions to 40 CFR Part 60 Subpart OOOO published in the Federal Register on 6/3/2016. However, if revisions to this Subpart are published at a later date,the owner or operator is required to comply with the requirements contained in the revised version of 40 CFR Part 60 Subpart OOOO. This facility is subject to the following applicable requirements: 5.6.1 At all times, including periods of startup, shutdown, and malfunction, owners and operators shall maintain and operate any affected facility including associated air pollution control equipment in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Administrator which may include but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source (§60.5370(b)). 5.6.2 Equipment leak standards applicable to affected facilities at an onshore natural gas processing plant (§60.5400). 5.6.3 Exceptions to the equipment leak standards for affected facilities at an onshore natural gas processing plant(§60.5401). Operating Permit Number: 950PWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 66 5.6.4 Alternative emission limitations for equipment leaks from onshore natural gas processing plants (§60.5402). 5.6.5 Continuous compliance demonstration with the standards for affected facilities at onshore natural gas processing plants (§60.5415(f)). 5.6.6 Recordkeeping Requirements for affected facilities subject to VOC requirements for onshore natural gas processing plants (§60.5421). 5.6.7 Reporting Requirements for affected facilities subject to VOC requirements for onshore natural gas processing plants (§60.5422). 5.7 40 CFR Part 60 Subpart A NSPS This facility, with respect to fugitive emissions, is subject to the requirements in 40 CFR Part 60 Subpart A "General Provisions", as adopted by reference in Colorado Regulation No. 6, Part A, Subpart A as specified in 40 CFR Part 60 Subpart KKK and Subpart OOOO. These requirements include, but are not limited to the following: 5.7.1 §60.7—Notification and recordkeeping 5.7.2 §60.12—Circumvention 5.7.3 §60.17-Incorporations by reference 5.7.4 §60.19—General notification and reporting requirements Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 67 6. P-135—Pressurized Product Truck Loadout Rack,AIRS ID: 115 Permit Monitoring Parameter Condition Compliance Limits Compliance Emission Factor Number Method Interval Emission&Throughput Limits Propane: 1.11 lb/load Butane: 1.21 lb/load Isopentane: 1.29 lb/load VOC 6.1 43.15 tons per year B-G Mix: 1.52 lb/load Recordkeeping and Twelve Y-Grade: 1.53 lb/load Month Rolling Monthly NGL: 1.52 lb/load Total Calculation Condensate: 1.55 lb/load Product 6.2 55,7181oads/year 100% Condensate used as worst Throughput case scenario Other Requirements Extended ASTM Methods Every 5 Liquids 6.3 or Equivalent years Analysis Maintenance 6 4 Maintenance Per Plan Plan Plan 6.1 VOC Emission Limitations & Compliance Monitoring Emissions of Volatile Organic Compounds (VOC) from the pressurized truck loadout rack shall not exceed the limitation listed in Summary Table 6 above (Colorado Construction Permit 90WE048-2, as modified under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3,Part C, Section I.A.7 and Part C, Section 11I.8.7 based on requested emissions identified on the APEN submitted on 12/20/2019). Compliance with the emission limitation shall be monitored as follows: 6.1.1 Monthly determination of VOC emissions shall be calculated by the end of the subsequent month using the above emission factors and the methodology specified below: 6.1.1.1 The following parameters shall be input to the equation below: Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit#95OPWE038 Page 68 a. The number of trucks loading/unloading each species (propane, butane, isopentane, B-G mix, Y-grade, NGL and condensate), as required by Condition 6.2. b. The VOC content of each species loaded/unloaded, according to the table below: Species Transferred VOC Content Propane 100% Butane 100% Isopentane 100% B-G Mix Y-Grade See Condition 6.3 NGL Condensate 6.1.1.2 Monthly VOC emissions shall be calculated via the following equation: (truck lb tons Ni i lmonth� x EF�,i (truck x xi VOC Emissions (month = (2000 lb) Each Service Unit Conversion . ton Where: Ni=Number of trucks loaded/unloaded for each species,i,truck/month EF i=Loading/unloading emission factor for each species,i,lb/load xi =VOC content for each species,i,mass fraction i=Service designation(propane,butane,isopentane,BG mix,Ygrade,NGL,condensate) Monthly VOC emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 6.1.2 Facility-wide emissions of Hazardous Air Pollutants (HAP) shall not exceed the annual facility-wide limitations set forth in Condition 11 (as provided for under the provisions of Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 69 Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). Monthly emissions of each HAP shall be calculated by the end of the subsequent month using the same method as indicated above for VOC, except that the HAP content, as indicated in the table below, shall replace the VOC content in the equation above. Calculated monthly emissions of each HAP shall be used in a twelve month rolling total to monitor compliance with the facility-wide HAP emission limitations. Species Transferred L HAP Content Propane 0% Butane 0% Isopentane 0% B-G Mix Y-Grade See Condition 6.3 NGL Condensate 6.2 Pressurized Loading Throughput Limitations & Compliance Monitoring The number of trucks loaded/unloaded each month at the pressurized liquid loadout shall not exceed the limitation listed in Summary Table 6 above (Colorado Construction Permit 90WE048-2, as modified under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7 based on requested emissions identified on the APEN submitted on 12/20/2019). Sales or haul tickets from each loading operation shall be used to monitor the number of trucks loaded/unloaded during each month. Additionally,the type of product species loaded/unloaded (propane, butane, isopentane, B-G mix, Y-grade,NGL or condensate) shall be recorded for each loading/unloading event, and shall be made available to the Division upon request. The total number of trucks loaded/unloaded each month shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. The number of trucks loaded/unloaded each month, as indicated by the sales or haul tickets, shall be used to monitor compliance with the VOC emission limitation, as required by Condition 6.1. 6.3 Extended Liquids Analysis of Loaded Products Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 70 An initial extended liquids analysis of each of the B-G mix, Y-grade, NGL and condensate shall be obtained within five (5)years of permit issuance according to appropriate ASTM methods, or equivalent, if approved in advance by the Division. Thereafter, extended liquids analyses of each of the B-G mix, Y- grade, NGL and condensate shall be performed every five (5) years from the previous sample date for each species. The extended liquids analysis shall identify the relevant VOC and HAP constituents of the species loaded/unloaded, including any BTEX components. The composition indicated on each analysis may be used as a representative composition for all loading/unloading of that species completed over the next five years from the date on which the sample was taken. Records of the extended liquids analyses shall be maintained and made available to the Division upon request. The VOC mass fraction of the B-G mix, Y-grade, NGL and condensate shall be used to monitor compliance with the annual VOC emission limitation, as required by Condition 6.1. 6.4 Maintenance Plan A maintenance plan shall be developed that outlines the procedures to locate and repair equipment leaks to minimize the fugitive volatile organic compound emissions. The plan shall be kept on-site and made available for Division review upon request. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 71 7. P-130—Ethylene Glycol Dehydration Unit, AIRS ID: 111 Permit Compliance Monitoring Parameter Condition Limitations Emission Number Factor Method Interval Emission&Throughput Limits GLYCaIc 4.0 Process Simulation and VOC 7.1 0.2 tons/year or higher Twelve Month Rolling Monthly Total Calculation Total: 12,045 MMSCF/year VRU Downtime:Not to exceed 5%of total actual Inlet Meter and Wet Gas 7.2 throughput Twelve Month Rolling Monthly Throughput Total Calculation ECD Downtime:Not to exceed 5%of total actual throughput Lean Glycol Meter and 7.3 6.0 gallons/minute Daily Circulation Rate Recordkeeping Other Requirements Extended Gas 7 4 ASTM Methods or Annually Analysis Equivalent Parametric 7.5 Recordkeeping Weekly Monitoring Hours of Operation 7.6 Recordkeeping Monthly Not to exceed 30%for a period or periods Opacity 7.7 aggregating more than six(6)minutes in any See Condition 7.7 sixty(60)consecutive minutes Control Device 7.8 See Condition 7.8 Requirements Alternative Operating Scenario 7.9 See Condition 7.9 (AOS) Statewide Controls for Oil and Gas 7.10 See Condition 7.10 Operations 7.1 VOC Emission Limitations & Compliance Monitoring Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 72 Emissions of Volatile Organic Compounds(VOC)for this dehydration unit shall not exceed the limitation listed in Summary Table 7 above (Colorado Construction Permit 15WE0939). Compliance with the emission limitation shall be monitored as follows: 7.1.1 Monthly determination of VOC emissions shall be conducted by the end of the subsequent month utilizing the Gas Research Institute's GLYCaic (Version 4.0 or higher) (Colorado Construction Permit 15WE0939). 7.1.1.1 The following parameters shall be input to the process model: a. The inlet wet gas composition obtained from the most recent extended gas analysis, as required by Condition 7.4. b. The average daily inlet wet gas throughput, as required by Condition 7.2.1. c. The average monthly value of the lean glycol circulation rate, as required by Condition 7.3, and the inlet wet gas temperature and pressure, the cold separator operating temperature and pressure and the flash tank operating temperature and pressure, as required by Condition 7.5. 7.1.1.2 Control Efficiencies a. A control efficiency (CE) of 95% shall apply to the enclosed combustion device (ECD)when it is operational and emissions from the dehydration unit are routed to it, provided the requirements of Conditions 7.8.2, 7.10.1.1 and 7.10.2.1 are met. 7.1.1.3 Operating Hours a. Hours of vapor recovery unit (VRU) downtime, as required by Condition 7.6.2, shall be input to the equation below, along with the corresponding control efficiency (CE)of 95%for the ECD,to determine actual emissions of VOC during periods of VRU downtime, in which the flash tank emissions are routed to the ECD. b. Total hours of operation for this dehydration unit, as required by Condition 7.6.1, and hours of ECD downtime, as required by Condition 7.6.3, shall be input to the equation below, along with the corresponding control efficiency (CE) of 95% for the ECD, to determine actual emissions of VOC during periods of ECD operation, in which still vent emissions are routed to the ECD. c. Hours of ECD downtime, as required by Condition 7.6.3, shall be input to the equation below, to determine actual still vent emissions of VOC during periods of ECD downtime, in which still vent emissions are routed to atmosphere. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit. Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 73 d. Hours of concurrent downtime, during which both the VRU and ECD are experiencing downtime, as required by Condition 7.6.4, shall be input to the equation below,to determine actual flash tank emissions of VOC during periods of concurrent VRU and ECD downtime, in which flash tank emissions are routed to atmosphere. 7.1.1.4 Monthly emissions of VOC shall be monitored using the following equations: tons l tons l tons l VOC Emissions (month/ =Flash Gas Emissions (month)+Still Vent Emissions (month) Where: lb ( hrs tons l _ FGvoc (hr)x DTVRU+ECD)month) Flash Gas Emissions (month/ (2000 Ib + Unit Conversion ton ) lb (1 100 hrs l _CE(%)) FGvoc (hr)x DTvRumonth)x Unit Conversion (2000 lb 1 ton 1 lb ( hrs l tons l = SVvoc (hr)x DTECD )month) Still Vent Emissions (month) 2000 lb + Unit Conversion ( ton ) lb hrs ( hrs ( CE(%)) SVvoc (hr)x [[OHEG month)— DTEC°lmonth)i x 1— 100 Unit Conversion (2000 Lb) ton And: FGvoc= Uncontrolled Flash Gas Emissions of VOC,lb/hr SVvoc= Uncontrolled Still Vent Emissions of VOC,lb/hr OHEG =Total Dehydration Unit Operating Hours,hrs/month DTvRu =VRU—Only Downtime,hrs/month DTEC° =ECD Downtime,hrs/month DTvRU+ecD =Concurrent ECD and VRU Downtime,hrs/month Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 74 CE=Control Efficiency of ECD,95% The monthly VOC emissions obtained from this calculation shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 7.1.2 Facility-wide emissions of Hazardous Air Pollutants (HAP) shall not exceed the annual facility-wide limitations set forth in Condition 11 (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). Monthly emissions of each HAP shall be calculated by the end of the subsequent month using the same method as indicated above for VOC, except that the flash gas and still vent HAP emissions obtained from the most recent process model run,as required by Condition 7.1.1, shall replace the flash gas and still vent VOC emissions in the equations above. Calculated monthly emissions of each HAP shall be used in a twelve month rolling total to monitor compliance with the facility-wide HAP emission limitations. 7.2 Wet Gas Throughput Limitations & Compliance Monitoring 7.2.1 Total Wet Gas Throughput: The total amount of wet gas processed by this dehydration unit shall not exceed the limitations listed in Summary Table 7 above (Colorado Construction Permit 15WE0939). The gas throughput to this dehydration unit shall be monitored and recorded monthly using the flowmeter located at the facility inlet. The monthly wet gas throughput shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. An average daily gas throughput rate shall be used as an input to the monthly process model run, as required by Condition 7.1. This average daily gas throughput rate shall be calculated by dividing the total monthly wet gas throughput by the total unit hours of operation, as required by Condition 7.6.1, as follows: MMSCF Total Monthly Gas Throughput month)x Unit Conversion (2 days) Average Daily Gas Throughput ( ) = day hrs Total Hours of Operation (month) 7.2.1 Wet Gas Throughput during VRU Downtime: The total amount of wet gas processed by this dehydration unit during periods of VRU downtime shall not exceed 5% of the total wet gas throughput to this dehydration unit on a rolling twelve month basis (Colorado Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 75 Construction Permit 15WE0939, as modified under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). VRU downtime is defined as periods when this dehydration unit is operating and flash tank emissions are routed to the ECD. The wet gas throughput to this dehydration unit during periods of VRU downtime shall be determined monthly as the total amount of wet gas throughput to this dehydration unit, as indicated by the inlet flowmeter (Condition 7.2.1), during periods for which flash tank emissions were routed to the ECD, as indicated by the VRU downtime (Condition 7.6.2). The monthly wet gas throughput during VRU downtime shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 7.2.2 Wet Gas Throughput during ECD Downtime: The total amount of wet gas processed by this dehydration unit during periods of ECD downtime shall not exceed 5% of the total wet gas throughput to this dehydration unit on a rolling twelve month basis (Colorado Construction Permit 15WE0939,as modified under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). ECD downtime is defined as periods when this dehydration unit is operating and still vent emissions are routed to atmosphere. The wet gas throughput to this dehydration unit during periods of ECD downtime shall be determined monthly as the total amount of wet gas throughput to this dehydration unit, as indicated by the inlet flowmeter (Condition 7.2.1), during periods for which still vent emissions were routed to atmosphere, as indicated by the. ECD downtime (Condition 7.6.3). The monthly wet gas throughput during ECD downtime shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 7.3 Lean Glycol Circulation Rate Limitations & Compliance Monitoring The circulation rate of lean glycol for this dehydration unit shall not exceed the limitation listed in Summary Table 7 above (Colorado Construction Permit 15WE0939). The lean glycol flowrate shall be recorded daily using the existing glycol flowmeter. The recorded flowrate shall be the sum of the flowrate from each pump and all other glycol injection points (if applicable). Records of the daily lean glycol circulation rate shall be maintained and made available to the Division upon request. A monthly average of the lean glycol circulation rate shall be calculated from the daily recorded values from that month for this dehydration unit. This monthly average shall be used as an input to the monthly process model run, as required by Condition 7.1. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 76 7.4 Extended Gas Analysis An extended gas analysis of the inlet wet gas to this dehydration unit shall be performed annually according to appropriate ASTM methods, or equivalent, if approved in advance by the Division(Colorado Construction Permit 15WE0939). Sequential sampling events shall be separated by at least three months. The extended gas analysis shall identify the relevant VOC and HAP constituents of the wet gas, including any BTEX components. Results of the wet gas analysis shall be maintained and made available to the Division upon request. The composition indicated by the most recent extended wet gas analysis shall be used in the monthly process model run, as required by Condition 7.1. 7.5 Parametric Monitoring The following operating parameters for this dehydration unit shall be monitored and recorded at the intervals specified in the table below. Values of the parameters recorded shall be representative of the unit's operation for the duration of the monitoring period. Records of the values recorded shall be maintained and made available to the Division upon request. Parameter Monitoring Frequency Inlet Wet Gas Temperature Weekly Inlet Wet Gas Pressure Weekly Cold Separator Operating Temperature Weekly Cold Separator Operating Pressure Weekly Flash Tank Operating Temperature Weekly Flash Tank Operating Pressure Weekly Monthly averages of each parameter shall be obtained by averaging the operating values recorded for that month. These monthly averages shall be used as inputs to the monthly process model run, as required by Condition 7.1 (Colorado Construction Permit 15WE0939, as modified under the provisions of Section I, Condition 1.3). 7.6. Hours of Operation 7.6.1 Total Hours of Operation: Hours of operation for this dehydration unit shall be monitored and recorded monthly in a log that is to be made available to the Division upon request. Monthly hours of operation shall be used to monitor compliance with the VOC emission Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 77 limitation, as required by Condition 7.1, and to determine the average daily gas throughput, as required by Condition 7.2.1. 7.6.2 VRU Downtime:Hours of downtime during which the VRU was not operating and emissions from the dehydration unit flash tank were routed to the ECD shall be monitored and recorded monthly in a log to be made available to the Division upon request. Hours of downtime shall be determined using the VRU run status indication. Hours of VRU downtime shall be used to monitor compliance with the VOC emission limitation, as required by Condition 7.1. 7.6.3 ECD Downtime: Hours of downtime during which the ECD was not operating and emissions from the dehydration unit still vent were routed to atmosphere shall be monitored and recorded monthly in a log to be made available to the Division upon request. Hours of downtime shall be determined using the ECD run status indication. Hours of ECD downtime shall be used to monitor compliance with the VOC emission limitation, as required by Condition 7.1. 7.6.4 Concurrent Downtime: Hours during which the VRU and ECD were concurrently experiencing downtime and emissions from the dehydration unit flash tank were routed to atmosphere shall be determined monthly, using the information obtained from Conditions 7.6.2 and 7.6.3. Records of any concurrent downtime shall be maintained and made available to the Division upon request. Concurrent downtime shall be used to monitor compliance with the VOC emission limitations, as required by Condition 7.1. 7.7 Opacity The following opacity requirements apply to the enclosed combustion device (ECD): 7.7.1 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. (Colorado Regulation No. 1, Section II.A.5). In the absence of credible evidence to the contrary, compliance with the opacity limit shall be presumed, provided the requirements of Conditions 7.8.2.4 and 12.4.4 are met. 7.8 Control Device Requirements 7.8.1 The following operating requirements apply to the vapor recovery unit(VRU): 7.8.1.1 The VRU shall be operated at all times when emissions are routed to it, except during periods of permitted downtime. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 78 7.8.1.2 The owner or operator shall complete a daily visual inspection of the air pollution control equipment to ensure that the valves for the piping from the dehydration unit flash tank vent to the VRU are open, except during periods of permitted downtime. The results of this daily visual inspection shall be maintained and made available to the Division upon request. 7.8.2 The following operating requirements apply to the enclosed combustion device (ECD): 7.8.2.1 The ECD shall be operated at all times when emissions are routed to it, except during periods of permitted downtime. 7.8.2.2 The owner or operator shall complete a daily visual inspection of the air pollution control equipment to ensure that the valves for the piping from the dehydration unit still vent (and, if the VRU is experiencing downtime, the flash tank vent) to the ECD are open, except during periods of permitted downtime. The results of this daily visual inspection shall be maintained and made available to the Division upon request. 7.8.2.3 The ECD shall be operated with the pilot light present at all times, except during periods of permitted downtime. A flame detector shall continuously monitor the presence of the pilot light. If the presence of a flame cannot be detected, an auto- igniter shall automatically re-light the pilot. The pilot light shall be monitored as follows: a. Visual inspection of the pilot light shall be completed daily to verify pilot light presence. A daily log with the results from the visual inspection shall be maintained and made available to the Division upon request. b. Records of pilot light outage events and the duration of such events shall be maintained and made available to the Division upon request. 7.8.2.4 EPA Method 22 observations shall be conducted daily to determine whether visible emissions are present for a period of at least one (1) minute in any fifteen (15) minute period of normal operation (Colorado Construction Permit 15WE0939). The results of the daily visual observations shall be kept on file and made available to the Division upon request. a. In the event visible emissions are observed, an EPA Reference Method 9 opacity observation shall be performed to monitor compliance with the opacity standard. The result(s) of the visual observations and the Method 9 observations shall be kept on file and made available for Division review upon request. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 79 (i) The EPA Reference Method 9 opacity observations shall be performed by an observer with a current and valid Method 9 certification. A clear and readable copy of the observer's certificate and any opacity observations shall be kept on file and made available to the Division for review upon request. b. Subject to the provisions of§25-7-123.1,C.R.S.,and in the absence of credible evidence to the contrary, exceedance of the opacity limit(Condition 7.7) shall be considered to exist from the time a Method 9 reading is taken that shows an exceedance of the opacity limit until a Method 9 reading is taken that shows the opacity is less than the opacity limit. 7.9 Alternative Operating Scenario (AOS) The electric glycol circulation pumps may be replaced with another electric glycol circulation pump in accordance with the requirements of Regulation 3, Part A, Section IV.A and without applying for a revision to this permit or obtaining a new construction permit, provided the following requirements are met: 7.9.1 A replacement pump shall operate at the same or lower glycol recirculation rate as required by Condition 7.3. 7.9.2 The source shall maintain a log on-site or at a local field office to contemporaneously record the start and stop dates of any pump replacement, the manufacturer, model number, serial number and capacity of the replacement pump. This log shall be made available to the Division upon request. 7.10 Statewide Controls for Oil and Gas Operations 7.10.1 Colorado Regulation No. 7, Part D, Section I.H. Requirements: This dehydration unit and associated air pollution control equipment are subject to the following "Emission Reductions from Glycol Natural Gas Dehydrators" of Colorado Regulation No. 7, Part D, Section I., "Volatile Organic Compound Emissions from Oil and Gas Operations", as required by Condition 12.2.1: Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 80 Part D, Section I. General Requirements 7.10.1.1 This dehydration unit is subject to the General Provisions of Colorado Regulation No. 7, Part D, Section I.C., as required by Conditions 12.1.1 and 12.1.2. Part D, Section I.H. Control Requirements 7.10.1.2 Beginning May 1,2005,still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, drip station or gas- processing plant in the 8- Hour Ozone Control Area and subject to control requirements pursuant to Section I.H.3. (Condition 7.10.1.3), shall reduce uncontrolled actual emissions of volatile organic compounds by at least 90 percent on a rolling twelve-month basis through the use of a condenser or air pollution control equipment(Colorado Regulation No. 7, Part D, Section I.H.1.). [Compliance Demonstration: In absence of credible evidence to the contrary, compliance with the VOC reduction requirements of Condition 7.10.1.2 shall be presumed as long as the control device requirements in Conditions 7.8 and 7.10.1.1 are met.] 7.10.1.3 The control requirements of Sections I.H.1. (Condition 7.10.1.2) apply where: a. Actual uncontrolled emissions of volatile organic compounds from the glycol natural gas dehydrator are equal to or greater than one ton per year(Colorado Regulation No. 7, Part D, Section I.H.3.a.); and b. The sum of actual uncontrolled emissions of volatile organic compounds from any single glycol natural gas dehydrator or grouping of glycol natural gas dehydrators at a single stationary source is equal to or greater than 15 tons per year. To determine if a grouping of dehydrators meets or exceeds the 15 tons per year threshold, sum the total actual uncontrolled emissions of volatile organic compounds from all individual dehydrators at the stationary source, including those with emissions less than one ton per year(Colorado Regulation No. 7, Part D, Section I.H.3.b.). 7.10.1.4 For purposes of Section I.H. (Condition 7.10.1), emissions from still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator shall be calculated using a method approved in advance by the Division (Colorado Regulation No. 7, Part D, Section I.H.4.). Part D, Section I.H. Monitoring and Recordkeeping Requirements Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 81 7.10.1.5 [Additional Monitoring: The owner or operator shall maintain current records of uncontrolled actual emissions on a rolling twelve month basis for this glycol dehydration unit. Such records shall be used to determine whether the control requirements in Condition 7.10.1.2 apply. Such records shall be maintained and made available for the Division upon request. Dehydration units that are not subject to the control requirements in Condition 7.10.1.2 that increase uncontrolled actual emissions from the dehydrator and/or group of dehydrators at the facility above the thresholds listed in Conditions 7.10.1.3a and/or 7.10.1.3b shall comply with the control requirements of Condition 7.10.1.2 within 60 days of discovery of the emission increase.] 7.10.1.6 Monitoring and Recordkeeping (Colorado Regulation No. 7, Part D, Section I.H.5.) a. Beginning January 1, 2017, owners or operators of glycol natural gas dehydrators subject to the control requirements of Sections I.H.1. (Condition 7.10.1.2) must check on a weekly basis that any condenser or air pollution control equipment used to control emissions of volatile organic compounds is operating properly (Colorado Regulation No. 7, Part D, Section I.H.5.a.), and document: (i) The date of each inspection (Colorado Regulation No. 7, Part D, Section I.H.5.a.(i)); (ii) A description of any problems observed during the inspection of the condenser or air pollution control equipment(Colorado Regulation No. 7, Part D, Section I.H.5.a.(ii)); and (iii) A description and date of any corrective actions taken to address problems observed during the inspection of the condenser or air pollution control equipment (Colorado Regulation No. 7, Part D, Section I.H.5.a.(iii)). b. The owner or operator must check and document on a weekly basis that the pilot light on a combustion device is lit,that the valves for piping of gas to the pilot light are open, and visually check for the presence or absence of smoke (Colorado Regulation No. 7, Part D, Section I.H.5.b.). c. The owner or operator must document the maintenance of the condenser or air pollution control equipment, consistent with manufacturer specifications or good engineering and maintenance practices(Colorado Regulation No. 7, Part D, Section I.H.5.c.). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 82 d. The owner or operator must retain records for a period of five years and make these records available to the Division upon request(Colorado Regulation No. 7, Part D, Section I.H.5.d.). Part D, Section I.H. Reporting Requirements 7.10.1.7 On or before November 30, 2017, and semi-annually by April 30 and November 30 of each year thereafter, the owner or operator must submit the following information for the preceding calendar year (April 30 report) and for May 1 through September 30 (November 30 report) using Division-approved format (Colorado Regulation No. 7, Part D, Section I.H.6.a.). a. A list of the glycol natural gas dehydrator(s) subject to Section I.H. (Colorado Regulation No. 7, Part D, Section I.H.6.a.(i)); b. A list of the condenser or air pollution control equipment used to control emissions of volatile organic compounds from the glycol natural gas dehydrator(s) (Colorado Regulation No. 7, Part D, Section I.H.6.a.(ii)); and c. The date(s) of inspection(s) where the condenser or air pollution control equipment was found not operating properly or where smoke was observed (Colorado Regulation No. 7, Part D, Section I.H.6.a.(iii)). 7.10.2 [State-Only Enforceable] Colorado Regulation No. 7, Part D, Section II.D. Requirements: This dehydration unit and associated air pollution control equipment are subject to the following State-Only Enforceable "Emission Reductions from Glycol Natural Gas Dehydrators" of Colorado Regulation No. 7, Part D, Section II, "Statewide Controls for Oil and Gas Operations": Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No. 7 as of the issuance date of this permit, but are being included as per Colorado Regulation No. 3, Part C, Section V.C.5.b. Part D. Section II. General Requirements 7.10.2.1 This dehydration unit is subject to the General Provisions of Colorado Regulation No. 7, Part D, Section II.B., as required by Condition 12.4. Part D, Section II.D. Control Requirements 7.10.2.2 Beginning May 1,2008,still vents and vents from any flash separator or flash tank Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 83 on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas-processing plant subject to control requirements pursuant to Section II.D.2. (Condition 7.10.2.3), shall reduce uncontrolled actual emissions of volatile organic compounds by at least 90 percent through the use of a condenser or air pollution control equipment (Colorado Regulation No. 7, Part D, Section II.D.1.). [Compliance Demonstration: In absence of credible evidence to the contrary, compliance with the requirements VOC reduction requirements of Condition 7.10.2.2 shall be presumed as long as the control device requirements in Conditions 7.8 and 7.10.2.1 are met.] 7.10.2.3 The control requirements in Section II.D.1. (Condition 7.10.2.2) apply where: a. Actual uncontrolled emissions of volatile organic compounds from the glycol natural gas dehydrator are equal to or greater than two tons per year; and (Colorado Regulation No. 7, Part D, Section II.D.2.a.) b. The sum of actual uncontrolled emissions of volatile organic compounds from any single glycol natural gas dehydrator or grouping of glycol natural gas dehydrators at a single stationary source is equal to or greater than 15 tons per year. To determine if a grouping of dehydrators meets or exceeds the 15 tons per year threshold, sum the total actual uncontrolled emissions of volatile organic compounds from all individual dehydrators at the stationary source, including those with emissions less than two tons per year (Colorado Regulation No. 7, Part D, Section II.D.2.b.). 7.10.2.4 Beginning May 1,2015, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas-processing plant subject to control requirements pursuant to Section II.D.4. (Condition 7.10.2.5), shall reduce uncontrolled actual emissions of hydrocarbons by at least 95 percent on a rolling twelve-month basis through the use of a condenser or air pollution control equipment(Colorado Regulation No. 7, Part D, Section II.D.3.). [Compliance Demonstration: In absence of credible evidence to the contrary, • compliance with the hydrocarbon reduction requirements of Condition 7.10.2.4 shall be presumed as long as the control device requirements in Conditions 7.8 and 7.10.2.1 are met.] Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 84 If a combustion device is used(to meet the requirements of Condition 7.10.2.4), it shall have a design destruction efficiency of at least 98%for hydrocarbons except where: a. The combustion device has been authorized by permit prior to May 1, 2014; and (Colorado Regulation No. 7, Part D, Section II.D.3.a.). b. A building unit or designated outside activity area (as defined in Section II.D.4.c.)is not located within 1,320 feet of the facility at which the natural gas glycol dehydrator is located. (Colorado Regulation No. 7, Part D, Section II.D.3.b.). [Compliance Demonstration: In absence of credible evidence to the contrary, compliance with the design destruction efficiency requirements of Condition 7.10.2.4 shall be presumed as long as the requirements in Conditions 7.10.2.7 and 7.10.2.8 are met.] 7.10.2.5 The control requirements in Section II.D.3. (Condition 7.10.2.4) apply where: a. Uncontrolled actual emissions of VOCs from a single glycol natural gas dehydrator constructed before May 1, 2015, are equal to or greater than (Colorado Regulation No. 7, Part D, Section II.D.4.b.): (i) six (6)tons per year, or (ii) two (2) tons per year if the glycol natural gas dehydrator is located within 1,320 feet of a building unit or designated outside activity area (as defined in Section II.D.4.c.). Part D, Section ILD. Recordkeeping Requirements 7.10.2.6 [Additional Monitoring: The owner or operator shall maintain current records of uncontrolled actual emissions on a rolling twelve month basis for each glycol dehydrator. Such records shall be used to determine whether the control requirements in either Conditions 7.10.2.2 or 7.10.2.4 apply. Such records shall be maintained and made available for the Division upon request. Dehydrators that are not subject to the control requirements in Conditions 7.10.2.2 or 7.10.2.4 that increase uncontrolled actual emissions from the dehydrator and/or group of dehydrators at the facility above the thresholds listed in Conditions 7.10.2.3 and/or 7.10.2.5 shall comply with the control requirements of Conditions 7.10.2.2 and/or 7.10.2.4 within 60 days of discovery of the emission increase.] Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit#95OPWE038 Page 85 7.10.2.7 [Additional Monitoring: If the owner or operator is claiming an exemption from the control requirements of Condition 7.10.2.4 based on the location of the facility, the owner or operator shall maintain records that document whether the facility is located within 1,320 feet of a residential building unit or designated outside activity area. Such records shall be reviewed annually and updated if necessary, and made available to the Division upon request. Dehydrators that are not subject to the control requirements in Condition 7.10.2.4 that become subject based on additions of or changes to residential building units or designated outside activity areas shall comply with the control requirements of Condition 7.10.2.4 within 60 days of discovery of the changes.] 7.10.2.8 [Compliance Demonstration: The owner or operator shall maintain records that document the design efficiency of the combustion device used to meet the requirements of Condition 7.10.2.4. Such records shall be maintained and made available for Division review.] Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 86 8. FLARE—Plant Flare, AIRS ID: 122 Permit Monitoring Parameter Condition Limitations Emission Factor Number Method Interval Emission&Throughput Limits Pilot Gas: 5.5 lb/MMSCF Twelve Month VOC 8.1 19.8 tons/year Rolling Total Monthly Purge/Waste Gas: Calculation Calculation Pilot Gas: 100 lb/MMSCF NOx 2.6 tons/year Purge/Waste Gas:0.068 lb/MMBTU g Twelve Month 8.2 Rolling Total Monthly Pilot Gas: 84 lb/MMSCF Calculation CO 11.4 tons/year Purge/Waste Gas: 0.31 Ib/MMIBTU Flare Gas Pilot Gas: 0.88 MMSCF/year Meter and Twelve Throughput 8.3 Purge/Waste Gas• 56.09 Month Rolling Monthly Limitations MMSCF/year Total Calculation Other Requirements Extended Gas 8 4 ASTM Methods Annually Analysis or Equivalent Hours of 8.5 Recordkeeping Monthly Operation Not to exceed 30%for a period or periods aggregating more than Opacity 8.6 six(6)minutes in any sixty(60) See Condition 8.6 consecutive minutes Control Device 8.7 See Condition 8.7 Requirements Statewide Controls for 8.8 See Condition 8.8 Oil and Gas Operations 40 CFR 60 Subpart A 8.9 See Condition 8.9 §60.18 NSPS Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 87 8.1 VOC Emission Limitations & Compliance Monitoring Emissions of Volatile Organic Compounds (VOC) from the plant flare shall not exceed the limitations listed in Summary Table 8 above (Colorado Construction Permit 15WE0939). Compliance with the emission limitations shall be monitored as follows: 8.1.1 Monthly determination of VOC emissions shall be conducted by the end of the subsequent month utilizing the following methodology: 8.1.1.1 Pilot Gas: VOC emissions contributed by the pilot gas destruction shall be calculated using the above emission factor (from EPA's AP-42: Compilation of Emission Factors, Section 1.4 for Natural Gas Combustion, Final Section, dated 7/98) and the pilot gas flowrate, as required by Condition 8.3, in the equation below: lb MMSCF VOC Emissions (-month l = EF (MMSCF x FRp�iot (month \,month) Unit Conversion (2000 lbl ton Where: EF=Emission Factor,lb/MMSCF FRp;Iat =Flow Rate of Pilot Gas,MMSCF/month 8.1.1.2 Purge/Waste Gas: VOC emissions contributed by purge and waste gas destruction shall be calculated using the monthly purge and waste gas flowrates, as required by Condition 8.3, the molecular weight, and the VOC content of the purge and waste gas obtained from the most recent extended gas analysis, as required by Condition 8.4,in the equation below.A control efficiency of 95%shall apply to the flare, provided the requirements of Conditions 8.7 and 8.8 are met. MMSCF) lb CE(%)) tons l FRpurge/Waste (month l X MWpurge/Waste Ginnol�x Xpurge/Waste X(1— 100 VOC Emissions (month/ 2000 lb MMSCF 379.5 SCF Unit Conversion ( ton x 106 SCF x lbmol Where: FR purge/waste =Flow Rate of Purge or Waste Gas,MMSCF/month Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 88 MWPurge/wane =Molecular Weight of Purge or Waste Gas,lb/lbmol XPurge/waste =Purge or Waste Gas VOC Content,mass fraction CE= Control Efficiency of Flare,% Monthly VOC emissions shall be the sum total of the VOC contributions of the pilot, purge and waste gases sent to the flare for each month. The monthly VOC emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 8.1.2 Facility-wide emissions of Hazardous Air Pollutants (HAP) shall not exceed the annual facility-wide limitations set forth in Condition 11 (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). Monthly emissions of each HAP shall be calculated by the end of the subsequent month using the method indicated in Condition 11 (for pilot gas only), in conjunction with the same method as indicated above for VOC(for purge and waste gas only), except that the HAP content obtained from the most recent extended gas analysis, as required by Condition 8.4, shall replace the VOC content in the equations above. Calculated monthly emissions of each HAP shall be used in a twelve month rolling total to monitor compliance with the facility-wide HAP emission limitations. 8.2 NOx & CO Emission Limitations & Compliance Monitoring Emissions of Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from the plant flare shall not exceed the limitations listed in Summary Table 8 above(Colorado Construction Permit 15WE0939). Compliance with the emission limitations shall be monitored as follows: 8.2.1 Monthly determination of NOx and CO emissions shall be conducted by the end of the subsequent month utilizing the following methodology: 8.2.1.1 Pilot Gas: NOx and CO emissions contributed by the pilot gas combustion shall be calculated using the above emission factors (from EPA's AP-42: Compilation of Emission Factors, Section 1.4 for Natural Gas Combustion,Final Section,dated 7/98), and the pilot gas flowrate, as required by Condition 8.3, in the equation below: r lb l MMSCF tons l _ EF IMMSCF)x FRpitot (month NOx or CO Emissions (month) (2000 on Unit Conversion ton / Where: Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 89 EF=Emission Factor,lb/MMSCF FRpuat=Flow Rate of Pilot Gas,MMSCF/month 8.2.1.2 Purge/Waste Gas: NOx and CO emissions contributed by purge and waste gas destruction shall be calculated using the above emission factors (from EPA's AP- 42: Compilation of Emission Factors, Section 13.5 for Industrial Flares, Final Section, dated 2/18), the waste and purge gas flowrate, as required by Condition 8.3, and the heat content of the waste and purge gas obtained from the most recent extended gas analysis, as required by Condition 8.4, in the equation below: ( lb (Btu MMSCF tons _ EF .MMBtu�X HCpurge/waste ISCF�X FRpurge/waste month NOx or CO Emissions (month) (2000 lb 106 Btu MMSCF) Unit Conversion ` ton X MMBtu X 106 SCF Where: EF=Emission Factor,lb/MMBtu FRpurge/waste =Flow Rate of Purge or Waste Gas,MMSCF/month HCpurge/waste =Heat Content of Purge or Waste Gas,Btu/SCF Monthly NOx and CO emissions shall be the sum total of the NOx and CO contributions of the pilot, purge and waste gases sent to the flare for that month. The monthly NOx and CO emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 8.3 Flare Gas Throughput Limitations & Compliance Monitoring The amount of pilot, purge and waste gas sent to the plant flare shall not exceed the limitations listed in Summary Table 8 above (Colorado Construction Permit 15WE0939, as modified under the provisions of Section I,Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). The pilot, purge and waste gas throughput to the plant flare shall be determined as follows: 8.3.1 Pilot Gas: The pilot gas throughput to the plant flare shall be assumed to have a constant value of 100 SCFH. Monthly pilot gas throughput shall be determined by multiplying this hourly pilot gas throughput by the plant flare monthly hours of operation, as required by Condition 8.5. Records of the monthly pilot gas throughput calculation and the manufacturer specification for the hourly pilot gas throughput rate shall be maintained and made available to the Division upon request. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 90 8.3.2 Purge/Waste Gas: The combined purge and waste gas throughput to the plant flare shall be continuously monitored and recorded monthly using the existing flare header flowmeter.All purge and waste gas streams routed to the plant flare shall be introduced upstream of this meter. During periods of flare operation,the lower detection limit of the flare header flowmeter shall be assumed at all times that the metered value cannot be obtained due to a flowrate below the detection limit. Records of the flare header flowmeter readings shall be maintained and made available to the Division upon request. The monthly pilot,purge and waste gas throughput shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. The monthly pilot, purge and waste gas throughput shall be used to monitor compliance with the annual VOC,NOx and CO emission limitations, as required by Conditions 8.1 and 8.2. 8.4 Extended Gas Analysis An extended gas analysis of the combined purge/waste gas routed to the flare shall be performed annually according to appropriate ASTM methods,or equivalent, if approved in advance by the Division(Colorado Construction Permit 15WE0939, as modified under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3,Part C, Section I.A.7 and Part C, Section III.B.7). The extended analysis shall identify the relevant VOC and HAP constituents of the combined purge/waste gas stream routed to the flare. The purge/waste gas analysis shall be representative of the actual purge/waste gases flared. Results of the extended gas analysis shall be maintained and made available to the Division upon request. The composition and heat content values from combined purge/waste gas obtained from the most recent extended analysis shall be used to monitor compliance with the annual VOC, NOx and CO emission limitations, as required by Conditions 8.1 and 8.2. The combined purge/waste gas composition utilized to monitor compliance with the emissions limitations shall be representative of actual operations during each month. Engineering judgement shall be exercised when determining the appropriate purge/waste gas composition. 8.5 Hours of Operation Hours of operation of the plant flare shall be monitored and recorded monthly in a log to be made available to the Division upon request. Monthly hours of operation shall be used to monitor compliance with the pilot gas throughput limitations, as required by Condition 8.3. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 91 8.6 Opacity The following opacity requirements apply to the plant flare: 8.6.1 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. (Colorado Regulation No. 1, Section II.A.5). In the absence of credible evidence to the contrary, compliance with the opacity limit shall be presumed, provided the requirements of Condition 8.7.3 are met. 8.7 Control Device Requirements The following operating requirements apply to the plant flare: 8.7.1 The flare shall be operated at all times when emissions are routed to it. 8.7.2 The flare shall be operated with the pilot light present at all times. A flame detector shall continuously monitor the presence of the pilot light. If the presence of a flame cannot be detected, an auto-igniter shall automatically re-light the pilot. The pilot light shall be monitored as follows: 8.7.2.1 Visual inspection of the pilot light shall be completed daily to verify pilot light presence. A daily log with the results from the visual inspection shall be maintained and made available to the Division upon request. 8.7.2.2 Records of pilot light outage events and the duration of such events shall be maintained and made available to the Division upon request. 8.7.3 EPA Method 22 observations shall be conducted daily to determine whether visible emissions are present for a period of at least one (1) minute in any fifteen (15) minute period of normal operation. The results of the daily visual observations shall be kept on file and made available to the Division upon request. 8.7.3.1 In the event visible emissions are observed, an EPA Reference Method 9 opacity observation shall be performed to monitor compliance with the opacity standard. The result(s) of the visual observations and the Method 9 observations shall be kept on file and made available for Division review upon request. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 92 a. The EPA Reference Method 9 opacity observations shall be performed by an observer with a current and valid Method 9 certification. A clear and readable copy of the observer's certificate and any opacity observations shall be kept on file and made available to the Division for review upon request. b. Subject to the provisions of§25-7-123.1,C.R.S.,and in the absence of credible evidence to the contrary, exceedance of the opacity limit(Condition 8.6) shall be considered to exist from the time a Method 9 reading is taken that shows an exceedance of the opacity limit until a Method 9 reading is taken that shows the opacity is less than the opacity limit. 8.8 Statewide Controls for Oil and Gas Operations The plant flare is subject to the General Provisions of Colorado Regulation No. 7, Part D, Section II.B., as required by Condition 12.4.2. 8.9 40 CFR Part 60, Subpart A&60.18 NSPS The plant emergency flare is subject to the New Source Performance Standards requirements of Colorado Regulation No. 6, Part A, Subpart A (40 CFR Part 60, Subpart A §60.18) "General Control Device and Work Practice Requirements", including, but not limited to,the following: The requirements below reflect the current rule language as of the revisions to 40 CFR Part 60 Subpart A §60.18 published in the Federal Register on 12/22/2008. However, if revisions to this Subpart are published at a later date, the owner or operator is subject to the requirements contained in the revised version of 40 CFR Part 60 Subpart A §60.18. 8.9.1 Flares shall be designed for and operated with no visible emissions as determined by the methods specified in paragraph (f) (Condition 8.9.7), except for periods not to exceed a total of 5 minutes during any 2 consecutive hours (§60.18(c)(1)). 8.9.2 Flares shall be operated with a flame present at all times, as determined by the methods specified in paragraph (f) (Condition 8.9.8) (§60.18(c)(2)). 8.9.3 An owner/operator has the choice of adhering to either the heat content specifications §60.18(c)(3)(ii) (Condition 8.9.3.1) and the maximum tip velocity specifications in §60.18(c)(4) (Condition 8.9.4), or adhering to the requirements in §60.18(c)(3)(i) (§60.18(c)(3)). 8.9.3.1 Flares shall be used only with the net heating value of the gas being combusted Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 93 being 7.45 MJ/scm (200 Btu/scf) or greater if the flare is nonassisted. The net heating value of the gas being combusted shall be determined by the methods specified in paragraph (f)(3) (Condition 8.9.9) of this section (§60.18(c)(3)(ii)). 8.9.4 Nonassisted flares shall be designed for and operated with an exit velocity, as determined by the methods specified in paragraph (f)(4) (Condition 8.9.10) of this section, less than 18.3 m/sec (60 ft/sec), except as provided in paragraphs (c)(4) (ii) and (iii) of this Subpart (§60.18(c)(4)(i)). 8.9.5 Owners or operators of flares used to comply with the provisions of this subpart shall monitor these control devices to ensure that they are operated and maintained in conformance with their designs. Applicable subparts will provide provisions stating how owners or operators of flares shall monitor these control devices (§60.18(d)). 8.9.6 Flares used to comply with provisions of this subpart shall be operated at all times when emissions may be vented to them (§60.18(e)). 8.9.7 Method 22 of appendix A to this part shall be used to determine the compliance of flares with the visible emission provisions of this subpart. The observation period is 2 hours and shall be used according to Method 22 (§60.18(f)(1)). 8.9.8 The presence of a flare pilot flame shall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame (§60.18(f)(2)). 8.9.9 The net heating value of the gas being combusted in a flare shall be calculated using the following equation (§60.18(f)(3)): HT = K i=1 Where: HT=Net heating value of the sample, MJ/scm; where the net enthalpy per mole of offgas is based on combustion at 25°C and 760 mm Hg, but the standard temperature for determining the volume corresponding to one mole is 20°C; K = Constant; 1.740 x 10-7 (1/ppm)(gmol/scm)(MJ/kcal) where the standard temperature for (gmol/scm) is 20°C; Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 94 = Concentration of sample component i in ppm on a wet basis, as measured for organics by Reference Method 18 and measured for hydrogen and carbon monoxide by ASTM DI946-77 or 90 (Reapproved 1994) (Incorporated by reference as specified in §60.17); and H; =Net heat of combustion of sample component i, kcal/g mole at 25 °C and 760 mm Hg. The heats of combustion may be determined using ASTM D2382-76 or 88 or D4809- 95 (incorporated by reference as specified in §60.17) if published values are not available or cannot be calculated. 8.9.10 The actual exit velocity of a flare shall be determined by dividing the volumetric flowrate (in units of standard temperature and pressure), as determined by Reference Methods 2, 2A, 2C, or 2D as appropriate; by the unobstructed (free) cross sectional area of the flare tip (§60.18(f)(4)). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 95 9. Exempt Non-Emergency Natural Gas Fired Engines One (1) 16 hp Briggs & Stratton Model 303447-1295-E1 Engine One (1) 10 hp Kohler Command Pro 10 Sweeper Brush Engine One (1) 8.5 hp Kohler Command Pro 8.5 Engine One (1) 7.9 hp Honda GX240 Engine , Permit Compliance Monitoring Parameter Condition Limitation Number Emission Factor Method Interval Other Requirements , Not to exceed 20%,except as provided for below: Opacity 9.1 For Certain Operational Activities-Not to EPA Method 9 Annually exceed 30%for a period or periods aggregating more than six(6)minutes in any sixty(60)consecutive minutes 40 CFR 63 Subpart ZZZZ MACT 9.2 See Condition 9.2 40 CFR 63 Subpart A General Provisions 9.3 See Condition 9.3 MACT 9.1 Opacity The following opacity requirements apply to each engine: 9.1.1 Except as provided for in Condition 9.1.2 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 (Colorado Regulation No. 1, Section II.A.1). 9.1.2 No owner or operator of a source shall allow or cause to be emitted into the atmosphere any air pollutant resulting from the building of a new fire, cleaning of fire boxes, soot blowing, start-up, process modifications, or adjustment or occasional cleaning of control equipment which is excess of 30% opacity for a period or periods aggregating more than six (6) minutes in any sixty (60) consecutive minutes (Colorado Regulation No. 1, Section II.A.4). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 96 9.1.3 An EPA Reference Method 9 opacity observation shall be performed annually to monitor compliance with the opacity limitations above (Conditions 9.1.1 and 9.1.2). The results of the Method 9 observations shall be kept on file and made available for Division review upon request. 9.1.3.1 The EPA Reference Method 9 opacity observations shall be performed by an observer with a current and valid Method 9 certification. A clear and readable copy of the observer's certificate and any opacity observations shall be kept on file and made available to the Division for review upon request. 9.1.3.2 Subject to the provisions of §25-7-123.1, C.R.S., and in the absence of credible evidence to the contrary, exceedance of the opacity limitations (Conditions 9.1.1 and 9.1.2)shall be considered to exist from the time a Method 9 reading is taken that shows an exceedance of the opacity limit until a Method 9 reading is taken that shows the opacity is less than the opacity limit. 9.1.3.3 If the engine is not operated during the annual period,then the annual Method 9 opacity observation is not required for that engine. 9.2 40 CFR Part 63, Subpart ZZZZ MACT Each engine is subject to the National Emissions Standards for Hazardous Air Pollutants requirements of Regulation No. 8, Part E, Subpart ZZZZ (40 CFR Part 63, Subpart ZZZZ) "National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines", including, but not limited to,the following: The requirements below reflect the current rule language as of the revisions to 40 CFR Part 63 Subpart ZZZZ published in the Federal Register on 2/27/2014. However, if revisions to this Subpart are published at a later date, the owner or operator is subject to the requirements contained in the revised version of 40 CFR Part 63 Subpart ZZZZ. Note that as of the date of revised permit issuance XX/XX/XXXX, the requirements in 40 CFR Part 63 Subpart ZZZZ promulgated on March 3, 2010 and later have not been adopted into Colorado Regulation No. 8, Part E by the Division and are therefore not state-enforceable. In the event that the Division adopts these requirements, they will become both state and federally enforceable. General Requirements 9.2.1 You must be in compliance with the emission limitations, operating limitations, and other requirements in this subpart that apply to you at all times (§63.6605(a)). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 97 9.2.2 At all times you must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. The general duty to minimize emissions does not require you to make any further efforts to reduce emissions if levels required by this standard have been achieved. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source (§63.6605(b)). Emission Limitations, Operating Limitations and Work Practices 9.2.3 If you own or operate an existing stationary RICE located at an area source of HAP emissions, you must comply with the requirements in Table 2d to this subpart that apply to you (§63.6603(a)): 9.2.3.1 Non-emergency, non-black start 4SRB stationary RICE<500 HP shall: a. Change oil and filter every 1,440 hours of operation or annually, whichever comes first(Table 2d, Item 10.a) b. Inspect spark plugs every 1,440 hours of operation or annually, whichever comes first, and replace as necessary(Table 2d, Item 10.b); and c. Inspect all hoses and belts every 1,440 hours of operation or annually, whichever comes first, and replace as necessary (Table 2d, Item 10.c). d. Sources have the option to utilize an oil analysis program as described in §63.6625(j) (Condition 9.2.6) in order to extend the specified oil change requirement in Table 2d of this subpart(Table 2d, Footnote 1). Monitoring, Installation, Collection, Operation and Maintenance Requirements 9.2.4 You must operate and maintain the stationary RICE and after-treatment control device(if any) according to the manufacturer's emission-related written instructions or develop your own maintenance plan which must provide to the extent practicable for the maintenance and operation of the engine in a manner consistent with good air pollution control practice for minimizing emissions (§63.6625(e)). 9.2.5 If you operate a new, reconstructed, or existing stationary engine, you must minimize the engine's time spent at idle during startup and minimize the engine's startup time to a period needed for appropriate and safe loading of the engine, not to exceed 30 minutes, after which Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 98 time the emission standards applicable to all times other than startup in Table 2d (Condition 9.2.3.1)to this subpart apply (§63.6625(h)). 9.2.6 If you own or operate a stationary SI engine that is subject to the work, operation or management practices in Table 2d (Condition 9.2.3.1)to this subpart, you have the option of utilizing an oil analysis program in order to extend the specified oil change requirement in Table 2d (Condition 9.2.3.1) to this subpart. The oil analysis must be performed at the same frequency specified for changing the oil in Table 2d (Condition 9.2.3.1) to this subpart. The analysis program must at a minimum analyze the following three parameters: Total Acid Number, viscosity, and percent water content. The condemning limits for these parameters are as follows: Total Acid Number increases by more than 3.0 milligrams of potassium hydroxide (KOH)per gram from Total Acid Number of the oil when new; viscosity of the oil has changed by more than 20 percent from the viscosity of the oil when new; or percent water content (by volume) is greater than 0.5. If all of these condemning limits are not exceeded, the engine owner or operator is not required to change the oil.If any of the limits are exceeded, the engine owner or operator must change the oil within 2 business days of receiving the results of the analysis; if the engine is not in operation when the results of the analysis are received, the engine owner or operator must change the oil within 2 business days or before commencing operation, whichever is later. The owner or operator must keep records of the parameters that are analyzed as part of the program, the results of the analysis, and the oil changes for the engine. The analysis program must be part of the maintenance plan for the engine (§63.6625(j)). Continuous Compliance Demonstration 9.2.7 You must demonstrate continuous compliance with each emission limitation, operating limitation, and other requirements in Table 2d (Condition 9.2.3.1) to this subpart that apply to you according to methods specified in Table 6 to this subpart(§63.6640(a)): 9.2.7.1 Existing 4SRB stationary RICE <500 HP located at an area source of HAP shall: a. Operate and maintain the stationary RICE according to the manufacturer's emission-related operation and maintenance instructions (Table 6, Item 9.a.i); or b. Develop and follow your own maintenance plan which must provide to the extent practicable for the maintenance and operation of the engine in a manner consistent with good air pollution control practice for minimizing emissions (Table 6, Item 9.a.ii). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 99 9.2.8 You must report each instance in which you did not meet each emission limitation or operating limitation in Table 2d (Condition 9.2.3.1) to this subpart that apply to you. These instances are deviations from the emission and operating limitations in this subpart. These deviations must be reported according to the requirements in §63.6650(Condition 9.2.10). If you change your catalyst, you must reestablish the values of the operating parameters measured during the initial performance test. When you reestablish the values of your operating parameters, you must also conduct a performance test to demonstrate that you are meeting the required emission limitation applicable to your stationary RICE (§63.6640(b)). 9.2.9 You must also report each instance in which you did not meet the requirements in Table 8 (Condition 9.3)to this subpart that apply to you(§63.6640(e)). Reporting Requirements 9.2.10 Each affected source that has obtained a title V operating permit pursuant to 40 CFR part 70 or 71 must report all deviations as defined in this subpart(Condition 9.2.8) in the semiannual monitoring report required by 40 CFR 70.6 (a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A) (§63.6650(f)). Recordkeeping Requirements 9.2.11 If you must comply with the emission and operating limitations(Condition 9.2.3.1),you must keep the records described in paragraphs §63.6655(a)(1) through (a)(5) of this subpart (§63.6655(a)). 9.2.12 You must keep the records required in Table 6 (Condition 9.2.7.1) of this subpart to show continuous compliance with each emission or operating limitation that applies to you (§63.6655(d)). 9.2.13 You must keep records of the maintenance conducted on the stationary RICE in order to demonstrate that you operated and maintained the stationary RICE and after-treatment control device (if any) according to your own maintenance plan (§63.6655(e)). 9.2.14 Your records must be in a form suitable and readily available for expeditious review according to §63.10(b)(1) (Condition 9.3.2) (§63.6660(a)). 9.2.15 As specified in §63.10(b)(1) (Condition 9.3.2), you must keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record (§63.6660(b)). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 100 9.2.16 You must keep each record readily accessible in hard copy or electronic form for at least 5 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to §63.10(b)(1) (Condition 9.3.2) (§63.6660(c)). 9.3 40 CFR Part 63, Subpart A MACT Each engine is subject to the requirements in 40 CFR Part 63 Subpart A"General Provisions",as adopted by reference in Colorado Regulation No. 8,Part E, Section I as specified in 40 CFR Part 63 Subpart ZZZZ §63.6665. These requirements include, but are not limited to, the following: 9.3.1 Prohibited activities and circumvention (§63.4) 9.3.2 Recordkeeping and reporting requirements (§63.10) Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 101 10. Exempt Emergency Natural Gas Fired Engine One(1) 14 hp Briggs & Stratton Model 030549 Emergency Genset Permit Compliance Monitoring Parameter Condition Limitation Number Emission Factor Method Interval Other Requirements Not to exceed 20%,except as provided for below: Opacity 10.1 For Certain Operational Activities-Not to EPA Method 9 Annually exceed 30%for a period or periods aggregating more than six(6)minutes in any sixty(60)consecutive minutes 40 CFR 63 Subpart 10.2 See Condition 10.2 ZZZZ MACT 40 CFR 63 Subpart A General Provisions 10.3 See Condition 10.3 MACT 10.1 Opacity The following opacity requirements apply to this engine: 10.1.1 Except as provided for in Condition 10.1.2 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 (Colorado Regulation No. 1, Section II.A.1). 10.1.2 No owner or operator of a source shall allow or cause to be emitted into the atmosphere any air pollutant resulting from the building of a new fire, cleaning of fire boxes, soot blowing, start-up, process modifications, or adjustment or occasional cleaning of control equipment which is excess of 30% opacity for a period or periods aggregating more than six (6) minutes in any sixty (60) consecutive minutes (Colorado Regulation No. 1, Section II.A.4). 10.1.3 An EPA Reference Method 9 opacity observation shall be performed annually to monitor compliance with the opacity limitations above (Conditions 10.1.1 and 10.1.2). The results of the Method 9 observations shall be kept on file and made available for Division review upon request. 10.1.3.1 The EPA Reference Method 9 opacity observations shall be performed by an observer Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED. DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 102 with a current and valid Method 9 certification. A clear and readable copy of the observer's certificate and any opacity observations shall be kept on file and made available to the Division for review upon request. 10.1.3.2 Subject to the provisions of §25-7-123.1, C.R.S., and in the absence of credible evidence to the contrary, exceedance of the opacity limitations (Conditions 10.1.1 and 10.1.2) shall be considered to exist from the time a Method 9 reading is taken that shows an exceedance of the opacity limit until a Method 9 reading is taken that shows the opacity is less than the opacity limit. 10.1.3.3 If the engine is not operated during the annual period,then the annual Method 9 opacity observation is not required for that engine. 10.2 40 CFR Part 63, Subpart ZZZZ MACT This engine is subject to the National Emissions Standards for Hazardous Air Pollutants requirements of Regulation No. 8, Part E, Subpart ZZZZ(40 CFR Part 63, Subpart ZZZZ) "National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines", including, but not limited to, the following: The requirements below reflect the current rule language as of the revisions to 40 CFR Part 63 Subpart ZZZZ published in the Federal Register on 2/27/2014. However, if revisions to this Subpart are published at a later date, the owner or operator is subject to the requirements contained in the revised version of 40 CFR Part 63 Subpart ZZZZ. Note that as of the date of revised permit issuance XX/XX/XXXX, the requirements in 40 CFR Part 63 Subpart ZZZZ promulgated on March 3, 2010 and later have not been adopted into Colorado Regulation No. 8, Part E by the Division and are therefore not state-enforceable. In the event that the Division adopts these requirements,they will become both state and federally enforceable. General Requirements 10.2.1 You must be in compliance with the emission limitations, operating limitations, and other requirements in this subpart that apply to you at all times (§63.6605(a)). 10.2.2 At all times you must operate and maintain any affected source, including associated air pollution control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. The general duty to minimize emissions does not require you to make any further efforts to reduce emissions if levels required by this standard have been achieved.Determination of whether such operation Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 103 and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source (§63.6605(b)). Emission Limitations, Operating Limitations and Work Practices 10.2.3 If you own or operate an existing stationary RICE located at an area source of HAP emissions, you must comply with the requirements in Table 2d to this subpart that apply to you (§63.6603(a)): 10.2.3.1 Emergency stationary SI RICE shall: a. Change oil and filter every 500 hours of operation or annually, whichever comes first (Table 2d, Item 5.a); b. Inspect spark plugs every 1,000 hours of operation or annually, whichever comes first, and replace as necessary (Table 2d, Item 5.b); and c. Inspect all hoses and belts every 500 hours of operation or annually,whichever comes first, and replace as necessary (Table 2d, Item 5.c). d. Sources have the option to utilize an oil analysis program as described in §63.6625(j) (Condition 10.2.7) in order to extend the specified oil change requirement in Table 2d of this subpart(Table 2d, Footnote 1). e. If an emergency engine is operating during an emergency and it is not possible to shut down the engine in order to perform the management practice requirements on the schedule required in Table 2d of this subpart, or if performing the management practice on the required schedule would otherwise pose an unacceptable risk under federal, state, or local law, the management practice can be delayed until the emergency is over or the unacceptable risk under federal, state, or local law has abated. The management practice should be performed as soon as practicable after the emergency has ended or the unacceptable risk under federal, state, or local law has abated. Sources must report any failure to perform the management practice on the schedule required and the federal, state or local law under which the risk was deemed unacceptable (Table 2d, Footnote 2). Monitoring, Installation, Collection, Operation and Maintenance Requirements 10.2.4 You must operate and maintain the stationary RICE and after-treatment control device(if any) according to the manufacturer's emission-related written instructions or develop your own Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 104 maintenance plan which must provide to the extent practicable for the maintenance and operation of the engine in a manner consistent with good air pollution control practice for minimizing emissions (§63.6625(e)). 10.2.5 If you own or operate an existing emergency stationary RICE with a site rating of less than or equal to 500 brake HP located at a major source of HAP emissions or an existing emergency stationary RICE located at an area source of HAP emissions,you must install a non-resettable hour meter if one is not already installed (§63.6625(f)). 10.2.6 If you operate a new, reconstructed, or existing stationary engine, you must minimize the engine's time spent at idle during startup and minimize the engine's startup time to a period needed for appropriate and safe loading of the engine, not to exceed 30 minutes, after which time the emission standards applicable to all times other than startup in Table 2d (Condition 10.2.3.1)to this subpart apply (§63.6625(h)). 10.2.7 If you own or operate a stationary SI engine that is subject to the work, operation or management practices in items 5 of Table 2d (Condition 10.2.3.1) to this subpart, you have the option of utilizing an oil analysis program in order to extend the specified oil change requirement in Table 2d (Condition 10.2.3.1) to this subpart. The oil analysis must be performed at the same frequency specified for changing the oil in Table 2d (Condition 10.2.3.1)to this subpart.The analysis program must at a minimum analyze the following three parameters: Total Acid Number, viscosity,and percent water content. The condemning limits for these parameters are as follows:Total Acid Number increases by more than 3.0 milligrams of potassium hydroxide (KOH) per gram from Total Acid Number of the oil when new; viscosity of the oil has changed by more than 20 percent from the viscosity of the oil when new;or percent water content(by volume)is greater than 0.5.If all of these condemning limits are not exceeded, the engine owner or operator is not required to change the oil. If any of the limits are exceeded, the engine owner or operator must change the oil within 2 business days of receiving the results of the analysis; if the engine is not in operation when the results of the analysis are received,the engine owner or operator must change the oil within 2 business days or before commencing operation,whichever is later.The owner or operator must keep records of the parameters that are analyzed as part of the program, the results of the analysis, and the oil changes for the engine. The analysis program must be part of the maintenance plan for the engine (§63.6625(j)). Continuous Compliance Demonstration Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 105 10.2.8 You must demonstrate continuous compliance with each emission limitation, operating limitation, and other requirements in Table 2d (Condition 10.2.3.1)to this subpart that apply to you according to methods specified in Table 6 to this subpart(§63.6640(a)): 10.2.8.1 Existing emergency and black start stationary RICE located at an area source of HAP shall: a. Operate and maintain the stationary RICE according to the manufacturer's emission-related operation and maintenance instructions (Table 6, Item 9.a.i); or b. Develop and follow your own maintenance plan which must provide to the extent practicable for the maintenance and operation of the engine in a manner consistent with good air pollution control practice for minimizing emissions (Table 6, Item 9.a.ii). 10.2.9 You must report each instance in which you did not meet each emission limitation or operating limitation in Table 2d (Condition 10.2.3.1) to this subpart that apply to you. These instances are deviations from the emission and operating limitations in this subpart. These deviations must be reported according to the requirements in §63.6650 (Condition 10.2.12). If you change your catalyst, you must reestablish the values of the operating parameters measured during the initial performance test. When you reestablish the values of your operating parameters,you must also conduct a performance test to demonstrate that you are meeting the required emission limitation applicable to your stationary RICE (§63.6640(b)). 10.2.10 You must also report each instance in which you did not meet the requirements in Table 8 (Condition 10.3)to this subpart that apply to you (§63.6640(e)). 10.2.11 If you own or operate an emergency stationary RICE, you must operate the emergency stationary RICE according to the requirements in paragraphs (0(1) through (4) (Conditions 10.2.11.1 through 10.2.11.3) of this section. In order for the engine to be considered an emergency stationary RICE under this subpart,any operation other than emergency operation, maintenance and testing, emergency demand response, and operation in non-emergency situations for 50 hours per year, as described in paragraphs (f)(1) through (4) (Conditions 10.2.11.1 through 10.2.11.3) of this section, is prohibited. If you do not operate the engine according to the requirements in paragraphs (f)(1)through (4) (Conditions 10.2.11.1 through 10.2.11.3) of this section, the engine will not be considered an emergency engine under this subpart and must meet all requirements for non-emergency engines (§63.6640(f)). 10.2.11.1 There is no time limit on the use of emergency stationary RICE in emergency Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 106 situations (§63.6640(f)(1)). 10.2.11.2 You may operate your emergency stationary RICE for any combination of the purposes specified in paragraphs (f)(2)(i) through (iii) of this section for a maximum of 100 hours per calendar year. Any operation for non-emergency situations as allowed by paragraphs (0(3) and (4) (Condition 10.2.11.3) of this section counts as part of the 100 hours per calendar year allowed by this paragraph (0(2) (§63.6640(f)(2)). 10.2.11.3 Emergency stationary RICE located at area sources of HAP may be operated for up to 50 hours per calendar year in non-emergency situations. The 50 hours of operation in non-emergency situations are counted as part of the 100 hours per calendar year for maintenance and testing and emergency demand response provided in paragraph (0(2) (Condition 10.2.11.2) of this section. Except as provided in paragraphs (f)(4)(i) and (ii) of this section, the 50 hours per year for non-emergency situations cannot be used for peak shaving or non-emergency demand response, or to generate income for a facility to an electric grid or otherwise supply power as part of a financial arrangement with another entity (§63.6640(0(4)). Reporting Requirements 10.2.12 Each affected source that has obtained a title V operating permit pursuant to 40 CFR part 70 or 71 must report all deviations as defined in this subpart(Condition 10.2.9)in the semiannual monitoring report required by 40 CFR 70.6 (a)(3)(iii)(A) or 40 CFR 71.6(a)(3)(iii)(A) (§63.6650(0). Recordkeeping Requirements 10.2.13 If you must comply with the emission and operating limitations (Condition 10.2.3.1), you must keep the records described in paragraphs §63.6655(a)(1) through (a)(5) of this subpart (§63.6655(a)). 10.2.14 You must keep the records required in Table 6 (Condition 10.2.8.1) of this subpart to show continuous compliance with each emission or operating limitation that applies to you (§63.6655(d)). 10.2.15 You must keep records of the maintenance conducted on the stationary RICE in order to demonstrate that you operated and maintained the stationary RICE and after-treatment control device (if any) according to your own maintenance plan (§63.6655(e)). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 107 10.2.16 If you own or operate any of the stationary RICE in paragraphs (0(1) through (2) (Condition 10.2.16.1) of this section, you must keep records of the hours of operation of the engine that is recorded through the non-resettable hour meter.The owner or operator must document how many hours are spent for emergency operation, including what classified the operation as emergency and how many hours are spent for non-emergency operation. If the engine is used for the purposes specified in §63.6640(f)(2)(ii) or (iii) (Condition 10.2.11.2) or §63.6640(f)(4)(ii) (Condition 10.2.11.3), the owner or operator must keep records of the notification of the emergency situation, and the date, start time, and end time of engine operation for these purposes (§63.6655(f)). 10.2.16.1 An existing emergency stationary RICE located at an area source of HAP emissions that does not meet the standards applicable to non-emergency engines (§63.6655(f)(2)). 10.2.17 Your records must be in a form suitable and readily available for expeditious review according to §63.10(b)(1) (Condition 10.3.2) (§63.6660(a)). 10.2.18 As specified in §63.10(b)(1) (Condition 10.3.2), you must keep each record for 5 years following the date of each occurrence, measurement, maintenance, corrective action, report, or record (§63.6660(b)). 10.2.19 You must keep each record readily accessible in hard copy or electronic form for at least 5 years after the date of each occurrence, measurement, maintenance, corrective action, report, or record, according to §63.10(b)(1) (Condition 10.3.2) (§63.6660(c)). 10.3 40 CFR Part 63, Subpart A MACT This engine is subject to the requirements in 40 CFR Part 63 Subpart A"General Provisions", as adopted by reference in Colorado Regulation No. 8,Part E, Section I as specified in 40 CFR Part 63 Subpart ZZZZ §63.6665. These requirements include, but are not limited to,the following: 10.3.1 Prohibited activities and circumvention (§63.4) 10.3.2 Recordkeeping and reporting requirements (§63.10) Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 108 11. Facility-Wide Hazardous Air Pollutant(HAP) Emission Limitations Permit Monitoring Parameter Condition Limitation Number Emission Factor Method Interval Emission&Throughput Limits Recordkeeping and HAP 11.1 8.0 tons/year single HAP See Condition Twelve Month Monthly 20.0 tons/year total HAP 11.1.1 Rolling Total Calculation 11.1 HAP Emission Limitations & Compliance Monitoring Emissions of Hazardous Air Pollutants (HAP) from this facility shall not exceed the limitations listed in Summary Table 11 above (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). Compliance with the emission limitations shall be monitored as follows: 11.1.1 Monthly emission calculations shall be completed for each HAP emitted at this facility.Point- specific calculations of HAP emissions are outlined as follows: 11.1.1.1 For Natural Gas Fired Reciprocating Internal Combustion Engines: a. Uncontrolled emission factors (EF) for each HAP shall be obtained from the most recent edition of EPA's AP-42: Compilation of Emission Factors,Section 3.2 for Natural Gas Fired Reciprocating Engines. Final Section, Table 3.2-3 "Uncontrolled Emission Factors for 4-Stroke Rich-Burn Engines". b. The following control efficiencies(CE) shall be applied to the referenced HAP species Hazardous Air Pollutant Control Efficiency Formaldehyde 76% Other HAP 50% c. Monthly emissions of each HAP with uncontrolled actual emissions above the de minimis reporting threshold shall be calculated for each engine by the end of the subsequent month using the above emission factors (EF) and control efficiencies (CE), the monthly natural gas consumption, as required by Conditions 1.3 and 2.2, and the heat content of the natural gas obtained from Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 109 the most recent analysis,as required by Conditions 1.4 and 2.3, in the equation below: lb MMBtu MMSCF ( _CE(% J )1 tons l Emission Factor (MMBtu�x Heat Content (MMSCF x Fuel Use (month x 1 100 HAP Emissions (month/ 2000 Ib Unit Conversion ( ton 11.1.1.2 For Process Heaters: a. Uncontrolled emission factors for each HAP shall be obtained from the most recent edition of EPA's AP-42: Compilation of Emission Factors, Section 1.4 for Natural Gas Combustion, Final Section, Table 1.4-3 "Emission Factors for Speciated Organic Compounds from Natural Gas Combustion". b. Monthly emissions of each HAP shall be calculated for each heater by the end of the subsequent month using the above emission factors and the monthly natural gas consumption,as required by Conditions 3.3 and 4.3, in the equation below: lb MMSCF) tons Emission Factor (MMSCF x Fuel Use (month HAP Emissions (month 2000 lb Unit Conversion ( ton 11.1.1.3 For Fugitive Emissions: a. See Condition 5.1.4 11.1.1.4 For Pressurized Product Truck Loadout Rack: a. See Condition 6.1.2 11.1.1.5 For Dehydration Unit: a. See Condition 7.1.2 11.1.1.6 For Plant Flare: a. See Condition 8.1.2 for purge and waste gas only b. For Pilot Gas Only: (i) Uncontrolled emission factors for each HAP shall be obtained from the most recent edition of EPA's AP-42: Compilation of Emission Factors, Section 1.4 for Natural Gas Combustion, Final Section, Table 1.4-3 "Emission Factors for Speciated Organic Compounds from Natural Gas Combustion". Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 110 (ii) Monthly emissions of each HAP shall be calculated for the plant flare pilot gas by the end of the subsequent month using the above emission factors and the monthly pilot gas throughput, as required by Condition 8.3.1, in the equation below: tons l Emission Factor (MMscF)x Pilot Throughput (month HAP Emissions (month/ 2000 lb ) Unit Conversion ( ton c. Total emissions of each HAP for the plant flare shall be the sum of the HAP emissions from the waste, purge and pilot gases. 11.1.2 Determination of Compliance with the Facility-Wide Individual HAP Limit 11.1.2.1 Facility-wide emissions for an individual HAP shall be the sum total emissions of that HAP from each point listed in Condition 11.1.1 above for which uncontrolled actual emissions of that HAP are above the de minimis reporting threshold. Monthly emissions of each HAP shall be used in a twelve month rolling total to monitor compliance with the individual HAP annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 11.1.3 Determination of Compliance with the Facility-Wide Total HAP Limit 11.1.3.1 Facility-wide emissions for total HAP shall be the sum total of all HAP emitted from each point listed in Condition 11.1.1 above for which uncontrolled actual emissions are above the de minimis reporting threshold. Monthly emissions of total HAP shall be used in a twelve month rolling total to monitor compliance with the total HAP annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 111 12. Facility-Wide General Requirements 12.1 Colorado Regulation No. 7, Part D, Section I.C. Requirements This facility is subject to the following "General Provisions" of Colorado Regulation No. 7, Part D, Section I, "Volatile Organic Compound Emissions from Oil and Gas Operations": 12.1.1 All air pollution control equipment used to demonstrate compliance with this Section I. must be operated and maintained consistent with manufacturer specifications and good engineering and maintenance practices. The owner or operator must keep manufacturer specifications on file. In addition, all such air pollution control equipment must be adequately designed and sized to achieve the control efficiency rates required by this Section I. and to handle reasonably foreseeable fluctuations in emissions of volatile organic compounds. Fluctuations in emissions that occur when the separator dumps into the tank are reasonably foreseeable (Colorado Regulation No. 7, Part D, Section I.C.1.a.). 12.1.2 All hydrocarbon liquids and produced water collection, storage, processing and handling operations, regardless of size, must be designed, operated and maintained so as to minimize emission of volatile organic compounds to the atmosphere to the maximum extent practicable (Colorado Regulation No. 7, Part D, Section I.C.1.b.) 12.2 Colorado Regulation No. 7, Part D, Section I.G. Requirements This facility is subject to the following "Natural Gas Processing Plants Located in the 8-Hour Ozone Control Area Requirements" of Colorado Regulation No. 7, Part D, Section I, "Volatile Organic Compound Emissions from Oil and Gas Operations": 12.2.1 Natural gas-processing plants located in the 8-hour Ozone Control Area shall comply with requirements of this Section I.G. (Conditions 5.4 and 12.2), as well as the requirements of Sections I.B., I.C.1.a. (Condition 12.1.1), I.C.1.b. (Condition 12.1.2), I.H. (Condition 7.10.1), I.J. (Condition 12.3), and Part E, Sections I.A. through C. (Condition 1.10.1.1) (Colorado Regulation No. 7, Part D, Section I.G.4.). 12.3 Colorado Regulation No. 7, Part D, Section I.J. Requirements: Each compressor is subject to the following"Compressor Requirements" of Colorado Regulation No. 7, Part D, Section I, "Volatile Organic Compound Emissions from Oil and Gas Operations": Control Requirements Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 112 12.3.1 Beginning January 1, 2018, the rod packing on reciprocating compressors located between the wellhead and the point of custody transfer to the natural gas transmission and storage segment must be replaced every 26,000 hours of operation or every thirty six (36) months (Colorado Regulation No. 7, Part D, Section I.J.2.a.). Owners or operators of reciprocating compressors located at a natural gas processing plant and constructed before January 1, 2018, must: 12.3.1.1 Begin monitoring the hours of operation starting January 1, 2018; or (Colorado Regulation No. 7, Part D, Section I.J.2.a.(i)(A)) 12.3.1.2 Conduct the first rod packing replacement required under Section I.J.2. prior to January 1, 2021 (Colorado Regulation No. 7, Part D, Section I.J.2.a.(i)(B)). Recordkeeping Requirements 12.3.2 Owners or operators must maintain the following records for at least five (5)years and make records available to the Division upon request (Colorado Regulation No. 7, Part D, Section I.J.2.c.(i)): 12.3.2.1 Identification of each reciprocating compressor (Colorado Regulation No. 7, Part D, Section I.J.2.c.(i)(A)) 12.3.2.2 The hours of operation or the number of months since the previous rod packing replacement, or a statement that emissions from the rod packing are being routed to a process through a closed vent system under negative pressure (Colorado Regulation No. 7, Part D, Section I.J.2.c.(i)(B)) 12.3.2.3 The date of each rod packing replacement, or date of installation of a rod packing emissions collection system and closed vent system (Colorado Regulation No. 7, Part D, Section I.J.2.c.(i)(C)) Alternate Compliance Option 12.3.3 As an alternative to the emission control, inspection, repair, and recordkeeping provisions described in Section I.J.2.a. (Condition 12.3.1) the owner or operator may comply with reciprocating compressor emission control, monitoring, recordkeeping, and reporting requirements of a New Source Performance Standard in 40 CFR Part 60(Colorado Regulation No. 7, Part D, Section I.J.2.e.). 12.4 [State-Only Enforceable] Colorado Regulation No. 7, Part D, Section II.B. Requirements Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 113 This facility is subject to the following State-Only Enforceable "General Provisions" of Colorado Regulation No. 7, Part D, Section II, "Statewide Controls for Oil and Gas Operations": 12.4.1 All hydrocarbon liquids and produced water collection, storage, processing, and handling operations, regardless of size, must be designed, operated, and maintained so as to minimize emission of VOCs and other hydrocarbons to the atmosphere to the extent reasonably practicable (Colorado Regulation No. 7, Part D, Section II.B.1.a.). 12.4.2 At all times, including periods of start-up and shutdown, the facility and air pollution control equipment must be maintained and operated in a manner consistent with good air pollution control practices for minimizing emissions. Determination of whether or not acceptable operation and maintenance procedures are being used will be based on information available to the Division, which may include, but is not limited to, monitoring results, opacity observations, review of operation and maintenance procedures, and inspection of the source (Colorado Regulation No. 7, Part D, Section II.B.I.b.). 12.4.3 All air pollution control equipment must be operated and maintained pursuant to the manufacturing specifications or equivalent to the extent practicable, and consistent with technological limitations and good engineering and maintenance practices. The owner or operator must keep manufacturer specifications or equivalent on file. In addition, all such air pollution control equipment must be adequately designed and sized to achieve the control efficiency rates and to handle reasonably foreseeable fluctuations in emissions of VOCs and other hydrocarbons during normal operations. Fluctuations in emissions that occur when the separator dumps into the tank are reasonably foreseeable (Colorado Regulation No. 7, Part D, Section II.B.2.a.). 12.4.4 If a combustion device is used to control emissions of VOCs and other hydrocarbons, it must be enclosed, have no visible emissions during normal operation, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly (Colorado Regulation No. 7, Part D, Section II.B.2.b.). 12.4.5 Auto-igniters: All combustion devices used to control emissions of hydrocarbons must be equipped with and operate an auto-igniter as follows (Colorado Regulation No. 7, Part D, Section II.B.2.d.): 12.4.5.1 All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto-igniter upon installation of the combustion device (Colorado Regulation No. 7, Part D, Section II.B.2.d.(i)). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 114 12.5 [State-Only Enforceable] Colorado Regulation No. 7, Part D, Section V. Requirements: This facility is subject to the following State-Only Enforceable "Oil and Natural Gas Operations Inventory" requirements of Colorado Regulation No. 7, Part D, Section V.: Conditions shown in italic text below represent monitoring, recordkeeping and recording provisions that are not included in Colorado Regulation No.7 as of the issuance date of this permit,but are being included as per Colorado Regulation No 3, Part C, Section V.C.5.b. 12.5.1 On or before June 30th, 2021 (and on June 30th each year thereafter), the owner or operator of oil and natural gas operations and equipment at or upstream of a natural gas processing plant in Colorado must submit a single annual report that includes actual emissions and specified information in the Division-approved report format (Colorado Regulation No. 7, Part D, Section V.A.). 12.5.2 General reporting requirements (Colorado Regulation No. 7, Part D, Section V.B.). 12.5.2.1 The following information must be reported in accordance with Section V.A (Condition 12.5.1) (Colorado Regulation No. 7, Part D, Section V.B.1.). a. Company name, physical street address, and name and contact information of the company representative, for reporting purposes (Colorado Regulation No. 7, Part D, Section V.B.1.a.). b. The date of submittal and the year covered by the report(Colorado Regulation No. 7, Part D, Section V.B.1.b.). c. A list of the activities or equipment, as specified in Section V.C. (Condition 12.5.3), for which emissions are reported (Colorado Regulation No. 7, Part D, Section V.B.1.c.). d. The company's monthly actual emissions of volatile organic compounds (VOC), oxides of nitrogen (NOx), carbon monoxide (CO), methane, and ethane for each month of May through September (Colorado Regulation No. 7, Part D, Section V.B.1.d.). e. The company's annual actual emissions of VOCs, NOx, CO, methane, and ethane for the entire calendar year(Colorado Regulation No. 7,Part D, Section V.B.1.e.). f. The actual emissions of VOCs, NOx, CO, methane, and ethane for each activity or equipment listed in Section W.C. (Condition 12.5.3) per facility, or Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 115 per pipeline between facilities where the pipeline is not located at a stationary source(Colorado Regulation No. 7, Part D, Section V.B.1.f.). (i) The report must include the actual emissions from each activity or equipment per month for each month of May through September (Colorado Regulation No. 7, Part D, Section V.B.I.f.(i)). (ii) The report must include the actual emissions from each activity or equipment for the entire calendar year (Colorado Regulation No. 7, Part D, Section V.B.1.f.(ii)). g. A certification by the company representative that supervised the development and submission of the inventory report that, based on information and belief formed after reasonable inquiry, the statements and information in the document are true, accurate, and complete (Colorado Regulation No. 7, Part D, Section V.B.1.g.). 12.5.2.2 The owner or operator must submit a revised annual report after discovering that an annual report submitted within the previous two(2)years contained one or more substantive errors. A substantive error is a mass of emissions of any individual pollutant subject to reporting under Section V.(Condition 12.5)that is at least 10% higher or lower than the mass of emissions of the pollutant reported across the owner or operator's activity or equipment, as listed in Section V.C. (Condition 12.5.3), in Colorado. A refinement of or improvement to an emissions estimation technique or emission factor is not a substantive error but must be noted in the subsequent annual report after the refinement or improvement. Revised annual reports must be submitted by August 31 if the substantive error is discovered between January 1 and June 30, and by February 28 if the substantive error is discovered between July 1 and December 31 of the preceding calendar year (Colorado Regulation No. 7, Part D, Section V.B.2.). 12.5.3 Beginning July 1, 2020,and each calendar year thereafter, owners or operators must maintain the following information for inclusion in the annual report(Colorado Regulation No. 7, Part D, Section V.C.). 12.5.3.1 AIRS number of the activity or equipment and associated facility or pipeline (if a pipeline between facilities) location, including latitude and longitude coordinates. If the activity or equipment does not have an AIRS number, a description of the activity or equipment(Colorado Regulation No. 7, Part D, Section V.C.1.). 12.5.3.2 Actual emissions from each activity or equipment listed in this Section V.C.2., unless otherwise specified in the Division-approved report format, and the Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 116 emission factor(s),assumptions,and calculation methodology used to calculate the emissions (Colorado Regulation No. 7, Part D, Section V.C.2.). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 117 13. Compliance Assurance Monitoring(ver 4/16/2009) 13.1 The Compliance Assurance Monitoring (CAM) requirements in 40 CFR Part 64, as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV, apply to the following units: 13.1.1 C-116, C-117, C-118, C-119, C-120, C-152, C-122 — Seven (7) Waukesha Model L-7042 GSI Engines(1,100 hp)with respect to the NOx limitations identified in Section II,Condition 1.1. C-123 — One (1) Waukesha Model L-7042 GU Engine (896 hp) with respect to the NOx limitations identified in Section II, Condition 1.1. 13.1.1.1 The permittee shall follow the CAM Plan provided in Appendix G of this permit. 13.1.1.2 Excursions, for the purposes of reporting, are defined as any instance in which the pre-catalyst temperature is less than 750°F or greater than 1250°F, or the catalyst pressure drop exceeds more than 3 inches of water from the pressure drop established during the initial performance test. Excursions shall be reported as required by Section IV, Conditions 21 and 22.d of this permit. 13.1.2 Operation of Approved Monitoring 13.1.2.1 At all times, the owner or operator shall maintain the monitoring, including but not limited to, maintaining necessary parts for routine repairs of the monitoring equipment (40 CFR Part 64 § 64.7(b), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 13.1.2.2 Except for, as applicable, monitoring malfunctions, associated repairs, and required quality assurance or control activities (including, as applicable, calibration checks and required zero and span adjustments),the owner or operator shall conduct all monitoring in continuous operation (or shall collect data at all required intervals) at all times that the pollutant-specific emissions unit is operating. Data recorded during monitoring malfunctions, associated repairs, and required quality assurance or control activities shall not be used for purposes of these CAM requirements, including data averages and calculations, or fulfilling a minimum data availability requirement, if applicable. The owner or operator shall use all the data collected during all other periods in assessing the operation of the control device and associated control system. A monitoring malfunction is any sudden,infrequent,not reasonably preventable failure of the monitoring to provide valid data. Monitoring failures that are caused in part by poor maintenance or Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 118 careless operation are not malfunctions (40 CFR Part 64 § 64.7(c), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 13.1.2.3 Response to excursions or exceedances a. Upon detecting an excursion or exceedance,the owner or operator shall restore operation of the pollutant-specific emissions unit(including the control device and associated capture system) to its normal or usual manner of operation as expeditiously as practicable in accordance with good air pollution control practices for minimizing emissions. The response shall include minimizing the period of any startup, shutdown or malfunction and taking any necessary corrective actions to restore normal operation and prevent the likely recurrence of the cause of an excursion or exceedance(other than those caused by excused startup or shutdown conditions). Such actions may include initial inspection and evaluation, recording that operations returned to normal without operator action (such as through response by a computerized distribution control system), or any necessary follow-up actions to return operation to within the indicator range, designated condition, or below the applicable emission limitation or standard, as applicable (40 CFR Part 64 § 64.7(d)(1), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). b. Determination of whether the owner of operator has used acceptable procedures in response to an excursion or exceedance will be based on information available, which may include but is not limited to, monitoring results, review of operation and maintenance procedures and records, and inspection of the control device,associated capture system,and the process(40 CFR Part 64 § 64.7(d)(2), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 13.1.2.4 After approval of the monitoring required under the CAM requirements, if the owner or operator identifies a failure to achieve compliance with an emission limitation or standard for which the approved monitoring did not provide an indication of an excursion or exceedance while providing valid data, or the results of compliance or performance testing document a need to modify the existing indicator ranges or designated conditions, the owner or operator shall promptly notify the Division and, if necessary submit a proposed modification for this permit to address the necessary monitoring changes. Such a modification may include, but is not limited to, reestablishing indicator ranges or designated conditions,modifying the frequency of conducting monitoring and collecting data, or the monitoring of additional parameters (40 CFR Part 64 § 64.7(e), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 119 13.1.3 Quality Improvement Plan (QIP) Requirements 13.1.3.1 Based on the results of a determination made under the provisions of Condition 13.1.2.3b, the Division may require the owner or operator to develop and implement a QIP (40 CFR Part 64 § 64.8(a), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 13.1.3.2 The owner or operator shall maintain a written QIP, if required, and have it available for inspection (40 CFR Part 64 § 64.8(b)(1), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 13.1.3.3 The QIP initially shall include procedures for evaluating the control performance problems and, based on the results of the evaluation procedures, the owner or operator shall modify the plan to include procedures for conducting one or more of the following actions, as appropriate: a. Improved preventative maintenance practices (40 CFR Part 64 § 64.8(b)(2)(i), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). b. Process operation changes (40 CFR Part 64 § 64.8(b)(2)(ii), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). c. Appropriate improvements to control methods (40 CFR Part 64 § 64.8(b)(2)(iii), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). d. Other steps appropriate to correct control performance (40 CFR Part 64 § 64.8(b)(2)(iv), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). e. More frequent or improved monitoring (only in conjunction with one or more steps under Conditions a through d above) (40 CFR Part 64 § 64.8(b)(2)(v),as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 13.1.3.4 If a QIP is required, the owner or operator shall develop and implement a QIP as expeditiously as practicable and shall notify the Division if the period for completing the improvements contained in the QIP exceeds 180 days from the date on which the need to implement the QIP was determined (40 CFR Part 64 § 64.8(c), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 13.1.3.5 Following implementation of a QIP, upon any subsequent determination pursuant to Condition 13.1.2.3b,the Division or the U.S. EPA may require that an owner or Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 120 operator make reasonable changes to the QIP if the QIP is found to have: a. Failed to address the cause of the control device performance problems (40 CFR Part 64 § 64.8(d)(1), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV); or b. Failed to provide adequate procedures for correcting control device performance problems as expeditiously as practicable in accordance with good air pollution control practices for minimizing emissions (40 CFR Part 64 § 64.8(d)(2), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 13.1.3.6 Implementation of a QIP shall not excuse the owner or operator of a source from compliance with any existing emission limitation or standard, or any existing monitoring,testing, reporting or recordkeeping requirement that may apply under federal, state, or local law, or any other applicable requirements under the federal clean air act (40 CFR Part 64 § 64.8(e), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 13.1.4 Reporting and Recordkeeping Requirements 13.1.4.1 Reporting Requirements: The reports required by Section IV, Condition 22.d, shall contain the information specified in Appendix B of the permit and the following information, as applicable: a. Summary information on the number, duration and cause (including unknown cause, if applicable), for monitor downtime incidents (other than downtime associated with zero and span or other daily calibration checks, if applicable) ((40 CFR Part 64 § 64.9(a)(2)(ii), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV); and b. The owner or operator shall submit, if necessary, a description of the actions taken to implement a QIP during the reporting period as specified in Condition 13.1.3 of this permit. Upon completion of a QIP, the owner or operator shall include in the next summary report documentation that the implementation of the plan has been completed and reduced the likelihood of similar levels of excursions or exceedances occurring (40 CFR Part 64 § 64.9(a)(2)(iii), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 13.1.4.2 General Recordkeeping Requirements: In addition to the recordkeeping requirements in Section IV, Condition 22.a through 22.c. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 121 a. The owner or operator shall maintain records of any written QIP required pursuant to Condition 13.1.3 and any activities undertaken to implement a QIP, and any supporting information required to be maintained under these CAM requirements (such as data used to document the adequacy of monitoring, or records of monitoring maintenance or corrective actions) (40 CFR Part 64 § 64.9(b)(1), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). b. Instead of paper records, the owner or operator may maintain records on alternative media, such as microfilm, computer files, magnetic tape disks, or microfiche, provided that the use of such alternative media allows for expeditious inspection and review, and does not conflict with other applicable recordkeeping requirements (40 CFR Part 64 § 64.9(b)(2), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 13.1.5 Savings Provisions 13.1.5.1 Nothing in these CAM requirements shall excuse the owner or operator of a source from compliance with any existing emission limitation or standard,or any existing monitoring, testing, reporting or recordkeeping requirement that may apply under federal, state, or local law, or any other applicable requirements under the federal clean air act. These CAM requirements shall not be used to justify the approval of monitoring less stringent than the monitoring which is required under separate legal authority and are not intended to establish minimum requirements for the purposes of determining the monitoring to be imposed under separate authority under the federal clean air act, including monitoring in permits issued pursuant to title I of the federal clean air act. The purpose of the CAM requirements is to require, as part of the issuance of this Title V operating permit, improved or new monitoring at those emissions units where monitoring requirements do not exist or are inadequate to meet the requirements of CAM (40 CFR Part 64 § 64.10(a)(1), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 13.1.5.2 Nothing in these CAM requirements shall restrict or abrogate the authority of the U.S. EPA or the Division to impose additional or more stringent monitoring, recordkeeping, testing or reporting requirements on any owner or operator of a source under any provision of the federal clean air act, including but not limited to sections 114(a)(1) and 504(b), or state law, as applicable (40 CFR Part 64 § 64.10(a)(2),as adopted by reference in Colorado Regulation No. 3,Part C, Section XIV). 13.1.5.3 Nothing in these CAM requirements shall restrict or abrogate the authority of the Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 122 U.S. EPA or the Division to take any enforcement action under the federal clean air act for any violation of an applicable requirement or of any person to take action under section 304 of the federal clean air act (40 CFR Part 64 § 64.10(a)(2), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 123 14. Portable Monitoring(ver.6/26/2014) 14.1 Emission measurements of nitrogen oxides (NOx) and carbon monoxide (CO) shall be conducted quarterly using a portable flue gas analyzer. At least one calendar month shall separate the quarterly tests. Note that if the engine is operated for less than 100 hrs in any quarterly period, then the portable monitoring requirements do not apply. 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 website at: https://www.colorado.gov/pacific/cdphe/portable-analyzer-monitoring-protocol Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual or short term 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. 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. For comparison with the emission rates/factors, the emission rates/factors determined by the portable analyzer tests and approved by the Division shall be converted to the same units as the emission rates/factors in the permit. If the portable analyzer tests shows that either the NOx or CO emission rates/factors are greater than the relevant ones set forth in the permit, and in the absence of subsequent testing results to the contrary (as approved by the Division), the permittee shall apply for a modification to this permit to reflect, at a minimum, the higher emission rate/factor within 60 days of the completion of the test. Results of all tests conducted shall be kept on site and made available to the Division upon request. 14.1.1 The outlet oxygen content of the exhaust stream shall be measured during portable monitoring when measurement of the outlet CO content is being conducted. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 124 SECTION III- Permit Shield Regulation No. 3, 5 CCR 1001-5, Part C, §§ I.A.4, V.D. & XIII.B; § 25-7-114.4(3)(a), C.R.S. 1. Specific Non-Applicable Requirements Based upon the information available to the Division and supplied by the applicant,the following parameters and requirements have been specifically identified as non-applicable to the facility to which this permit has been issued. This shield does not protect the source from any violations that occurred prior to or at the time of permit issuance. In addition, this shield does not protect the source from any violations that occur as a result of any modification or reconstruction on which construction commenced prior to permit issuance. Emission Unit Description& Applicable Justification Number Requirement C-124 WaukeshaF-11G, 125 hp C-116 WaukeshaL-7042 GSI, 1,100 hp C-117 Waukesha L-7042 GSI, 1,100 hp C-118 Waukesha L-7042 GSI, 1,100 hp Colorado Regulation No. 1 Section Internal combustion engines are not considered fuel C-119 Waukesha L-7042 GSI, 1,100 hp III.A.1.b burning equipment for the purposes of the referenced C-120 Waukesha L-7042 GSI, 1,100 hp regulation. C-123 Waukesha L-7042 GSI,896 hp C-152 Waukesha L-7042 GSI, 1,100 hp C-122 Waukesha L-7042 GSI, 1,100 hp Colorado Regulation No.7,Part B, Section IV.B.1 These regulations are intended to apply to gasoline storage and loading facilities and are therefore not Colorado Regulation applicable to condensate at a natural gas processing plant. No.7,Part B, Facility-Wide Section IV.B.2 This regulation requires crude oil storage tanks over Colorado Regulation 40,000 gallons to comply with selected requirements No.7,Part B, from Colorado Regulation No. 7 Section VI.This natural Section V.C gas processing plant does not store crude oil,and is therefore not required to comply with this requirement. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 125 2. General Conditions Compliance with this Operating Permit shall be deemed compliance with all applicable requirements specifically identified in the permit and other requirements specifically identified in the permit as not applicable to the source. This permit shield shall not alter or affect the following: 2.1 The provisions of§§ 25-7-112 and 25-7-113, C.R.S., or § 303 of the federal act, concerning enforcement in cases of emergency; 2.2 The liability of an owner or operator of a source for any violation of applicable requirements prior to or at the time of permit issuance. 2.3 The applicable requirements of the federal Acid Rain Program,consistent with §408(a)of the federal act; 2.4 The ability of the Air Pollution Control Division to obtain information from a source pursuant to § 25-7- 111(2)(I), C.R.S.,or the ability of the Administrator to obtain information pursuant to § 114 of the federal act; 2.5 The ability of the Air Pollution Control Division to reopen the Operating Permit for cause pursuant to Regulation No. 3, Part C, § XIII. 2.6 Sources are not shielded from terms and conditions that become applicable to the source subsequent to permit issuance. 3. Streamlined Conditions 3.1 The following applicable requirements have been subsumed within this operating permit using the pertinent streamlining procedures approved by the U.S. EPA. For purposes of the permit shield, compliance with the listed permit conditions will also serve as a compliance demonstration for purposes of the associated subsumed requirements. Permit Condition Streamlined(Subsumed)Requirements Section II,Conditions 3.2 and 4.2 Colorado Regulation No.6,Part B,Section II.C.2[fuel burning equipment particulate matter requirement]—State-Only Requirement Section IV,Conditions 22.b and 22.c 40 CFR Part 60 Subpart Dc NSPS [requirement to maintain records for 2 years only; §60.48c(i))]—less stringent than 5 year Title V retention requirements Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 126 Section IV- General Permit Conditions (ver.1/21/2020) 1. Administrative Changes Regulation No.3,5 CCR 1001-5,Part A, §III. The permittee shall submit an application for an administrative permit amendment to the Division for those permit changes that are described in Regulation No. 3,Part A, § I.B.1. The permittee may immediately make the change upon submission of the application to the Division. 2. Certification Requirements Regulation No.3,5 CCR 1001-5,Part C, III.B.9.,V.C.16.a.&e.and V.C.17. a. Any application, report, document and compliance certification submitted to the Air Pollution Control Division pursuant to Regulation No.3 or the Operating Permit shall contain a certification by a responsible official of the truth, accuracy and completeness of such form,report or certification stating that,based on information and belief formed after reasonable inquiry,the statements and information in the document are true,accurate and complete. b. All compliance certifications for terms and conditions in the Operating Permit shall be submitted to the Air Pollution Control Division at least annually unless a more frequent period is specified in the applicable requirement or by the Division in the Operating Permit. c. Compliance certifications shall contain: (i) the identification of each permit term and condition that is the basis of the certification; (ii) the compliance status of the source; (iii) whether compliance was continuous or intermittent; (iv) method(s)used for determining the compliance status of the source,currently and over the reporting period; and (v) such other facts as the Air Pollution Control Division may require to determine the compliance status of the source. d. All compliance certifications shall be submitted to the Air Pollution Control Division and to the Environmental Protection Agency at the addresses listed in Appendix D of this Permit. e. If the permittee is required to develop and register a risk management plan pursuant to§ 112(r)of the federal act,the permittee shall certify its compliance with that requirement; the Operating Permit shall not incorporate the contents of the risk management plan as a permit term or condition. 3. Common Provisions Common Provisions Regulation,5 CCR 1001-2 II.I,and II.J a. To Control Emissions Leaving Colorado Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit#95OPWE038 Page 127 When emissions generated from sources in Colorado cross the State boundary line,such emissions shall not cause the air quality standards of the receiving State to be exceeded,provided reciprocal action is taken by the receiving State. b. Emission Monitoring Requirements The Division may require owners or operators of stationary air pollution sources to install, maintain, and use instrumentation to monitor and record emission data as a basis for periodic reports to the Division. c. Performance Testing The owner or operator of any air pollution source shall,upon request of the Division,conduct performance test(s)and furnish the Division a written report of the results of such test(s) in order to determine compliance with applicable emission control regulations. Performance test(s)shall be conducted and the data reduced in accordance with the applicable reference test methods unless the Division: (i) specifies or approves,in specific cases,the use of a test method with minor changes in methodology; (ii) approves the use of an equivalent method; (iii) approves the use of an alternative method the results of which the Division has determined to be adequate for indicating where a specific source is in compliance;or (iv) waives the requirement for performance test(s)because the owner or operator of a source has demonstrated by other means to the Division's satisfaction that the affected facility is in compliance with the standard. Nothing in this paragraph shall be construed to abrogate the Commission's or Division's authority to require testing under the Colorado Revised Statutes,Title 25,Article 7,and pursuant to regulations promulgated by the Commission. Compliance test(s)shall be conducted under such conditions as the Division shall specify to the plant operator based on representative performance of the affected facility.The owner or operator shall make available to the Division such records as may be necessary to determine the conditions of the performance test(s). Operations during period of startup, shutdown, and malfunction shall not constitute representative conditions of performance test(s) unless otherwise specified in the applicable standard. The owner or operator of an affected facility shall provide the Division thirty days prior notice of the performance test to afford the Division the opportunity to have an observer present. The Division may waive the thirty day notice requirement provided that arrangements satisfactory to the Division are made for earlier testing. The owner or operator of an affected facility shall provide,or cause to be provided,performance testing facilities as follows: (i) Sampling ports adequate for test methods applicable to such facility; (ii) Safe sampling platform(s); (iii) Safe access to sampling platform(s);and Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 128 (iv) Utilities for sampling and testing equipment. Each performance test shall consist of at least three separate runs using the applicable test method.Each run shall be conducted for the time and under the conditions specified in the applicable standard. For the purpose of determining compliance with an applicable standard,the arithmetic mean of results of at least three runs shall apply.In the event that a sample is accidentally lost or conditions occur in which one of the runs must be discontinued because of forced shutdown, failure of an irreplaceable portion of the sample train, extreme meteorological conditions, or other circumstances beyond the owner or operator's control,compliance may,upon the Division's approval,be determined using the arithmetic mean of the results of the two other runs. Nothing in this section shall abrogate the Division's authority to conduct its own performance test(s) if so warranted. d. Affirmative Defense Provision for Excess Emissions during Malfunctions An affirmative defense to a claim of violation under these regulations is provided to owners and operators for civil penalty actions for excess emissions during periods of malfunction. To establish the affirmative defense and to be relieved of a civil penalty in any action to enforce an applicable requirement,the owner or operator of the facility must meet the notification requirements below in a timely manner and prove by a preponderance of evidence that: (i) The excess emissions were caused by a sudden, unavoidable breakdown of equipment, or a sudden, unavoidable failure of a process to operate in the normal or usual manner,beyond the reasonable control of the owner or operator; (ii) The excess emissions did not stem from any activity or event that could have reasonably been foreseen and avoided,or planned for,and could not have been avoided by better operation and maintenance practices; (iii) Repairs were made as expeditiously as possible when the applicable emission limitations were being exceeded; (iv) The amount and duration of the excess emissions (including any bypass)were minimized to the maximum extent practicable during periods of such emissions; (v) All reasonably possible steps were taken to minimize the impact of the excess emissions on ambient air quality; (vi) All emissions monitoring systems were kept in operation(if at all possible); (vii) The owner or operator's actions during the period of excess emissions were documented by properly signed, contemporaneous operating logs or other relevant evidence; (viii) The excess emissions were not part of a recurring pattern indicative of inadequate design, operation, or maintenance; (ix) At all times,the facility was operated in a manner consistent with good practices for minimizing emissions. This section is intended solely to be a factor in determining whether an affirmative defense is available to an owner or operator,and shall not constitute an additional applicable requirement;and Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 129 (x) During the period of excess emissions, there were no exceedances of the relevant ambient air quality standards established in the Commissions' Regulations that could be attributed to the emitting source. The owner or operator of the facility experiencing excess emissions during a malfunction shall notify the division verbally as soon as possible, but no later than noon of the Division's next working day, and shall submit written notification following the initial occurrence of the excess emissions by the end of the source's next reporting period. The notification shall address the criteria set forth above. The Affirmative Defense Provision contained in this section shall not be available to claims for injunctive relief. The Affirmative Defense Provision does not apply to failures to meet federally promulgated performance standards or emission limits, including, but not limited to,new source performance standards and national emission standards for hazardous air pollutants.The affirmative defense provision does not apply to state implementation plan(sip)limits or permit limits that have been set taking into account potential emissions during malfunctions, including, but not necessarily limited to, certain limits with 30-day or longer averaging times, limits that indicate they apply during malfunctions,and limits that indicate they apply at all times or without exception. e. Circumvention Clause A person shall not build,erect, install,or use any article, machine,equipment,condition,or any contrivance,the use of which,without resulting in a reduction in the total release of air pollutants to the atmosphere,reduces or conceals an emission which would otherwise constitute a violation of this regulation.No person shall circumvent this regulation by using more openings than is considered normal practice by the industry or activity in question. f. Compliance Certifications For the purpose of submitting compliance certifications or establishing whether or not a person has violated or is in violation of any standard in the Colorado State Implementation Plan,nothing in the Colorado State Implementation Plan shall preclude the use,including the exclusive use,of any credible evidence or information,relevant to whether a source would have been in compliance with applicable requirements if the appropriate performance or compliance test or procedure had been performed. Evidence that has the effect of making any relevant standard or permit term more stringent shall not be credible for proving a violation of the standard or permit term. When compliance or non-compliance is demonstrated by a test or procedure provided by permit or other applicable requirement, the owner or operator shall be presumed to be in compliance or non-compliance unless other relevant credible evidence overcomes that presumption. g. Affirmative Defense Provision for Excess Emissions During Startup and Shutdown An affirmative defense is provided to owners and operators for civil penalty actions for excess emissions during periods of startup and shutdown.To establish the affirmative defense and to be relieved of a civil penalty in any action to enforce an applicable requirement, the owner or operator of the facility must meet the notification requirements below in a timely manner and prove by a preponderance of the evidence that: (i) The periods of excess emissions that occurred during startup and shutdown were short and infrequent and could not have been prevented through careful planning and design; Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 130 (ii) The excess emissions were not part of a recurring pattern indicative of inadequate design, operation or maintenance; (iii) If the excess emissions were caused by a bypass (an intentional diversion of control equipment), then the bypass was unavoidable to prevent loss of life,personal injury,or severe property damage; (iv) The frequency and duration of operation in startup and shutdown periods were minimized to the maximum extent practicable; (v) All possible steps were taken to minimize the impact of excess emissions on ambient air quality; (vi) All emissions monitoring systems were kept in operation(if at all possible); (vii) The owner or operator's actions during the period of excess emissions were documented by properly signed, contemporaneous operating logs or other relevant evidence;and, (viii) At all times,the facility was operated in a manner consistent with good practices for minimizing emissions. This subparagraph is intended solely to be a factor in determining whether an affirmative defense is available to an owner or operator,and shall not constitute an additional applicable requirement. The owner or operator of the facility experiencing excess emissions during startup and shutdown shall notify the Division verbally as soon as possible,but no later than two(2)hours after the start of the next working day,and shall submit written quarterly notification following the initial occurrence of the excess emissions. The notification shall address the criteria set forth above. The Affirmative Defense Provision contained in this section shall not be available to claims for injunctive relief. The Affirmative Defense Provision does not apply to State Implementation Plan provisions or other requirements that derive from new source performance standards or national emissions standards for hazardous air pollutants, or any other federally enforceable performance standard or emission limit with an averaging time greater than twenty-four hours. In addition, an affirmative defense cannot be used by a single source or small group of sources where the excess emissions have the potential to cause an exceedance of the ambient air quality standards or Prevention of Significant Deterioration(PSD)increments. In making any determination whether a source established an affirmative defense, the Division shall consider the information within the notification required above and any other information the Division deems necessary, which may include, but is not limited to, physical inspection of the facility and review of documentation pertaining to the maintenance and operation of process and air pollution control equipment. 4. Compliance Requirements Regulation No.3,5 CCR 1001-5,Part C, III.C.9.,V.C.11.& 16.d.and 25-7-122.1(2),C.R.S. a. The permittee must comply with all conditions of the Operating Permit. Any permit noncompliance relating to federally-enforceable terms or conditions constitutes a violation of the federal act, as well as the state act and Regulation No.3. Any permit noncompliance relating to state-only terms or conditions constitutes a violation of the state act and Regulation No. 3, shall be enforceable pursuant to state law, and shall not be enforceable by citizens under§ 304 of the federal act. Any such violation of the federal act,the state act or regulations implementing either Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 131 statute is grounds for enforcement action, for permit termination, revocation and reissuance or modification or for denial of a permit renewal application. b. It shall not be a defense for a permittee in an enforcement action or a consideration in favor of a permittee in a permit termination,revocation or modification action or action denying a permit renewal application that it would have been necessary to halt or reduce the permitted activity in order to maintain compliance with the conditions of the permit. c. The permit may be modified,revoked,reopened,and reissued,or terminated for cause. The filing of any request by the permittee for a permit modification, revocation and reissuance, or termination, or any notification of planned changes or anticipated noncompliance does not stay any permit condition, except as provided in §§ X. and XI. of Regulation No.3,Part C. d. The permittee shall furnish to the Air Pollution Control Division,within a reasonable time as specified by the Division, any information that the Division may request in writing to determine whether cause exists for modifying, revoking and reissuing,or terminating the permit or to determine compliance with the permit. Upon request,the permittee shall also furnish to the Division copies of records required to be kept by the permittee, including information claimed to be confidential. Any information subject to a claim of confidentiality shall be specifically identified and submitted separately from information not subject to the claim. e. Any schedule for compliance for applicable requirements with which the source is not in compliance at the time of permit issuance shall be supplemental, and shall not sanction noncompliance with, the applicable requirements on which it is based. f. For any compliance schedule for applicable requirements with which the source is not in compliance at the time of permit issuance,the permittee shall submit,at least every 6 months unless a more frequent period is specified in the applicable requirement or by the Air Pollution Control Division,progress reports which contain the following: (i) dates for achieving the activities, milestones, or compliance required in the schedule for compliance, and dates when such activities,milestones,or compliance were achieved;and (ii) an explanation of why any dates in the schedule of compliance were not or will not be met,and any preventive or corrective measures adopted. g. The permittee shall not knowingly falsify,tamper with,or render inaccurate any monitoring device or method required to be maintained or followed under the terms and conditions of the Operating Permit. 5. Emergency Provisions Regulation No.3,5 CCR 1001-5,Part C, §VII An emergency means any situation arising from sudden and reasonably unforeseeable events beyond the control of the source, including acts of God, which situation requires immediate corrective action to restore normal operation, and that causes the source to exceed the technology-based emission limitation under the permit due to unavoidable increases in emissions attributable to the emergency. "Emergency" does not include noncompliance to the extent caused by improperly designed equipment, lack of preventative maintenance,careless or improper operation,or operator error. An emergency constitutes an affirmative defense to an enforcement action brought for noncompliance with a technology-based emission limitation if the permittee demonstrates,through properly signed,contemporaneous operating logs,or other relevant evidence that: Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 132 a. an emergency occurred and that the permittee can identify the cause(s)of the emergency; b. the permitted facility was at the time being properly operated; c. during the period of the emergency the permittee took all reasonable steps to minimize levels of emissions that exceeded the emission standards,or other requirements in the permit;and d. the permittee submitted oral notice of the emergency to the Air Pollution Control Division no later than noon of the next working day following the emergency, and followed by written notice within one month of the time when emissions limitations were exceeded due to the emergency. This notice must contain a description of the emergency, any steps taken to mitigate emissions,and corrective actions taken. This emergency provision is in addition to any emergency or malfunction provision contained in any applicable requirement. 6. Emission Controls for Asbestos Regulation No. 8,5 CCR 1001-10,Part B The permittee shall not conduct any asbestos abatement activities except in accordance with the provisions of Regulation No. 8,Part B,"asbestos control." 7. Emissions Trading,Marketable Permits,Economic Incentives Regulation No.3,5 CCR 1001-5,Part C, &V.C.13. No permit revision shall be required under any approved economic incentives,marketable permits,emissions trading and other similar programs or processes for changes that are specifically provided for in the permit. 8. Fee Payment C.R.S §§25-7-114.1(6)and 25-7-114.7 a. The permittee shall pay an annual emissions fee in accordance with the provisions of C.R.S. §25-7-114.7. A 1%per month late payment fee shall be assessed against any invoice amounts not paid in full on the 91st day after the date of invoice,unless a permittee has filed a timely protest to the invoice amount. b. The permittee shall pay a permit processing fee in accordance with the provisions of C.R.S. § 25-7-114.7. If the Division estimates that processing of the permit will take more than 30 hours,it will notify the permittee of its estimate of what the actual charges may be prior to commencing any work exceeding the 30 hour limit. c. The permittee shall pay an APEN fee in accordance with the provisions of C.R.S. § 25-7-114.1(6)for each APEN or revised APEN filed. 9. Fugitive Particulate Emissions Regulation No. 1,5 CCR 1001-3, §III.D.1. The permittee shall employ such control measures and operating procedures as are necessary to minimize fugitive particulate emissions into the atmosphere, in accordance with the provisions of Regulation No. 1, §III.D.1. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 133 10. Inspection and Entry Regulation No.3,5 CCR 1001-5,Part C, $V.C.16.b. Upon presentation of credentials and other documents as may be required by law,the permittee shall allow the Air Pollution Control Division,or any authorized representative,to perform the following: a. enter upon the permittee's premises where an Operating Permit source is located, or emissions-related activity is conducted,or where records must be kept under the terms of the permit; b. have access to,and copy,at reasonable times,any records that must be kept under the conditions of the permit; c. inspect at reasonable times any facilities, equipment (including monitoring and air pollution control equipment), practices,or operations regulated or required under the Operating Permit; • d. sample or monitor at reasonable times,for the purposes of assuring compliance with the Operating Permit or applicable requirements,any substances or parameters. 11. Minor Permit Modifications Regulation No.3,5 CCR 1001-5,Part C, tic X.&XI. The permittee shall submit an application for a minor permit modification before making the change requested in the application. The permit shield shall not extend to minor permit modifications. 12. New Source Review Regulation No.3,5 CCR 1001-5,Parts B&D The permittee shall not commence construction or modification of a source required to be reviewed under the New Source Review provisions of Regulation No.3,Parts B and/or D,as applicable,without first receiving a construction permit. 13. No Property Rights Conveyed Regulation No.3,5 CCR 1001-5,Part C,&V.C.11.d. This permit does not convey any property rights of any sort,or any exclusive privilege. 14. Odor Regulation No.2,5 CCR 1001-4,Part A As a matter of state law only,the permittee shall comply with the provisions of Regulation No.2 concerning odorous emissions. 15. Off-Permit Changes to the Source Regulation No.3,5 CCR 1001-5,Part C, §XII.B. The permittee shall record any off-permit change to the source that causes the emissions of a regulated pollutant subject to an applicable requirement,but not otherwise regulated under the permit, and the emissions resulting from the change,including Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 134 any other data necessary to show compliance with applicable ambient air quality standards. The permittee shall provide contemporaneous notification to the Air Pollution Control Division and to the Environmental Protection Agency at the addresses listed in Appendix D of this Permit. The permit shield shall not apply to any off-permit change. 16. Opacity Regulation No. 1,5 CCR 1001-3, ,$§I.,II. The permittee shall comply with the opacity emissions limitation set forth in Regulation No. 1,§§ I.-II. 17. Open Burning Regulation No.9,5 CCR 1001-11 The permittee shall obtain a permit from the Division for any regulated open burning activities in accordance with provisions of Regulation No.9. 18. Ozone Depleting Compounds Regulation No. 15,5 CCR 1001-19 The permittee shall comply with the provisions of Regulation No. 15 concerning emissions of ozone depleting compounds. Sections I.,II.C.,II.D.,III.IV.,and V.of Regulation No. 15 shall be enforced as a matter of state law only. 19. Permit Expiration and Renewal Regulation No.3,5 CCR 1001-5,Part C, §§III.B.6.,IV.C.,V.C.2. a. The permit term shall be five(5)years. The permit shall expire at the end of its term. Permit expiration terminates the permittee's right to operate unless a timely and complete renewal application is submitted. b. Applications for renewal shall be submitted at least twelve months,but not more than 18 months,prior to the expiration of the Operating Permit. An application for permit renewal may address only those portions of the permit that require revision,supplementing,or deletion,incorporating the remaining permit terms by reference from the previous permit. A copy of any materials incorporated by reference must be included with the application. 20. Portable Sources Regulation No.3,5 CCR 1001-5,Part C, II.D. Portable Source permittees shall notify the Air Pollution Control Division at least 10 days in advance of each change in location. 21. Prompt Deviation Reporting Regulation No.3,5 CCR 1001-5,Part C, §V.C.7.b. The permittee shall promptly report any deviation from permit requirements, including those attributable to malfunction conditions as defined in the permit,the probable cause of such deviations,and any corrective actions or preventive measures taken. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 135 "Prompt"is defined as follows: a. Any definition of"prompt" or a specific timeframe for reporting deviations provided in an underlying applicable requirement as identified in this permit;or b. Where the underlying applicable requirement fails to address the time frame for reporting deviations, reports of deviations will be submitted based on the following schedule: (i) For emissions of a hazardous air pollutant or a toxic air pollutant(as identified in the applicable regulation) that continue for more than an hour in excess of permit requirements, the report shall be made within 24 hours of the occurrence; (ii) For emissions of any regulated air pollutant,excluding a hazardous air pollutant or a toxic air pollutant that continue for more than two hours in excess of permit requirements,the report shall be made within 48 hours; and (iii) For all other deviations from permit requirements,the report shall be submitted every six(6)months,except as otherwise specified by the Division in the permit in accordance with paragraph 22.d.below. c. If any of the conditions in paragraphs b.i or b.ii above are met,the source shall notify the Division by telephone(303- 692-3155) or facsimile (303-782-0278) based on the timetables listed above. [Explanatory note: Notification by telephone or facsimile must sped that this notification is a deviation report for an Operating Permit.] A written notice,certified consistent with General Condition 2.a.above(Certification Requirements),shall be submitted within 10 working days of the occurrence. All deviations reported under this section shall also be identified in the 6-month report required above. "Prompt reporting"does not constitute an exception to the requirements of"Emergency Provisions"for the purpose of avoiding enforcement actions. 22. Record Keeping and Reporting Requirements Regulation No.3,5 CCR 1001-5,Part A, $II.;Part C,$&V.C.6.,V.C.7. a. Unless otherwise provided in the source specific conditions of this Operating Permit, the permittee shall maintain compliance monitoring records that include the following information: (i) date,place as defined in the Operating Permit,and time of sampling or measurements; (ii) date(s)on which analyses were performed; (iii) the company or entity that performed the analysis; (iv) • the analytical techniques or methods used; (v) the results of such analysis; and (vi) the operating conditions at the time of sampling or measurement. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 136 b. The permittee shall retain records of all required monitoring data and support information for a period of at least five (5)years from the date of the monitoring sample, measurement, report or application. Support information, for this purpose, includes all calibration and maintenance records and all original strip-chart recordings for continuous monitoring instrumentation, and copies of all reports required by the Operating Permit. With prior approval of the Air Pollution Control Division,the permittee may maintain any of the above records in a computerized form. c. Permittees must retain records of all required monitoring data and support information for the most recent twelve(12) month period, as well as compliance certifications for the past five(5)years on-site at all times. A permittee shall make available for the Air Pollution Control Division's review all other records of required monitoring data and support information required to be retained by the permittee upon 48 hours advance notice by the Division. d. The permittee shall submit to the Air Pollution Control Division all reports of any required monitoring at least every six(6)months,unless an applicable requirement,the compliance assurance monitoring rule,or the Division requires submission on a more frequent basis. All instances of deviations from any permit requirements must be clearly identified in such reports. e. The permittee shall file an Air Pollutant Emissions Notice("APEN")prior to constructing,modifying,or altering any facility,process,activity which constitutes a stationary source from which air pollutants are or are to be emitted,unless such source is exempt from the APEN filing requirements of Regulation No. 3,Part A, § II.D or as provided for in Regulation No. 3,Part A, § II.A.2 for oil and gas well production facilities.A revised APEN shall be filed annually whenever a significant change in emissions,as defined in Regulation No.3,Part A, §II.C.2.,occurs;whenever there is a change in owner or operator of any facility, process, or activity; whenever new control equipment is installed; whenever a different type of control equipment replaces an existing type of control equipment; whenever a permit limitation must be modified;or before the APEN expires. An APEN is valid for a period of five years.The five-year period recommences when a revised APEN is received by the Air Pollution Control Division.Revised APENs shall be submitted no later than 30 days before the five-year term expires.Permittees submitting revised APENs to inform the Division of a change in actual emission rates must do so by April 30 of the following year.Where a permit revision is required,the revised APEN must be filed along with a request for permit revision. APENs for changes in control equipment must be submitted before the change occurs, except an APEN shall be filed once per year for control equipment at condensate storage tanks located at oil and gas exploration and production facilities subject to Regulation No.7,Part D§I.Annual fees are based on the most recent APEN on file with the Division. 23. Reopenings for Cause Regulation No.3,5 CCR 1001-5,Part C, §XIII. a. The Air Pollution Control Division shall reopen, revise, and reissue Operating Permits; permit reopenings and reissuance shall be processed using the procedures set forth in Regulation No.3,Part C,§III.,except that proceedings to reopen and reissue permits affect only those parts of the permit for which cause to reopen exists. b. The Division shall reopen a permit whenever additional applicable requirements become applicable to a major source with a remaining permit term of three or more years,unless the effective date of the requirements is later than the date on which the permit expires, or unless a general permit is obtained to address the new requirements; whenever additional requirements(including excess emissions requirements)become applicable to an affected source under the acid rain program; whenever the Division determines the permit contains a material mistake or that inaccurate statements were made in establishing the emissions standards or other terms or conditions of the permit;or whenever Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 137 the Division determines that the permit must be revised or revoked to assure compliance with an applicable requirement. c. The Division shall provide 30 days' advance notice to the permittee of its intent to reopen the permit, except that a shorter notice may be provided in the case of an emergency. d. The permit shield shall extend to those parts of the permit that have been changed pursuant to the reopening and reissuance procedure. 24. Requirements for Major Stationary Sources Regulation No.3,5 CCR 1001-5,Part D, §§V.A.7.c&d,VI.B.5&VI.B.6 The following provisions apply to projects at existing emissions units at a major stationary source (other than projects at a source with a PAL) that are not part of a major modification and where the owner or operator relies on projected actual emissions. The definitions of baseline actual emissions, major modification, major stationary source, PAL, projected actual emissions,regulated NSR pollutant and significant can be found in Regulation No.3,Part D, §ILA. a. Before beginning actual construction of the project,the owner or operator shall document and maintain a record of the following information: (i) a description of the project; (ii) identification of the emissions unit(s)whose emissions of a regulated NSR pollutant could be affected by the project;and (iii) a description of the applicability test used to determine the project is not a major modification for any regulated NSR pollutants,including the baseline actual emissions,the projected actual emissions,the amount of emissions excluded and an explanation for why such amount was excluded,and any netting calculations, if applicable. b. The owner or operator shall monitor emissions of any regulated NSR pollutant that could increase as a result of the project from any emissions units identified in paragraph a(ii) and calculate and maintain a record of the annual emissions, in tons per year on a calendar year basis, for a period of five (5) years following resumption of regular operation after the change,or for a period of ten(10)years following resumption of regular operation after the change if the project increases the design capacity or potential to emit of that regulated NSR pollutant at such emissions unit. c. For existing electric utility steam generating units the following requirements apply: (I) Before beginning actual construction,the owner or operator shall provide a copy of the information required by paragraph a above to the Division. The owner or operator is not required to obtain a determination from the Division prior to beginning actual construction. (ii) The owner or operate shall submit a report to the Division within sixty days after the end of each year during which records must be generated under paragraph b above setting out the unit's annual emissions during the calendar year that preceded submission of the report. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 138 d. For existing emissions units that are not electric utility steam generating units,the owner or operator shall submit a report to the Division if the annual emissions from the project, in tons per year,exceed the baseline actual emissions (documented and maintained per paragraph a(iii)) by a significant amount for that regulated NSR pollutant, and if such emissions differ from the preconstruction projection (documented and maintained per paragraph a(iii)). Such report shall be submitted to the Division within sixty days after the end of such year. The report shall contain the following: - (i) The name,address and telephone number of the owner or operator; (ii) The annual emissions as calculated per paragraph b;and (iii) Any other information that the owner or operator wishes to include in the report. e. The owner of operation of the source shall make the information in paragraph a available for review upon request to the Division or the general public. 25. Section 502(b)(10)Changes Regulation No.3,5 CCR 1001-5,Part C,& XII.A. The permittee shall provide a minimum 7-day advance notification to the Air Pollution Control Division and to the Environmental Protection Agency at the addresses listed in Appendix D of this Permit. The permittee shall attach a copy of each such notice given to its Operating Permit. 26. Severability Clause Regulation No.3,5 CCR 1001-5,Part C, § V.C.10. In the event of a challenge to any portion of the permit,all emissions limits,specific and general conditions,monitoring,record keeping and reporting requirements of the permit,except those being challenged,remain valid and enforceable. 27. Significant Permit Modifications Regulation No.3,5 CCR 1001-5,Part C, &III.B.2. The permittee shall not make a significant modification required to be reviewed under Regulation No.3,Part B("Construction Permit"requirements)without first receiving a construction permit. The permittee shall submit a complete Operating Permit application or application for an Operating Permit revision for any new or modified source within twelve months of commencing operation, to the address listed in Item 1 in Appendix D of this permit. If the permittee chooses to use the "Combined Construction/Operating Permit" application procedures of Regulation No. 3, Part C, then the Operating Permit must be received prior to commencing construction of the new or modified source. 28. Special Provisions Concerning the Acid Rain Program Regulation No.3,5 CCR 1001-5,Part C, V.C.1.b.&8 a. Where an applicable requirement of the federal act is more stringent than an applicable requirement of regulations promulgated under Title IV of the federal act,40 Code of Federal Regulations(CFR)Part 72,both provisions shall be incorporated into the permit and shall be federally enforceable. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 139 b. Emissions exceeding any allowances that the source lawfully holds under Title IV of the federal act or the regulations promulgated thereunder,40 CFR Part 72,are expressly prohibited. 29. Transfer or Assignment of Ownership Regulation No.3,5 CCR 1001-5,Part C, ILC. No transfer or assignment of ownership of the Operating Permit source will be effective unless the prospective owner or operator applies to the Air Pollution Control Division on Division-supplied Administrative Permit Amendment forms, for reissuance of the existing Operating Permit. No administrative permit shall be complete until a written agreement containing a specific date for transfer of permit,responsibility,coverage,and liability between the permittee and the prospective owner or operator has been submitted to the Division. 30. Volatile Organic Compounds Regulation No.7,5 CCR 1001-9,Part B, &§ I&III. The requirements in paragraphs a, b and e apply to sources located in the Denver 1-hour ozone attainment/maintenance area, any nonattainment area for the 1-hour ozone standard and to the 8-hour Ozone Control Area and on a state-only basis to sources located in any ozone nonattainment area,which includes areas designated nonattainment for either the 1-hour or 8-hour ozone standard,unless otherwise specified in Regulation No.7,Part A,Section I.A.1.c.The requirements in paragraphs c and d apply statewide. a. All storage tank gauging devices, anti-rotation devices, accesses, seals, hatches, roof drainage systems, support structures, and pressure relief valves shall be maintained and operated to prevent detectable vapor loss except when opened,actuated,or used for necessary and proper activities(e.g.maintenance). Such opening,actuation,or use shall be limited so as to minimize vapor loss. Detectable vapor loss shall be determined visually, by touch, by presence of odor, or using a portable hydrocarbon analyzer. When an analyzer is used,detectable vapor loss means a VOC concentration exceeding 10,000 ppm. Testing shall be conducted as in Regulation No.7,Part B, Section VI.C.3. b. Except as otherwise provided by Regulation No. 7, all volatile organic compounds, excluding petroleum liquids, transferred to any tank,container,or vehicle compartment with a capacity exceeding 212 liters(56 gallons),shall be transferred using submerged or bottom filling equipment.For top loading,the fill tube shall reach within six inches of the bottom of the tank compartment. For bottom-fill operations,the inlet shall be flush with the tank bottom. c. No person shall dispose of volatile organic compounds by evaporation or spillage unless Reasonably Available Control Technology(RACT)is utilized. d. No owner or operator of a bulk gasoline terminal, bulk gasoline plant, or gasoline dispensing facility as defined in Colorado Regulation No. 7,Part B, Sections IV.C.2., IV.C.3. and VII.A.3., shall permit gasoline to be intentionally spilled, discarded in sewers, stored in open containers, or disposed of in any other manner that would result in evaporation. e. Beer production and associated beer container storage and transfer operations involving volatile organic compounds with a true vapor pressure of less than 1.5 psia actual conditions are exempt from the provisions of paragraph b,above. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 140 31. Wood Stoves and Wood burning Appliances Regulation No.4,5 CCR 1001-6 The permittee shall comply with the provisions of Regulation No.4 concerning the advertisement,sale,installation,and use of wood stoves and wood burning appliances. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendices Page 141 OPERATING PERMIT APPENDICES A - INSPECTION INFORMATION B - MONITORING AND PERMIT DEVIATION REPORT C - COMPLIANCE CERTIFICATION REPORT D - NOTIFICATION ADDRESSES E - PERMIT ACRONYMS F - PERMIT MODIFICATIONS G - COMPLAINCE ASSURANCE MONITORING H - AOS APPLICABILITY REPORTS DISCLAIMER: None of the information found in these Appendices shall be considered to be State or Federally enforceable, except as otherwise provided in this permit, and is presented to assist the source, permitting authority, inspectors, and citizens. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix A Inspection Information Page 142 APPENDIX A-Inspection Information 1. Directions to Plant: The facility is located in the southern half of the southwest quarter of Section 25,T5N,R66 W.The plant is address is 3009 49th Street, Greeley,Colorado. Take Highway 85 north toward Greeley. Go through La Salle and across the Platte River. After crossing the river, take the next left which is 42nd Street. From 42nd Street take a left onto Industrial Parkway. Industrial Parkway will curve and turn into 49th Street. The plant is on 49th Street to the right. 2. Safety Equipment Required: • Hard Hat • Safety Shoes (Steel-Toed Boots) • Hearing Protection • Eye Protection • Fire Retardant Clothing 3. Facility Plot Plan: The attached Figure below shows the plot plan as submitted in the May 2, 2016 Significant Modification Application for the Title V Operating Permit. 4. List of Insignificant Activities: The following generic list of insignificant activities was provided in the Title V application: The following list of insignificant activities was provided by the source to assist in the understanding of the facility layout. Since there is no requirement to update such a list, activities may have changed since the last filing. The asterisk(*)denotes an insignificant activity source category based on the size of the activity,emissions levels from the activity or the production rate of the activity. The owner or operator of individual emission points in insignificant activity source categories marked with an asterisk (*) must maintain sufficient record keeping verifying that the exemption applies. Such records shall be made available for Division review upon request (Colorado Regulation No. 3, Part C, Section II.E). *Colorado Regulation No.3,Part C,Section II.E.3.a: Individual emission points in nonattainment areas having uncontrolled actual emissions of any criteria pollutant (as defined in Section I.B.17. of Part A of this Regulation Number 3) of less than one ton per year: • One (1)Niagara Cooler • Compressor Blowdowns Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix A Inspection Information Page 143 • CIG Line B lowdown • Two (2) 80 bbl Produced Water Storage Tanks (S-1086, S-1089) *Colorado Regulation No. 3, Part C, Section II.E.3.k: Each individual piece of fuel burning equipment, other than smokehouse generators and internal combustion engines, that uses gaseous fuel, and that has a design rate less than or equal to five million British thermal units per hour: • One (1) 3.45 MMBtu/hr Ethylene Glycol Unit Reboiler *Colorado Regulation No. 3,Part C, Section II.E.3.n: Chemical storage tanks or containers that hold less than five hundred gallons, that have an annual average throughput less than twenty-five gallons per day, and are not associated with either oil and gas production wastewater or commercial facilities that accept oil production wastewater for processing. • One (1) 2,000 gal Norkool Storage Tank(TK-31) • One (1) 2,000 gal Ethylene Glycol Storage Tank(TK-35) • One (1) 500 gal Petrosweet Tank(TK-0986) • One (1) 150 bbl Methanol Storage Tank(TK-30) Colorado Regulation No. 3, Part C, Section II.E.3.zz: Storage of butane, propane, or liquefied petroleum gas in a vessel with a capacity of less than sixty thousand gallons, provided the requirements of Regulation Number 7, Section IV. (now Part B, Section II.) are met, where applicable: • Five (5) 30,000 gal Pressurized Y-Grade Storage Tanks (TK-15 through TK-19) • Four(4) 30,000 gal Pressurized NGL Storage Tanks (TK-9 through TK-11, TK-14) • Two (2) 30,000 gal Pressurized B-G Mix Storage Tanks (TK-12, TK-13) • One (1) 38,000 gal Pressurized Condensate Storage Tank(TK-01-0301) • Eight(8) 30,000 gal Pressurized Propane Storage Tanks (TK-1 through TK-8) • One (1) 29,835 gal Pressurized Isopentane Storage Tank(TK-21) • Two(2) 30,000 gal Pressurized Butane Storage Tanks (TK-22, TK-25) • Two(2) 29,835 gal Pressurized Butane Storage Tanks (TK-23, TK-24) Colorado Regulation No. 3, Part C, Section II.E.3.aaa: Storage tanks of capacity less than forty thousand gallons of lubricating oils or waste lubricating oils: • One (1) 500 gal Engine Oil Storage Tank(TK-32) • One (1) 165 bbl Engine Oil Storage Tank(TK-36) Colorado Regulation No. 3, Part C, Section II.E.3.ggg: Each individual piece of fuel burning equipment that uses gaseous fuel, and that has a design rate less than or equal to ten million British thermal units per hour, and that is used solely for heating buildings for personal comfort. • Five (5) < 1 MMBtu/hr Natural Gas Fired Heaters Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix A Inspection Information Page 144 iii g !z q 1 1 � ,�J; a t 2 i s W I' 1= 1 II I I N T rk A wa 3 ll 1 �'�tr Ur I, w 38 a I 1 I I 1 I i �1 F: ' i f/ Ii. ,ti a r i 1 , u: 3,szl a1 1 - ! I 1 / s, a, i i 9 , 1 ib4PlIl 1�� A131 !' Cg9 I 1 1. [ d orb llsoi . E#• I I.h ig 4i4 #t R Ire i it Fj i A i P PO , 60.•••.' 9a r krIli ' ' r_ li -_ra-""a! fah: -Ito CSI ..1 c',, , , :4- ii Li F �'nue�a zaII' eaa _1 I i 11`i I` 1 `t �I. 6gdF ' k; II I �Vi a d` .� I I . i i.I_ , . ,;I I ° 1.11 1 t ;1!l' — it ti s r n II 5 , —11 Erg e Y e t. E �p iit. ) ;. 1..-3.,„--,1,,i1, 4ce;- � s,� i 1 ...;.,,,, , ..,J , „,.•:,,,,,.-,•\ s ,: , ,1 I hit; 18 11„4,1 11 _ 8� 4" Iiii t 1 f ##�� ' dry 11"71, 1 1 '; 1i e p I `E— i i q irt i _ I!, t'� i , Iii H÷ Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 145 APPENDIX B- Reporting Requirements and Definitions with codes ver 8/20/2014 Please note that, pursuant to 113(c)(2) of the federal Clean Air Act, any person who knowingly: (A) makes any false material statement,representation, or certification in, or omits material information from, or knowingly alters, conceals, or fails to file or maintain any notice, application, record, report, plan, or other document required pursuant to the Act to be either filed or maintained (whether with respect to the requirements imposed by the Administrator or by a State); (B) fails to notify or report as required under the Act; or (C) falsifies,tampers with, renders inaccurate, or fails to install any monitoring device or method required to be maintained or followed under the Act shall, upon conviction, be punished by a fine pursuant to title 18 of the United States Code, or by imprisonment for not more than 2 years, or both. If a conviction of any person under this paragraph is for a violation committed after a first conviction of such person under this paragraph, the maximum punishment shall be doubled with respect to both the fine and imprisonment. The permittee must comply with all conditions of this operating permit. Any permit noncompliance constitutes a violation of the Act and is grounds for enforcement action; for permit termination, revocation and reissuance, or modification; or for denial of a permit renewal application. The Part 70 Operating Permit program requires three types of reports to be filed for all permits. All required reports must be certified by a responsible official. Report#1: Monitoring Deviation Report(due at least every six months) For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by data from any monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 146 Report#2: Permit Deviation Report(must be reported "promptly") In addition to the monitoring requirements set forth in the permits as discussed above,each and every requirement of the permit is subject to deviation reporting. The reports must address deviations from permit requirements, including those attributable to malfunctions as defined in this Appendix, the probable cause of such deviations, and any corrective actions or preventive measures taken. All deviations from any term or condition of the permit are required to be summarized or referenced in the annual compliance certification. For purposes of this operating permit, "malfunction" shall refer to both emergency conditions and malfunctions. Additional discussion on these conditions is provided later in this Appendix. For purposes of this operating permit, the Division is requiring that the permit deviation reports are due as set forth in General Condition 21. Where the underlying applicable requirement contains a definition of prompt or otherwise specifies a time frame for reporting deviations,that definition or time frame shall govern. For example, quarterly Excess Emission Reports required by an NSPS or Regulation No. 1, Section IV. In addition to the monitoring deviations discussed above, included in the meaning of deviation for the purposes of this operating permit are any of the following: (1) A situation where emissions exceed an emission limitation or standard contained in the permit; (2) A situation where process or control device parameter values demonstrate that an emission limitation or standard contained in the permit has not been met; (3) A situation in which observations or data collected demonstrates noncompliance with an emission limitation or standard or any work practice or operating condition required by the permit; or, (4) A situation in which an excursion or exceedance as defined in 40CFR Part 64(the Compliance Assurance Monitoring (CAM) Rule) has occurred. (only if the emission point is subject to CAM) For reporting purposes, the Division has combined the Monitoring Deviation Report with the Permit Deviation Report. All deviations shall be reported using the following codes: 1 = Standard: When the requirement is an emission limit or standard 2 =Process: When the requirement is a production/process limit 3 =Monitor: When the requirement is monitoring 4=Test: When the requirement is testing 5=Maintenance: When required maintenance is not performed 6=Record: When the requirement is recordkeeping Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 147 7=Report: When the requirement is reporting 8=CAM: A situation in which an excursion or exceedance as defined in 40CFR Part 64 (the Compliance Assurance Monitoring (CAM) Rule) has occurred. 9=Other: When the deviation is not covered by any of the above categories Report#3: Compliance Certification (annually, as defined in the permit) Submission of compliance certifications with terms and conditions in the permit, including emission limitations, standards, or work practices, is required not less than annually. Compliance Certifications are intended to state the compliance status of each requirement of the permit over the certification period. They must be based, at a minimum, on the testing and monitoring methods specified in the permit that were conducted during the relevant time period. In addition, if the owner or operator knows of other material information (i.e. information beyond required monitoring that has been specifically assessed in relation to how the information potentially affects compliance status), that information must be identified and addressed in the compliance certification. The compliance certification must include the following: • The identification of each term or condition of the permit that is the basis of the certification; • Whether or not the method(s)used by the owner or operator for determining the compliance status with each permit term and condition during the certification period was the method(s) specified in the permit. Such methods and other means shall include, at a minimum, the methods and means required in the permit. If necessary, the owner or operator also shall identify any other material information that must be included in the certification to comply with section 113(c)(2) of the Federal Clean Air Act,which prohibits knowingly making a false certification or omitting material information; • The status of compliance with the terms and conditions of the permit,and whether compliance was continuous or intermittent. The certification shall identify each deviation and take it into account in the compliance certification. Note that not all deviations are considered violations.' • Such other facts as the Division may require, consistent with the applicable requirements to which the source is subject,to determine the compliance status of the source. For example, given the various emissions limitations and monitoring requirements to which a source may be subject,a deviation from one requirement may not be a deviation under another requirement which recognizes an exception and/or special circumstances relating to that same event. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 148 The Certification shall also identify as possible exceptions to compliance any periods during which compliance is required and in which an excursion or exceedance as defined under 40 CFR Part 64(the Compliance Assurance Monitoring (CAM) Rule) has occurred. (only for emission points subject to CAM) Note the requirement that the certification shall identify each deviation and take it into account in the compliance certification. Previously submitted deviation reports, including the deviation report submitted at the time of the annual certification, may be referenced in the compliance certification. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 149 Startup, Shutdown, Malfunctions and Emergencies, Understanding the application of Startup, Shutdown, Malfunctions and Emergency Provisions, is very important in both the deviation reports and the annual compliance certifications. Startup, Shutdown, and Malfunctions Please note that exceedances of some New Source Performance Standards (NSPS) and Maximum Achievable Control Technology (MACT) standards that occur during Startup, Shutdown or Malfunctions may not be considered to be non-compliance since emission limits or standards often do not apply unless specifically stated in the NSPS. Such exceedances must, however, be reported as excess emissions per the NSPS/MACT rules and would still be noted in the deviation report. In regard to compliance certifications, the permittee should be confident of the information related to those deviations when making compliance determinations since they are subject to Divisioh review. The concepts of Startup, Shutdown and Malfunctions also exist for Best Available Control Technology (BACT) sources, but are not applied in the same fashion as for NSPS and MACT sources. Emergency Provisions Under the Emergency provisions of Part 70 certain operational conditions may act as an affirmative defense against enforcement action if they are properly reported. DEFINITIONS Malfunction (NSPS) means any sudden, infrequent, and not reasonably preventable failure of air pollution control equipment, process equipment, or a process to operate in a normal or usual manner. Failures that are caused in part by poor maintenance or careless operation are not malfunctions. Malfunction (SIP) means any sudden and unavoidable failure of air pollution control equipment or process equipment or unintended failure of a process to operate in a normal or usual manner. Failures that are primarily caused by poor maintenance, careless operation, or any other preventable upset condition or preventable equipment breakdown shall not be considered malfunctions. Emergency means any situation arising from sudden and reasonably unforeseeable events beyond the control of the source, including acts of God, which situation requires immediate corrective action to restore normal operation, and that causes the source to exceed a technology-based emission limitation under the permit, due to unavoidable increases in emissions attributable to the emergency. An emergency shall not include noncompliance to the extent caused by improperly designed equipment, lack of preventative maintenance, careless or improper operation, or operator error. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 150 APPENDIX B: Monitoring and Permit Deviation Report -Part I 1. Following is the required format for the Monitoring and Permit Deviation report to be submitted to the Division as set forth in General Condition 21. The Table below must be completed for all equipment or processes for which specific Operating Permit terms exist. 2. Part II of this Appendix B shows the format and information the Division will require for describing periods of monitoring and permit deviations, or malfunction or emergency conditions as indicated in the Table below. One Part II Form must be completed for each Deviation. Previously submitted reports(e.g. EER's or malfunctions) may be referenced and the form need not be filled out in its entirety. FACILITY NAME: DCP Operating Company, LP—Greeley Natural Gas Processing Plant OPERATING PERMIT NO: 95OPWE038 REPORTING PERIOD: (see first page of the permit for specific reporting period and dates) Deviations noted Deviation Code 2 Condition Repo Malfunction/Emergency Operating Permit Unit ID Unit Description During Period?' Reported During Period? YES NO YES NO Waukesha Model F-11G Natural Gas Fired C-124 Internal Combustion Engine,Site Rated at 125 hp Waukesha Model L-7042 GSI C-116 Turbocharged Natural Gas Fired Internal Combustion Engine,Site Rated at 1,100 hp Waukesha Model L-7042 GSI C-117 Turbocharged Natural Gas Fired Internal Combustion Engine,Site Rated at 1,100 hp Waukesha Model L-7042 GSI C-118 Turbocharged Natural Gas Fired Internal Combustion Engine,Site Rated at 1,100 hp Waukesha Model L-7042 GSI C-119 Turbocharged Natural Gas Fired Internal Combustion Engine,Site Rated at 1,100 hp Waukesha Model L-7042 GSI C-120 Turbocharged Natural Gas Fired Internal Combustion Engine,Site Rated at 1,100 hp Waukesha Model L-7042 GU Natural Gas C-123 Fired Internal Combustion Engine,Site Rated at 896 hp Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 151 Deviations noted Malfunction/Emergency Deviation Code z Condition Reported Operating Permit Unit ID Unit Description During Period?i During Period? YES NO YES NO Waukesha Model L-7042 GSI C-152 Turbocharged Natural Gas Fired Internal Combustion Engine,Site Rated at 1,100 hp, Waukesha Model L-7042 GSI C-122 Turbocharged Natural Gas Fired Internal Combustion Engine,Site Rated at 1,100 hp P-130 Custom Ethylene Glycol Dehydration Unit, Rated at 33 MMSCFD P-132 Born,Inc.Hot Oil Heater,Natural Gas Fired,Rated at 15 MMBtu/hr Fugitive Emissions from Fractionation and P-133 Natural Gas Liquids(NGL)Processing Plants Pressurized Product Truck Loadout Rack for P-135 Propane,Butane,B-G Mix,Y-Grade, Isopentane,NGL and Condensate P-139 G.C.Broach Company Hot Oil Heater, Natural Gas Fired,Rated at 35.1 MMBtu/hr FLARE John Zink Hamworthy Combustion EEF Series Plant Flare General Conditions Insignificant Activities See previous discussion regarding what is considered to be a deviation. Determination of whether or not a deviation has occurred shall be based on a reasonable inquiry using readily available information. 2 Use the following entries,as appropriate 1 =Standard: When the requirement is an emission limit or standard 2=Process: When the requirement is a production/process limit 3 =Monitor: When the requirement is monitoring 4=Test: When the requirement is testing 5=Maintenance: When required maintenance is not performed 6=Record: When the requirement is recordkeeping 7=Report: When the requirement is reporting 8=CAM: A situation in which an excursion or exceedance as defined in 40CFR Part 64 (the Compliance Assurance Monitoring (CAM)Rule) has occurred. 9=Other: When the deviation is not covered by,any of the above categories Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 152 APPENDIX B: Monitoring and Permit Deviation Report -Part II FACILITY NAME: DCP Operating Company, LP—Greeley Natural Gas Processing Plant OPERATING PERMIT NO: 95OPWE038 REPORTING PERIOD: Is the deviation being claimed as an: Emergency Malfunction N/A (For NSPS/MACT) Did the deviation occur during: Startup Shutdown Malfunction Normal Operation OPERATING PERMIT UNIT IDENTIFICATION: Operating Permit Condition Number Citation Explanation of Period of Deviation Duration (start/stop date&time) Action Taken to Correct the Problem Measures Taken to Prevent a Reoccurrence of the Problem Dates of Malfunctions/Emergencies Reported (if applicable) Deviation Code Division Code QA: SEE EXAMPLE ON THE NEXT PAGE Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 153 EXAMPLE FACILITY NAME: Acme Corp. OPERATING PERMIT NO: 96OPZZXXX REPORTING PERIOD: 1/1/04 - 6/30/06 Is the deviation being claimed as an: Emergency Malfunction XX N/A (For NSPS/MACT) Did the deviation occur during: Startup Shutdown Malfunction Normal Operation OPERATING PERMIT UNIT IDENTIFICATION: Asphalt Plant with a Scrubber for Particulate Control - Unit XXX - Operating Permit Condition Number Citation Section II, Condition 3.1 - Opacity Limitation Explanation of Period of Deviation Slurry Line Feed Plugged Duration START- 1730 4/10/06 END- 1800 4/10/06 Action Taken to Correct the Problem Line Blown Out Measures Taken to Prevent Reoccurrence of the Problem Replaced Line Filter Dates of Malfunction/Emergencies Reported (if applicable) 5/30/06 to A. Einstein,APCD Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 154 Deviation Code Division Code QA: Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 155 APPENDIX B: Monitoring and Permit Deviation Report -Part III REPORT CERTIFICATION SOURCE NAME: DCP Operating Company, LP—Greeley Natural Gas Processing Plant FACILITY IDENTIFICATION NUMBER: 123-0099 PERMIT NUMBER: 95OPWE038 REPORTING PERIOD: (see first page of the permit for specific reporting period and dates) All information for the Title V Semi-Annual Deviation Reports must be certified by a responsible official as defined in Colorado Regulation No. 3, Part A, Section I.B. This signed certification document must be packaged with the documents being submitted. STATEMENT OF COMPLETENESS I have reviewed the information being submitted in its entirety and,based on information and belief formed after reasonable inquiry,I certify that the statements and information contained in this submittal are true, accurate and complete. Please note that the Colorado Statutes state that any person who knowingly, as defined in Sub-Section 18- 1-501(6), C.R.S., makes any false material statement, representation, or certification in this document is guilty of a misdemeanor and may be punished in accordance with the provisions of Sub-Section 25-7 122.1, C.R.S. Printed or Typed Name Title Signature of Responsible Official Date Signed Note:Deviation reports shall be submitted to the Division at the address given in Appendix D of this permit. No copies need be sent to the U.S. EPA. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix C Compliance Certification Report Page 156 APPENDIX C Required Format for Annual Compliance Certification Report(ver 8/20/2014) Following is the format for the Compliance Certification report to be submitted to the Division and the U.S. EPA annually based on the effective date of the permit. The Table below must be completed for all equipment or processes for which specific Operating Permit terms exist. FACILITY NAME: DCP Operating Company, LP—Greeley Natural Gas Processing Plant OPERATING PERMIT NO: 95OPWE038 REPORTING PERIOD: I. Facility Status During the entire reporting period, this source was in compliance with ALL terms and conditions contained in the Permit, each term and condition of which is identified and included by this reference. The method(s) used to determine compliance is/are the method(s) specified in the Permit. With the possible exception of the deviations identified in the table below, this source was in compliance with all terms and conditions contained in the Permit,each term and condition of which is identified and included by this reference, during the entire reporting period. The method used to determine compliance for each term and condition is the method specified in the Permit,unless otherwise indicated and described in the deviation report(s). Note that not all deviations are considered violations. Deviations Monitoring Operating Method per Was compliance continuous or Permit Unit Unit Description Reported I Permit?2 intermittent. ID i Previous I Current YES I NO Continuous I Intermittent Waukesha Model F-11G Natural Gas Fired C-124 Internal Combustion Engine,Site Rated at 125 hp Waukesha Model L-7042 GSI C-116 Turbocharged Natural Gas Fired Internal Combustion Engine,Site Rated at 1,100 hp Waukesha Model L-7042 GSI C-117 Turbocharged Natural Gas Fired Internal Combustion Engine,Site Rated at 1,100 hp Waukesha Model L-7042 GSI C-118 Turbocharged Natural Gas Fired Internal Combustion Engine,Site Rated at 1,100 hp Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix C Compliance Certification Report Page 157 Deviations Monitoring Operating Was compliance continuous or Permit Unit Unit Description Reported I Method per Permit. intermittent?3 ID Previous I Current YES I NO Continuous I Intermittent Waukesha Model L-7042 GSI C-119 Turbocharged Natural Gas Fired Internal Combustion Engine,Site Rated at 1,100 hp Waukesha Model L-7042 GSI C-120 Turbocharged Natural Gas Fired Internal Combustion Engine,Site Rated at 1,100 hp Waukesha Model L-7042 GU Natural Gas C-123 Fired Internal Combustion Engine,Site Rated at 896 hp Waukesha Model L-7042 GSI C-152 Turbocharged Natural Gas Fired Internal Combustion Engine,Site Rated at 1,100 hp, Waukesha Model L-7042 GSI C-122 Turbocharged Natural Gas Fired Internal Combustion Engine,Site Rated at 1,100 hp P-130 Custom Ethylene Glycol Dehydration Unit,Rated at 33 MMSCFD P-132 Born,Inc.Hot Oil Heater,Natural Gas Fired,Rated at 15 MMBtu/hr Fugitive Emissions from Fractionation and P-133 Natural Gas Liquids(NGL)Processing Plants Pressurized Product Truck Loadout Rack P-135 for Propane,Butane,B-G Mix,Y-Grade, Isopentane,NGL and Condensate G.C.Broach Company Hot Oil Heater, P-139 Natural Gas Fired,Rated at 35.1 MMBtu/hr FLARE John Zink Hamworthy Combustion EEF Series Plant Flare General Conditions Insignificant Activities 4 If deviations were noted in a previous deviation report,put an"X"under"previous". If deviations were noted in the current deviation report(i.e.for the last six months of the annual reporting period),put an"X"under"current". Mark both columns if both apply. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix C Compliance Certification Report Page 158 2 Note whether the method(s)used to determine the compliance status with each term and condition was the method(s)specified in the permit. If it was not,mark "no"and attach additional information/explanation. 3 Note whether the compliance status with of each term and condition provided was continuous or intermittent. "Intermittent Compliance"can mean either that noncompliance has occurred or that the owner or operator has data sufficient to certify compliance only on an intermittent basis. Certification of intermittent compliance therefore does not necessarily mean that any noncompliance has occurred. NOTE: The Periodic Monitoring requirements of the Operating Permit program rule are intended to provide assurance that even in the absence of a continuous system of monitoring the Title V source can demonstrate whether it has operated in continuous compliance for the duration of the reporting period. Therefore,if a source 1)conducts all of the monitoring and recordkeeping required in its permit,even if such activities are done periodically and not continuously, and if 2) such monitoring and recordkeeping does not indicate non- compliance,and if 3)the Responsible Official is not aware of any credible evidence that indicates non-compliance,then the Responsible Official can certify that the emission point(s)in question were in continuous compliance during the applicable time period. 4 Compliance status for these sources shall be based on a reasonable inquiry using readily available information. II. Status for Accidental Release Prevention Program: A. This facility is subject is not subject to the provisions of the Accidental Release Prevention Program (Section 112(r) of the Federal Clean Air Act) B. If subject: The facility is is not in compliance with all the requirements of section 112(r). 1. A Risk Management Plan will be has been submitted to the appropriate authority and/or the designated central location by the required date. III. Certification All information for the Annual Compliance Certification must be certified by a responsible official as defined in Colorado Regulation No. 3, Part A, Section I.B. This signed certification document must be packaged with the documents being submitted. I have reviewed this certification in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this certification are true, accurate and complete. Please note that the Colorado Statutes state that any person who knowingly, as defined in § 18-1-501(6), C.R.S., makes any false material statement, representation, or certification in this document is guilty of a misdemeanor and may be punished in accordance with the provisions of§ 25-7 122.1, C.R.S. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix C Compliance Certification Report Page 159 Printed or Typed Name Title Signature Date Signed NOTE: All compliance certifications shall be submitted to the Air Pollution Control Division and to the Environmental Protection Agency at the addresses listed in Appendix D of this Permit. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix D Notification Addresses Page 160 APPENDIX D Notification Addresses (ver. 1/27/2020) 1. Air Pollution Control Division Colorado Department of Public Health and Environment Air Pollution Control Division Operating Permits Unit APCD-SS-B 1 4300 Cherry Creek Drive S. Denver, CO 80246-1530 ATTN: Title V Unit Supervisor 2. United States Environmental Protection Agency Compliance Notifications: Enforcement and Compliance Assurance Division Air and Toxics Enforcement Branch Mail Code 8ENF-AT U.S. Environmental Protection Agency, Region VIII 1595 Wynkoop Street Denver, CO 80202-1129 502(b)(10) Changes, Off Permit Changes: Air and Radiation Division Air Permitting and Monitoring Branch Mail Code 8ARD-PM U.S. Environmental Protection Agency, Region VIII 1595 Wynkoop Street Denver, CO 80202-1129 Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix E Permit Acronyms Page 161 APPENDIX E Permit Acronyms Listed Alphabetically: AIRS - Aerometric Information Retrieval System AP-42 - EPA Document Compiling Air Pollutant Emission Factors APEN - Air Pollution Emission Notice (State of Colorado) APCD - Air Pollution Control Division (State of Colorado) ASTM - American Society for Testing and Materials BACT - Best Available Control Technology BTU - British Thermal Unit CAA - Clean Air Act(CAAA=Clean Air Act Amendments) CCR - Colorado Code of Regulations CEM - Continuous Emissions Monitor CF - Cubic Feet(scf= Standard Cubic Feet) CFR - Code of Federal Regulations CO - Carbon Monoxide COM - Continuous Opacity Monitor CRS - Colorado Revised Statute EPA - Environmental Protection Agency FR - Federal Register G - Grams Gal - Gallon HAPs - Hazardous Air Pollutants HP - Horsepower HP-HR - Horsepower Hour(G/HP-HR= Grams per Horsepower Hour) LAER - Lowest Achievable Emission Rate LBS - Pounds M - Thousand MM - Million MMscf - Million Standard Cubic Feet MMscfd - Million Standard Cubic Feet per Day N/A or NA - Not Applicable NOX - Nitrogen Oxides NESHAP - National Emission Standards for Hazardous Air Pollutants NSPS - New Source Performance Standards PMio - Particulate Matter Under 10 Microns PSD - Potential for Significant Deterioration Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix E Permit Acronyms Page 162 PTE - Potential To Emit RACT - Reasonably Available Control Technology SCC - Source Classification Code SIC - Standard Industrial Code SO2 - Sulfur Dioxide TPY - Tons Per Year TSP - Total Suspended Particulate VOC - Volatile Organic Compounds Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED:DRAFT Air Pollution Control Division Colorado Operating Permit Appendix F Permit Modifications Page 163 APPENDIX F Permit Modifications DATE OF SECTION NUMBER, DESCRIPTION OF REVISION REVISION CONDITION NUMBER Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix G Compliance Assurance Monitoring Page 164 APPENDIX G- Compliance Assurance Monitoring Plan I. Background a. Emission Unit Description: C-116, C-117, C-118,C-119,C-120, C-152, C-122—Seven (7) Waukesha Model L-7042 GSI Internal Combustion Engines, 1,100 hp each C-123—One (1) Waukesha Model L-7042 GU Internal Combustion Engine, 896 hp b. Applicable Regulation, Emission Limit, Monitoring Requirements: Regulations: Operating Permit Section II, Condition 1.1 Emission Limitations: C-116/C-117/C-118/C-120/C-122: NOx 24.00 tons/year C-119/C-152: NOx 21.24 tons/year C-123: NOx 8.65 tons/year c. Control Technology: Non-Selective Catalytic Reduction Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix G Compliance Assurance Monitoring Page 165 II. Monitoring Approach Indicator No. 1 Indicator No. 2 I. Indicator Catalyst Inlet Temperature Catalyst Pressure Drop Measurement Approach The temperature of the exhaust gas into the pressure drop across the catalyst beds is catalyst will be measured using an inline measured using a manometer. thermocouple. II. Indicator Range Excursions,for the purposes of reporting,are Excursions,for the purposes of reporting,are defined as a catalyst pressure drop reading defined as an inlet catalyst temperature below greater than three inches of water column above 750°F or above 1250°F. or below the pressure drop established during Excursions above 1250°F shall trigger engine the initial performance test,or,if a pressure shutdown. Excursions below 750°F shall drop was not established during the initial trigger notification of excursion. Excursions performance test,the pressure drop established trigger the permittee to investigate the engine by the manufacturer's specified range. performance and make any repairs or Excursions shall trigger the permittee to adjustments necessary. Any shutdowns, investigate the catalyst performance and make adjustments or repairs shall be recorded in a log any repairs or adjustments necessary. Any to be made available to the Division upon adjustments or repairs shall be recorded in a log request. to be made available to the Division upon request. III. Performance Criteria a. Data Representativeness Temperature is measured at the inlet to the Pressure drop is measured at the inlet and outlet catalyst. The minimum accuracy is+/-5°F. of the catalyst while the engine is operating. b. Verification of Operational N/A N/A Status c. QA/QC Practices/Criteria Thermocouples shall be calibrated annually and Manometers shall be calibrated,maintained and maintained and replaced in accordance with replaced in accordance with manufacturer's manufacturer's recommendations. recommendations. d. Monitoring Frequency Continuously. Monthly. f. Data Collection Procedures The catalyst inlet temperature shall be recorded The catalyst pressure drop shall be recorded daily in a log to be made available to the monthly in a log to be made available to the Division upon request. Division upon request. e. Averaging Time None. None. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix G Compliance Assurance Monitoring Page 166 III. Justification a. Background: The pollutant specific emission units are eight (8) internal combustion engines. Each engine is equipped with a non-selective catalytic reduction (NSCR) unit to control NOx emissions. The catalysis achieved by the NSCR reduces NOx emissions by promoting a reaction with CO to produce carbon dioxide, nitrogen and water. b. Rationale for Selection of Performance Indicators: The Division approved inlet temperature to the catalyst as it is an indicator of the catalyst performance. The temperature into the NSCR catalyst is measured because the catalytic reactions that convert NOx and CO to carbon dioxide, nitrogen and water are temperature-dependent. The reactions occur favorably if the engine exhaust temperature into the catalyst is greater than 750°F. Catalyst damage will occur if the inlet temperature is too high and deterioration of the catalyst would reduce emission conversion efficiency.Therefore,the upper operating limit for catalyst inlet temperature is 1250°F. Either excessive or inadequate temperature indicates possible problems with the engine operation that might be correctable after investigation. Monitoring of the temperature-sensing device of the inlet exhaust gas into the catalyst will ensure the presence of optimum conditions for the catalytic reaction. Additionally, pressure drop deviations across the catalyst are an indication of catalyst fouling or unfavorable catalyst settling. If significant fouling occurs, or if the catalyst has settled in a manner not conducive to the uniform distribution of flue gas, the number of available active sites on the catalyst may not be sufficient to ensure the conversion of NOx and CO to carbon dioxide, nitrogen and water at the design efficiency rating of the catalyst. If the pressure drop established during the initial performance test varies by a significant amount,catalyst reconditioning and/or maintenance must be performed to the manufacturer's specifications in order to bring the catalyst pressure drop back within the acceptable range. Therefore, monitoring the pressure drop will ensure fouling and/or settling has not occurred to the extent at which the catalyst becomes unable to convert the proper amount of NOx into nitrogen and water. The final RICE MACT (40 CFR Part 63 Subpart ZZZZ) requires monitoring of inlet temperature to the catalyst and the pressure drop across the catalyst. The CAM rule specifies that monitoring required for a MACT standard is presumptively acceptable monitoring, provided the monitoring is applicable to the performance of the control device (40 CFR Part 64 §64.4(b)(4)). Since the MACT monitoring is for NSCR units, the Division considers that these indicators are presumptively acceptable. c. Rationale for Selection of Indicator Ranges: Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix G Compliance Assurance Monitoring Page 167 The indicator range for the catalyst inlet temperature and pressure drop were selected based on the final RICE MACT (40 CFR Part 63 Subpart ZZZZ). The indicator range for the catalyst inlet temperature is the same range as specified in the final RICE MACT for engines required to install NSCR units. The indicator range for the pressure drop is based on the +/- 10% pressure drop required by the final RICE MACT for engines required to install NSCR units. The Division considers that these indicator ranges are presumptively acceptable pursuant to 40 CFR Part 64 §64.4(b)(4). Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H Engine AOS Applicability Reports Page 168 APPENDIX H—Applicability Reports ver 10/12/2012 (with updated web links and Reg 3 citations as of 8/20/2014) Note: A MS Word version of this Appendix can be found at: https://www.colorado.gov/pacific/cdphe/air/AOS DISCLAIMER: These are only example reports and do not cover all possible requirements. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H Engine AOS Applicability Reports Page 169 Engine AOS Applicability Report Certification Language All information for the Applicability Reports must be certified by either 1) for Operating Permits, a Responsible Official as defined in Colorado Regulation No. 3, Part A, Section I.B.40) for Construction and General Permits, the person legally authorized to act on behalf of the source. This signed certification document must be packaged with the documents being submitted. I have reviewed this certification in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this certification are true, accurate and complete. Further, I agree that by signing and submitting these documents I agree that any new requirements identified in the Applicability Report(s) shall be considered to be Applicable Requirements as defined in Colorado Regulation No. 3, Part A, Section I.B.9., and that such requirements shall be enforceable by the Division and its agents and shall be considered to be revisions to the underlying permit(s) referenced in the Report(s) until such time as the Permit is revised to reflect the new requirements. Please note that the Colorado Statutes state that any person who knowingly, as defined in § 18-1-501(6), C.R.S., makes any false material statement, representation, or certification in this document is guilty of a misdemeanor and may be punished in accordance with the provisions of§ 25-7 122.1, C.R.S. Printed or Typed Name Title Signature Date Signed Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H Engine AOS Applicability Reports Page 170 Colorado Regulation No. 7 Sections XVI and XVII.E DISCLAIMER: This is only an example report and does not cover all possible Reg 7 requirements. Company: Acme Gas Processing Source ID: 9991234 Permit#: 93OPXX999 Date: October 1, 2008 Determination of compliance and reporting requirements for a Manufacturer: BestEngineCompany Model: 777 LowNox. Nameplate HP: 1340 Construction date: July 1, 2007 Note: If the engine is exempt from a requirement due to construction date or was relocated from within Colorado, supporting documentation must be provided. Determination of Regulation No. 7 requirements: Regulation No. 7, §XVI ❑ Does not apply to this engine. Engine is not located in the ozone nonattainment area or does not have a manufacturer's design rate greater than 500 horsepower or did not commence operation on or after June 1, 2004. ❑ Does apply to this engine and applicable emissions controls have been installed. Regulation No. 7, § XVII.E ❑ Does not apply to this engine. Engine does not have a maximum horsepower greater than 100 or the construction or relocation date precedes the applicability dates. ❑ Does apply to this engine. The following emission limits apply to the engine: NOx (g/hp-hr): 2.0 CO (g/hp-hr): 4.0 VOC (g/hp-hr): 1.0 Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H Engine AOS Applicability Reports Page 171 Max Engine Construction or Emission Standards in g/hp-hr HP Relocation Date NOx CO VOC 100<Hp<500 January 1, 2008 2.0 4.0 1.0 January 1, 2011 1.0 2.0 0.7 500≤Hp July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H Engine AOS Applicability Reports Page 172 NSPS JJJJ Example Report Format DISCLAIMER: This is only an example report and does not cover all possible JJJJ requirements. Note that as of August 20, 2015 that the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS JJJJ 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, § I.C, upon adoption of NSPS JJJJ into Regulation No. 6, Part A, an internal combustion engine relocated from outside the State of Colorado into the Date of Colorado shall meet the most recent emission standard required in NSPS JJJJ. Engines with a manufacturer's rated horsepower of less than 500 and with a relocation date no later than 5 years after the manufacture date are exempt from this requirement per Regulation No. 6, Part B, Section I.C.2.a. Relocation is defined in Section I.C.1.a. NSPS Subpart JJJJ: Standards of Performance for Stationary Spark Ignition Internal Combustion Engines Company: Acme Gas Processing Source ID: 9991234 Permit#: 93OPXX999 Date: October 1, 2008 Manufacturer: BestEngineCompany Model: 777 LowNox Nameplate HP: 1340 Engine Type: 2 Stroke Lean Burn Manufacture Date: July 1, 2007 Date Engine Ordered:April 1, 2007 Note: If the engine is exempt from a requirement due to construction/manufacture date, supporting documentation must be provided. Upon adoption of NSPS Subpart JJJJ into Colorado Regulation No. 6, Part A, if the engine is exempt because the engine was relocated within the state of Colorado, supporting documentation must be provided. n NSPS JJJJ does not apply to this engine. n NSPS JJJJ does apply to this engine. Note: Using the format below,the source must submit to the Division an analysis of all of the NSPS JJJJ applicable requirements that apply to this specific engine. The analysis below is an example only, based on a hypothetical engine that is a rich burn engine, greater than 500 HP, with a manufacture date after July 1, 2007. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H Engine AOS Applicability Reports Page 173 Determination of NSPS JJJJ requirements: 60.4230 Applicability (a)(4)(i) Applies to this engine since it is a rich burn engine, greater than 500 HP,with a manufacture date after July 1, 2007. 60.4233 Emission Standards for Owners and Operators (e) Owners and operators of stationary SI ICE with a maximum engine power greater than 100 HP must comply with the standards in Table 1. Non-Emergency SI,Natural Gas, HP>500, Manufactured after 7/1/2007 NO, 2.0 g/HP-hr or 160 ppmvd@15% O2 CO 4.0 g/HP-hr or 540 ppmvd@15% O2 VOC 1.0 g/HP-hr or 86 ppmvd@15% O2 Other Requirements for Owners and Operators 60.4234 Emission standards must be met for the lifetime of the engine. 60.4235 N/A- Sulfur content of gasoline. 60.4236 N/A (for now) - After July 1, 2009 owners and operators may not install engines with a power rating> 500HP that do not meet the emissions standards in 60.4233. 60.4237 N/A - Emergency Engines. 60.4238 - 60.4242 Compliance Requirements for Manufacturers—(Not Applicable) 60.4243 Compliance Requirements for Owners and Operators (b)(2)(ii) To maintain compliance with the emission limits in 60.4233, owners of SI ICE> 500HP must: • Keep a maintenance plan; • Keep records of conducted maintenance; • Maintain and operate the engine in a manner consistent with good air pollution control practice for minimizing emissions; • Conduct an initial performance test; and • Conduct subsequent performance tests every 8,760 hours or every three years, which ever comes first, in order to demonstrate compliance with the emission limits. (g) Air to fuel ratio controllers (AFRCs) must be maintained and operated appropriately in order to ensure proper operation of the engine and control device to minimize emissions at all times. 60.4244 Testing Requirements for Owners and Operators Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H Engine AOS Applicability Reports Page 174 (a) Each performance test must be conducted within 10% of the highest achievable load and must comply with the testing requirements listed in 60.8 and Table 2 of NSPS JJJJ. (b) Performance tests may not be conducted during periods of startup, shutdown, or malfunction, as specified in 60.8(c). If the engine is non-operational when a performance test is due,the engine does not need to be started up just to test it, but will need to be tested immediately upon startup. (c) Three separate test runs must be conducted for each performance test as specified by 60.8(f). Each run must be within 10%of max load and be at least 1 hour in duration. (d) To determine compliance with the NOR, CO, and VOC mass per unit output emission limitations, the measured concentration must be converted using the equations outlined in this section of NSPS JJJJ. 60.4245 Notification,Reports, and Records for Owners and Operators (a) Owners of all stationary SI ICE must keep records of the following: (1) All notifications submitted to comply with this subpart; (2) Maintenance conducted on the engine; (3) N/A - Manufacturer information for certified engines, and (4) Documentation that shows non-certified engines are in compliance with the emission standards. (b) N/A—For emergency engines only. (c) Owners of non-certified engines> 500HP must submit an initial notification as required in 60.7(a)(1) which includes the following information: (1) Name and address of the owner or operator; (2) The address of the affected source; (3) Engine information including make, model, engine family, serial number, model year, maximum engine power, and engine displacement; (4) Emission control equipment; and (5) Fuel used. CONCLUSION OF FINDINGS (EXAMPLE ONLY) In general, Acme's 1,235HP, Waukesha 7042 GSI engine is subject to the emissions limitations summarized in Table 1 of NSPS JJJJ. ACME will meet these emission limitations using an AFRC and a non-selective catalytic converter(NSCR). These emission rates will be met throughout the life of the engine. A maintenance plan will be kept and all maintenance activities will be recorded. Compliance with the emission limits will be confirmed by the initial performance tests, which shall be conducted following the procedures outlined in 60.4244. Copies of performance test results will be submitted within 60 days of the completion of each test. Since this is an uncertified engine, an initial notification will be submitted including all of the requested information in 40.4245 within 30 days of startup. ACME will keep records of all compliance related materials. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H Applicability Reports Page 175 MACT ZZZZ Example Report Format DISCLAIMER: This is only an example report and does not cover all possible ZZZZ requirements. MACT Subpart ZZZZ: National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Company: Acme Gas Processing Source ID: 9991234 Permit#: 93OPXX999 Date: October 1, 2008 Manufacturer: BestEngineCompany Model: 777 LowNox Nameplate HP: 1340 Engine Type: 2 Stroke Lean Burn Manufacture Date: July 1, 2007 Date Engine Ordered: April 1, 2007 Note: If the engine is exempt from a requirement due to construction/reconstruction date, supporting documentation must be provided. n MACT ZZZZ does not apply to this engine. H MACT ZZZZ does apply to this engine. Note: Using the format below, the source must submit to the Division an analysis of all of the MACT ZZZZ applicable requirements that apply to this specific engine. The analysis below is an example only, based on a hypothetical new engine located at an area source of HAP emissions. Determination of MACT ZZZZ requirements: 63.6585 Applicability This subpart is applicable to Acme's engine since they are going to be operating a new stationary reciprocating internal combustion engine (RICE) at a major source of HAP emissions. 63.6590 What Parts of My Plant Does This Subpart Cover? This subpart covers Acme's new stationary reciprocating internal combustion engine. 63.6595 When do I have to comply with this Subpart? Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H Applicability Reports Page 176 (a)(5) The engine must comply with the applicable emission limitations and operating limitations upon startup. 63.6600 Emission and operating limitations for RICE site rated at more than 500 hp (a) The engine is subject to the emission limits in table la and the operating limits in table 1 b. ACME will meet the emission limitations by reducing formaldehyde emissions by 76 percent and will maintain the catalyst such that the pressure drop does not change by more than 2 inches of H2O at 100 % load plus or minus 10 percent from the pressure drop measured during the initial performance test and will maintain the temperature of the engine exhaust so that the catalyst inlet temperature is greater than or equal to 750 °F and less than or equal to 1250 °F. The engine will be equipped with non-selective catalytic reduction and an air fuel controller to meet the emission limitations. 63.6601 & 63.6611 Requirements for 4SLB engines between 250 and 500 hp These requirements do not apply. 63.6605 General Requirements (a) The engine will comply with the emission and operating limitations at all times, except during periods of startup, shutdown and malfunction(SSM) (b) The engine, including air pollution control and monitoring equipment shall be operating in a manner consistent with good air pollution control practices for minimizing emissions at all times, including during SSM. 63.6610 Initial performance test (a) The performance tests specified in Table 4 (select sampling port and measure O2, moisture and formaldehyde at inlet and outlet of the control device) shall be conducted within 180 days of startup. (b) & (c) Not applicable. Construction did not commence between 12/19/02 and 6/15/04. (d) Previous performance tests have not been conducted on this unit within two years, therefore, this provision does not apply. 63.6615 Subsequent performance tests Subsequent tests will be conducted as specified in Table 3. No additional testing is required for 4SRB engines meeting the formaldehyde percent reduction requirements. 63.6620 Performance test procedures Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H Applicability Reports Page 177 (b) Tests must be conducted at 100 % load plus or minus 10%. (c) Tests may not be conducted during periods of SSM. (d) Must conduct three 1-hr test runs (e) Equation (e)(1) shall be used to determine compliance with the percent reduction requirement. (f), (g) & (h) Not applicable (i) Engine load during test shall be determined as specified in this paragraph. 63.6625 Monitoring, installation, operation and maintenance requirements (a), (c) & (d) Not applicable (b) A continuous parameter monitoring system (CPMS) shall be installed to measure the catalyst inlet temperature. The CPMS will meet the requirements in § 63.8 63.6630 Demonstrating initial compliance (a) Initial compliance shall be determined in accordance with Table 5 (initial performance test must indicate formaldehyde reduction of 76 percent or more, a CPMS must be installed to measure inlet temperature of the catalyst and the pressure drop and catalyst inlet temperature must be recorded during the initial performance test). (b) Pressure differential will be established during the initial performance test. (c) Notification of compliance status will be submitted and will contain the results of the initial compliance demonstration. 63.6635 Monitoring to demonstrate continuous compliance (b) Except for monitor malfunctions, associated repairs, and required QA/QC activities monitoring must be continuous at all time the engine is operating. (c) Data recorded during monitoring malfunctions, associated repairs and required QA/QC activities must not be used in data averages and calculations to report operating levels, however, all the valid data collected during other periods shall be used. 63.6640 Demonstrating continuous compliance (a) Continuous compliance will be demonstrated as specified in Table 6 (collect catalyst inlet temperature data, reduce that data to 4-hr rolling average and maintain the 4-hr rolling averages to within the operating limitation and measuring the pressure drop across the catalyst once per month and demonstrating that the pressure drop meets the operating limitation). (b) Deviations from the emission and operating limitations must be reported per § 63.6550. If catalyst is changed the operating parameters established during the initial performance test must be re-established. When operating parameters re-established a performance test must also be conducted. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H Applicability Reports Page 178 63.6645 Notifications (a) Submit notifications in §§ 63.7(b) & (c), 63.8(e), (0(4) and(0(6), 63.9(b)thru(e) & (g) & (h) that apply by dates specified. (b) Not applicable. Acme unit started after effective dated for Subpart ZZZZ. (c) Submit initial notification within 120 days after becoming subject to Subpart ZZZZ. (d)thru (f) Not applicable. Acme engine greater than 500 hp and subject to requirements in Subpart ZZZZ. (g) & (h) Submit notification of intent to conduct performance test and notification of compliance status. 63.6650 Reports (a) Submit reports required by Table 7 (compliance report and SSM reports (if actions inconsistent with SSM plan) (b) Not applicable, an alternate schedule for report submittal has been approved. Reports will be submitted with Title V reports (c) Compliance reports to contain the following information: company name and address, statement by responsible official certifying accuracy, date of report and beginning and end of reporting period, if SSM the information in 63.10(d)(5)(i), if no deviations a statement saying that, if no periods when CPMS out of control a statement saying that. (d) Not applicable, using CPMS (e) For each deviation the information in (e)(1)thru (e)(12) shall be provided. (0 Applicable. Compliance reports are submitted with title v reports. Compliance reports under Subpart ZZZZ include all necessary info for title v deviation report with respect to Subpart ZZZZ requirements. (g) Not applicable. Acme engine not firing landfill or digester gas. 63.6655 Recordkeeping (a) Retain records as follows: copy of each notification and report(including all documentation supporting any initial notification or notification of compliance status), records in 63.6(e)(iii)thru (v) related to SSM, and records of performance tests and evaluations. (b) CPMS records including records in 63.10(b)(2)(vi)thru (xi), previous versions of the performance evaluation plan required by 63.8(d)(3) and requests for alternatives to the relative accuracy test for CPMS as required by 63.8(f)(6)(i). (c) Not applicable. Acme engine not firing landfill or digester gas. (d) Will keep records required in Table 6 (monthly pressure drop readings, 4-hr averages of catalyst inlet temperature)to show continuous compliance with emission and operating limits. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H Applicability Reports Page 179 63.6660 Form and length of records (a) Records must be in a form suitable and readily available for expeditions review. (b) Records must be retained for five years. (c) Records must be retained on-site for first 2 years, may be retained off-site for the remaining 3 years. 63.6665 General Provisions This engine must comply with the general provisions as indicated in Table 8. CONCLUSION OF FINDINGS (EXAMPLE ONLY) Since this engine is subject to the requirements of MACT Subpart ZZZZ. The engine will be installed with a non-selective catalyst to meet the formaldehyde reduction requirement of 76%or more. An initial performance test will be conducted within 180 days of startup to demonstrate compliance with the formaldehyde percent reduction requirement. During the initial performance test,the pressure drop across the catalyst will be measured. A CPMS will be installed to measure the catalyst inlet temperature. Continuous compliance will be demonstrated by keeping the 4-hr rolling averages of catalyst inlet temperature within the operating limitations and recording the pressure drop across the catalyst monthly and demonstrating that the pressure drop is within the operating limitation. Records, notifications and reports will be submitted as required. To that end required reports and notifications include initial notification, notice of intent to conduct performance test, notification of compliance status, SSM reports (if required)and semi-annual compliance reports. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: DRAFT TECHNICAL REVIEW DOCUMENT For DRAFT RENEWAL OF OPERATING PERMIT 95OPWE038 DCP Operating Company, LP — Greeley Natural Gas Processing Plant Weld County Source ID 123-0099 April 2018 — Date Operating Permit Engineer: Elie Schuchardt Operating Permit Supervisor review: Blue Parish Field Services Unit review: Alex Scherer I. PURPOSE This document establishes the basis for decisions made regarding the applicable requirements, emission factors, monitoring plan and compliance status of emission units covered by the renewed Operating Permit for the Greeley Natural Gas Processing Plant. The previous Operating Permit for this facility was issued on 5/1/1999, was renewed on 5/1/2009 and was last revised on 9/6/2017 and expired on 5/1/2014. However, since a timely and complete renewal application was submitted, under Colorado Regulation No. 3, Part C, Section IV.C all of the terms and conditions of the existing permit shall not expire until the renewal operating permit is issued and any previously extended permit shield continues in full force and operation. The source submitted the following significant permit modification applications: • Significant Modification (Rec'd 5/2/2016) — Request to incorporate changes to the ethylene glycol dehydration unit P-130 (AIRS 111) and the permitting of the plant flare (AIRS 122), as previously requested and permitted in Colorado Construction Permit 15WE0939. • Significant Modification (Rec'd 4/27/2020) — Request to reduce NOx emission limitations for engines C-116 (AIRS 103), C-117 (AIRS 117), C-118 (AIRS 105), C-120 (AIRS 107) and C-122 (AIRS 110) below the significance threshold of 25 tons/year for a serious non-attainment area to allow these engines to use the permanent replacement alternative operating scenario (AOS), as defined in PS Memo 98-06, and to request that the emission calculation methodology for pressurized product truck loadout rack P-135 (AIRS 115) be updated to base emissions on truck traffic tracking, as opposed to product volumetric tracking. Since the first modification involves the incorporation of a new construction permit and the second requests synthetic minor limitations, these modifications must be processed as significant modifications as required by Colorado Regulation No. 3, Part C, Section I.A.7.c. A significant modification is processed under the same procedures as a renewal, i.e. it must go through a 30-day public comment period and EPA 45-day review period. 123/0099 Page 1 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Therefore, since the renewal application has been submitted the Division is incorporating these modifications with the renewal. The source submitted the following minor permit modification applications: • Minor Modification (Rec'd 12/21/2018) — Request to decrease the emission limitations and factors for engine C-123 (AIRS 108) as this engine became subject to new Colorado Regulation No. 7 emission standards as the result of an alternative operating scenario (AOS) execution. • Minor Modification (Rec'd 12/20/2019)— Request to update the fugitive emission limit for P-133 (AIRS 114) based on a more recent component count and extended gas analysis and to update permit language with the most recent Colorado Regulation No. 7 fugitive emissions requirements for natural gas processing plants located in the 8 hour ozone control area. It was determined that these applications met the minor modification requirements set forth in Colorado Regulation No. 3, Part C, Section X. Because this these modifications were received during the renewal process, they were incorporated into this operating permit renewal. This document is designed for reference during the review of the proposed permit by the EPA, the public, and other interested parties. The conclusions made in this report are based on information provided in the original application submitted on 5/1/2013, comments on the draft permit submitted on 5/22/2020, previous inspection reports and various email correspondence, as well as telephone conversations with the applicant. Please note that copies of the Technical Review Document for the original permit and any Technical Review Documents associated with subsequent modifications of the original Operating Permit may be found in the Division files as well as on the Division website at https://www.colorado.gov/cdphe/title-v-operating-permits. This narrative is intended only as an adjunct for the reviewer and has no legal standing. Any revisions made to the underlying construction permits associated with this facility made in conjunction with the processing of this operating permit application have been reviewed in accordance with the requirements of Regulation No. 3, Part B, Construction Permits, and have been found to meet all applicable substantive and procedural requirements. This operating permit incorporates and shall be considered to be a combined construction/operating permit for any such revision, and the permittee shall be allowed to operate under the revised conditions upon issuance of this operating permit without applying for a revision to this permit or for an additional or revised construction permit. II. DESCRIPTION OF SOURCE The Greeley Natural Gas Processing Plant, classified as a natural gas processing plant as set forth under Standard Industrial Classification 1321, is designed to extract natural gas liquids from field produced natural gas and recompress the processed gas prior to transmission to a sales pipeline. Field gas is first piped to a separator where liquids formed during transport to the plant are separated from the gas stream. The gas stream discharged from the separator is processed through an ethylene glycol dehydration unit 123/0099 Page 2 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit (AIRS 111), where moisture contained in the gas stream is absorbed by ethylene glycol. The moisture laden glycol discharged from the contactor is regenerated in a reboiler. The glycol solution is then re-circulated to the contactor. Emissions from the dehydration unit still vent are routed to an enclosed combustor. Emissions from the dehydration unit flash tank are routed to a vapor recovery unit (VRU, AIRS 102) and routed back to the plant inlet. During periods of VRU downtime, flash tank emissions are routed to the enclosed combustor. After the moisture in the gas has been removed by the contactor, the gas stream is piped to the processing plant where it is chilled by a refrigeration system coupled with the Joule-Thompson process to create a natural gas liquid (NGL) product and a residue gas stream. A fractionation assembly separates the NGL product into ethane, propane, butane, isopentane and natural gasoline streams that are stored in separate pressurized bullet tanks and transported offsite by truck. The residue gas is recompressed by eight (8) compressors, powered by natural gas fired internal combustion engines (AIRS 103, 104, 105, 106, 107, 108, 109, 110) and is then routed to a sales gas pipeline. The facility operation also requires two natural gas fired hot oil heaters (AIRS 113, 120), a pressurized truck loadout rack for condensate, a pressurized NGL truck loadout rack (AIRS 115) and various pressurized storage tanks for the NGL and condensate products. The plant flare (AIRS 122) serves as a control device for facility and equipment blowdowns, as well as maintenance, malfunction, startup and shutdown emissions. Fugitive equipment leaks (AIRS 114) are also permitted at this facility. Emission control devices include: nine (9) NSCR beds to control compressor engine exhaust emissions, one (1) vapor recovery unit (VRU) permitted 5% downtime, to control the flash tank emissions from the dehydration unit, one (1) enclosed combustion device (ECD) permitted 5% downtime, to control the still vent emissions from the dehydration unit, as well as flash tank emissions during periods of VRU downtime, and one (1) plant flare, to control facility-wide process emissions. The address of the Greeley Natural Gas Processing Plant is 3009 49th Street, Greeley (SEY4& SW1%of SWY4 of Section 25, T5N, R66W). The plant is located at the southern edge of Greeley near Highway 85. This facility is located in an Area classified as attainment/maintenance for carbon monoxide (CO). Under that classification, all SIP- approved requirements for CO will continue to apply in order to prevent backsliding under the provisions of Section 110(1) of the Federal Clean Air Act. This Area is classified as non-attainment for the 8-hr ozone standard and is part of the 8-hr Ozone Control Area as defined in Regulation No. 7, Part A, Section II.A.1. The 8-hr Ozone Control Area has been classified as a serious non-attainment area effective January 27, 2020. Wyoming is an affected state within 50 miles of the plant. Rocky Mountain National Park and Rawah Wilderness are Federal Class I designated areas within 100 kilometers of the plant. Emissions (in tons/yr) at the facility are as follows: Controlled Emissions(tons/year) AIRS ID Facility ID Source Fugitive Reportable NOx CO VOC VOC HAP 123/0099 Page 3 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit 102 C-124 Compressor Engine 3.02 4.22 -- -- -- 103 C-116 Compressor Engine 24.00 26.55 5.31 -- 0.26 104 C-117 Compressor Engine 24.00 26.55 5.31 -- 0.26 105 C-118 Compressor Engine 24.00 26.55 5.31 -- 0.26 106 C-119 Compressor Engine 21.24 26.55 5.31 -- 0.26 107 C-120 Compressor Engine 24.00 26.55 5.31 -- 0.26 108 C-123 Compressor Engine 8.65 17.30 4.33 -- 0.16 109 C-152 Compressor Engine 21.24 26.55 5.31 -- 0.26 110 C-122 Compressor Engine 24.00 26.55 5.31 -- 0.26 111 P-130 EG Dehydration Unit -- -- 0.20 -- 0.05 113 P-132 Hot Oil Heater 6.32 5.31 -- -- -- 114 P-133 Fugitive Equipment Leaks -- -- -- 10.34 0.49 115 P-135 Pressurized Truck Loadout -- -- 43.15 -- 7.93 120 P-139 Hot Oil Heater 14.64 12.30 -- -- 0.26 122 Flare Plant Flare 2.58 11.35 19.83 -- 0.41 Total Permitted Facility Emissions(tons/year) 197.69 236.33 104.68 10.34 11.16 2018 Actual Facility Emissions(tons/year) 191.89 215.14 91.99 -- 2.13 *Actual VOC emissions include fugitive VOC emissions III. APPLICABLE REQUIREMENTS Non-Attainment New Source Review (NANSR) and Prevention of Significant Deterioration (PSD) This facility is categorized as a NANSR major stationary source (Potential to Emit of VOC or NOx > 50 Tons/Year). Future modifications at this facility resulting in a significant net emissions increase (see Reg 3, Part D, Sections II.A.27 and 44) for VOC or NOx or a modification which is major by itself(i.e. a Potential to Emit of > 50 TPY of either VOC or NOx) may result in the application of the NANSR review requirements. Based on the information provided by the applicant, this source is categorized as a minor stationary source for PSD as of the issue date of this permit. Any future modification which is major by itself (Potential to Emit of > 250 TPY) for any pollutant listed in Regulation No. 3, Part D, Section II.A.44 for which the area is in attainment or attainment/maintenance may result in the application of the PSD review requirements. Accidental Release Program — 112(r) Section 112(r) of the Clean Air Act mandates a new federal focus on the prevention of chemical accidents. Sources subject to these provisions must develop and implement risk management programs that include hazard assessment, a prevention program, and an emergency response program. They must prepare and implement a Risk Management Plan (RMP) as specified in the Rule. The Greeley Natural Gas Processing Plant is subject to the provisions of Section 112(r) of the Federal Clean Air Act. 112(r) requires the submittal of a risk management plan 123/0099 Page 4 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit (RMP) by June 20, 1999 and the facility did submit an RMP by the June 20, 1999 deadline. Compliance Assurance Monitoring (CAM) The following emission points at this facility use a control device to achieve compliance with an emission limitation or standard to which they are subject and have pre-control emissions that exceed or are equivalent to the major source threshold. They are therefore subject to the provisions of the CAM program as set forth in 40 CFR Part 64 as adopted by reference into Colorado Regulation No. 3, Part C, Section XIV: AIRS ID 103 (C-116) — Compressor RICE (1,100 hp) for NOx AIRS ID 104 (C-117) — Compressor RICE (1,100 hp) for NOx AIRS ID 105 (C-118) — Compressor RICE (1,100 hp) for NOx AIRS ID 106 (C-119) — Compressor RICE (1,100 hp) for NOx AIRS ID 107 (C-120) — Compressor RICE (1,100 hp) for NOx AIRS ID 108 (C-123) — Compressor RICE (896 hp) for NOx AIRS ID 109 (C-152) — Compressor RICE (1,100 hp) for NOx AIRS ID 110 (C-122) — Compressor RICE (1,100 hp) for NOx It should be noted that Engine C-123 was not listed as a CAM-subject engine in the previous issuance of the operating permit on 5/1/2009. In this operating permit renewal, it was determined that the pre-control emissions of NOx for C-123 were in excess of the major source threshold for CAM applicability (50 tons/year). Because this engine has the potential to emit NOx in excess of the major source threshold, is subject to a NOx limitation and uses a control device to comply with the NOx emission limitation set forth in this permit, this engine is subject to the requirements of CAM, pursuant to 40 CFR 60 Part §64.2(a). The remaining permitted points at this facility are not subject to CAM per the following justifications: AIRS ID 102 (C-124)—Compressor RICE (125 hp) exempt due to pre-control emissions below major source thresholds AIRS ID 111 (P-130) — Ethylene Glycol Dehydration Unit (33 MMSCFD) exempt due to pre-control emissions below major source thresholds AIRS ID 113 (P-132) — Hot Oil Heater (15 MMBtu/hr) exempt due to pre-control emissions below major source thresholds AIRS ID 114 (Fugitives) — Fugitive Equipment Leaks exempt as an uncontrolled emissions unit. Note that LDAR inspections are not considered to be a "control device" for the purposes of CAM, pursuant to the definition set forth in §64.1. 123/0099 Page 5 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit AIRS ID 115 (P-135)— Pressurized Truck Loading exempt as an uncontrolled emissions point AIRS ID 120 (P-139) — Hot Oil Heater (35.1 MMBtu/hr) exempt due to pre-control emissions below major source thresholds AIRS ID 122 (FLARE) — The PSEUs routed to the flare cumulatively result in uncontrolled VOC emissions of 396.5 tons/year, which exceeds the major source threshold of 50 tons/year. However, §64.2(a) states that the requirements of CAM "shall apply to a pollutant-specific emissions unit at a major source that is required to obtain a part 70 or 71 permit if the unit satisfies... potential pre-control device emissions of the applicable regulated air pollutant that are equal to or greater than 100 percent of the amount, in tons per year, required for a source to be classified as a major source". The plant flare is used to dispose of process vapors generated by equipment blowdowns and emergency safety relief devices. Each of the blowdown contributions from permitted units is, when evaluated individually, less than the 50 tons/year major source threshold for VOC. Therefore, because each PSEU venting to the flare contributes emissions below the major source thresholds, the plant flare was determined to be exempt from the requirements of CAM. Hazardous Air Pollutants (HAPs) The Greeley Natural Gas Processing Plant is a synthetic minor source of HAP emissions. Note that this facility was previously true minor, however, with the significant modification received 4/27/2020, uncontrolled HAP emissions are now in excess of the major source thresholds of 10 tons/year individual HAP (n-hexane) and 25 tons/year total HAP. However, because controlled HAP emissions are below these major source thresholds, this facility is considered to be a synthetic minor source of HAP (see table below). In order to maintain its facility status as a synthetic minor HAP source, as well as to ensure major source requirements under various MACTs are not triggered, synthetic minor HAP limits of 8 tons/year individual HAP and 20 tons/year total HAP were included in this operating permit. These lower limits (i.e., less than the major source threshold of 10 tons/year individual HAP and 25 tons/year total HAP) are Division-standard limitations that are assumed to leave sufficient buffer to accommodate HAP emissions from insignificant activities. As such, a source subject to these limitations does not have to track insignificant activity HAP emissions since it is presumed that if the permitted points are in compliance with the 8/20 limitations, the insignificant activity HAP emissions should not trigger major source requirements. Once a source's controlled potential to emit exceeds these 8/20 limitations, insignificant activity tracking is required. The Greeley Natural Gas Processing Plant has a controlled potential to emit below the 8/20 limitations. As such, this facility does not have to track insignificant activities for the purposes of HAP limitation compliance. It should be noted, however, that emissions from some insignificant activities are required to be tracked under the provisions of Colorado Regulation No. 3, Part C, Section II.E. These activities were clearly denoted as such in Appendix A of the operating permit. Calculated HAP emissions for this facility are summarized in the following table: Pollutant Uncontrolled Controlled Actual Emissions Emissions Emissions 123/0099 Page 6 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document-Renewal Operating Permit tons/year tons/year tons/year Acetaldehyde 0.00 0.00 0.00 Acrolein 0.00 0.00 0.00 Methanol 0.88 0.44 0.00 Formaldehyde 6.56 1.57 1.39 n-Hexane 16.13 7.30 0.72 2,2,4-TMP 0.15 0.15 0.00 Benzene 3.18 1.01 0.02 Toluene 2.45 0.65 0.00 Ethyl benzene 0.00 0.00 0.00 Xylenes 0.41 0.03 0.00 Facility Total 29.76 11.16 2.13 Source Determination With this permit action, the Division revisited the source determination in regards to the natural gas operations in the area surrounding the Greeley Natural Gas Processing Plant to verify that the proper pollutant emitting activities are included in this permit as part of the facility. The applicant did not identify any other pollutant emitting activities in the vicinity of the Greeley Natural Gas Processing Plant on that are dependent upon that facility to maintain operations. The Division considers the current determination for this facility to be accurate, and the proper pollutant emitting activities are included in this permit. Regulatory Applicability 40 CFR Part 63 Subpart ZZZZ MACT — National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines This section addresses the final version of Subpart ZZZZ, last updated in the Federal Register on 2/27/2014. For the purposes of the Greeley Natural Gas Processing Plant, this subpart applies to compressor engines. Affected facilities under this subpart include both area and major sources of HAP. A major source of HAP is defined in §63.2 as "any stationary source or group of stationary sources located within a contiguous area and under common control that emits or has the potential to emit considering controls, in the aggregate, 10 tons per year or more of any hazardous air pollutant or 25 tons per year or more of any combination of hazardous air pollutants". Section §63.6675 of Subpart ZZZZ lists four clarifications to this definition: 1. Emissions from any oil or gas exploration or production well (with its associated equipment (as defined in this section)) and emissions from any pipeline compressor station or pump station shall not be aggregated with emissions from other similar units, to determine whether such emission points or stations are major sources, even when emission points are in a contiguous area or under common control 123/0099 Page 7 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Based on the facility plot plan and source correspondence received on 4/25/2018, there are no exploration or production wells associated with the Greeley Natural Gas Processing Plant. Therefore, this clarification does not apply. 2. For oil and gas production facilities, emissions from processes, operations, or equipment that are not part of the same oil and gas production facility, as defined in §63.1271 of subpart HHH of this part, shall not be aggregated An oil and gas production facility, pursuant to §63.6675, "means any grouping of equipment where hydrocarbon liquids are processed, upgraded (i.e., remove impurities or other constituents to meet contract specifications), or stored prior to the point of custody transfer; or where natural gas is processed, upgraded, or stored prior to entering the natural gas transmission and storage source category'. A natural gas processing plant processes and upgrades natural gas prior to discharging it to the transmission sector. As such, the Greeley Natural Gas Processing Plant is considered an oil and gas production facility pursuant to the definition provided in §63.6675. Pursuant to the "facility" definition set forth in Subpart HHH §63.1271, a single facility is located on the same "surface site". "Surface site" is further defined in §63.1271 as "any combination of one or more graded pad sites, gravel pad sites, foundations, platforms, or the immediate physical location upon which equipment is physically affixed." The Greeley Natural Gas Processing Plant constitutes one individual surface site, and all emission sources within that surface site have been aggregated for the purposes of major source determination. No other sources from different surface sites were aggregated for the purposes of major source determination. 3. For production field facilities, only HAP emissions from glycol dehydration units, storage vessel with the potential for flash emissions, combustion turbines and reciprocating internal combustion engines shall be aggregated for a major source determination Production field facilities are defined in §63.6675 as "oil and gas production facilities located prior to the point of custody transfer". Custody transfer is defined in this subpart as "the point at which such liquids or natural gas enters a natural gas processing plant". The Greeley Natural Gas Processing Plant, as a natural gas processing plant is, by definition, located downstream of the point of custody transfer. Therefore, this clarification does not apply and all HAP sources were aggregated for the major source determination. 4. Emissions from processes, operations, and equipment that are not part of the same natural gas transmission and storage facility, as defined in §63.1271 of subpart HHH of this part, shall not be aggregated A natural gas transmission facility is defined in subpart HHH as "the pipelines used for the long distance transport of natural gas (excluding processing)". The Greeley Natural Gas Processing Plant is a processing facility and is therefore excluded from the definition of a natural gas transmission facility. As such, this clarification does not apply. 123/0099 Page 8 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Pursuant to the definition of major source set forth in §62.3, the HAP emissions from this facility are below the major source thresholds of 10 tons/year individual and 25 tons/year total HAP. Therefore, for the purposes of subpart ZZZZ, the Greeley Natural Gas Processing Plant is considered to be an area source of HAP emissions. Subpart ZZZZ requirements differ depending on whether or not the source is classified as "new" or "existing". For the purposes of Subpart ZZZZ, a stationary RICE located at an area source of HAP is considered new if construction is commenced after 6/12/2006 (§63.6590(a)(ii)). The following table summarizes the commenced construction date reported on the most recent APENs: Facility APEN Date of 40 CFR 60 AIRS ID Received Commenced Subpart ZZZZ Identifier Date Construction Classification 102 C-124 4/28/2017 Before 5/1986 Existing 103 C-116 5/15/2020 Before 12/2002 Existing 104 C-117 12/20/2019 Before 10/1979 Existing 105 C-118 12/20/2019 Before 4/1975 Existing 106 C-119 4/28/2017 Before 1974 Existing 107 C-120 12/20/2019 Before 6/12/2006 Existing 108 C-123 12/21/2018 12/1979 Existing 109 C-152 4/28/2017 Before 2001 Existing 110 C-122 12/20/2019 Before 4/2006 Existing Under Subpart ZZZZ, a source may be subject to work practice requirements only if it is classified as a "remote stationary RICE". These criteria are listed in §63.6675. It should be noted, however, that pursuant to the 2017 "RICE MACT Annual Class Location Evaluation" submitted by the source, the Greeley Natural Gas Processing Plant was identified as a non-remote location dating back to the July 2012 initial evaluation. As such, the engines at the Greeley Natural Gas Processing Plant do not qualify for these work practice requirements, and are subject to the full area-source requirements set forth in Subpart ZZZZ. Pursuant to the dates listed in the table above, all engines are subject to the area source requirements of Subpart ZZZZ for existing engines. It should be noted that that the 12/21/2018 APEN for C-123 listed a reconstruction date of 8/2018,which would have resulted in classification as a"new"engine for the purposes of this Subpart. However, in source comments received 5/22/2020 and 6/3/2020, it was indicated that this engine was not, in fact, "reconstructed" and that a commenced construction date of 12/1979 should be used for the purposes of Subpart ZZZZ applicability. The Subpart ZZZZ definition of reconstruction set forth in §63.6590 directly references the definition of reconstruction in the MACT Subpart A general provisions. Pursuant to §63.2, a reconstruction means that "the fixed capital cost of the new components exceeds 50 percent of the fixed capital cost that would be required to construct a comparable new source." In the reconstruction analysis provided in the 5/22/2020 source comments, the cost of the August 2018 overhaul was roughly 22% of the fixed capital cost of a new, comparable unit. As such the MACT definition of 123/0099 Page 9 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit reconstruction was not triggered and this engine, with a commenced construction date of 12/1979, is considered to be an "existing" engine for the purposes of Subpart ZZZZ. In addition to the compressor drivers, several smaller engines exist at the Greeley Natural Gas Processing Plant. These engines were identified in the insignificant activities list submitted on 5/31/2018. As noted above, a stationary RICE located at an area source of HAP is considered new for Subpart ZZZZ purposes if construction is commenced after 6/12/2006 (§63.6590(a)(ii)). The following table summarizes the commenced construction date reported in source comments received 6/3/2020: 40 CFR 60 Manufacturer Date of Commenced Engine Subpart ZZZZ Design Rating Construction Classification Honda GX24O Engine 7.9 hp 7/8/2003 Existing Kohler Command Pro 8.5 Engine 8.5 hp 2/5/2001 Existing Kohler Command Pro 10 Sweeper 10 hp Before 2006 Existing Brush Engine Briggs&Stratton Model 030549 14 hp Before 2006 Existing Emergency Genset Briggs&Stratton Model 303447- 1295-E1 Engine 16 hp 11/1/2001 Existing Pursuant to the dates listed in the table above, all engines are subject to the area source requirements of Subpart ZZZZ for existing engines. For a more detailed discussion on the incorporation of the requirements of MACT Subpart ZZZZ into the operating permit, refer to Sections V and VII of this document. 40 CFR Part 60 Subpart Dc NSPS - Standards of Performance for Small Industrial- Commercial-Institutional Steam Generating Units This section addresses the final version of Subpart Dc, last updated in the Federal Register on 2/16/2012. For the purposes of the Greeley Natural Gas Processing Plant, this subpart applies to hot oil heater P-139 only. Affected facilities under this subpart include "each steam-generating unit for which construction, modification, or reconstruction is commenced after June 9, 1989 and that has a maximum design heat input capacity of 29 megawatts (MVO (100 million British thermal units per hour (MMBtu/h)) or less, but greater than or equal to 2.9 MW (10 MMBtu/h)". A "steam generating unit" is defined in this subpart as "a device that combusts any fuel and produces steam or heats water or heats any heat transfer medium". Both heaters at the Greeley Natural Gas Processing Plant meet the definition of "steam generating unit" as they both heat hot oil, which is used as a heat transfer medium to facilitate various reboiler operations within the NGL fractionation train. Hot oil heater P-139 has a design heat input rating of 35.1 MMBtu/hr and commenced operation on 12/1/2008, as identified on the APEN received on 12/2/2013. As such, this heater meets both the date and design capacity thresholds for NSPS Dc applicability. 123/0099 Page 10 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Hot oil heater P-132 has a design heat input rating of 15 MMBtu/hr, which does fall within the applicability thresholds of NSPS Dc. However, as identified on the APEN received 4/30/2015, this hot oil heater commenced operation in 1987, predating the applicability of NSPS Dc. As such, P-132 is not subject to this NSPS. For a more detailed discussion on the incorporation of the requirements of NSPS Subpart Dc into the operating permit, refer to Section VII of this document. 40 CFR Part 60 Subpart KKK NSPS-Standards of Performance for Equipment Leaks of VOC From Onshore Natural Gas Processing Plants for Which Construction, Reconstruction or Modification Commenced After January 20, 1984, and on or Before August 23, 2011 This section addresses the final version of Subpart KKK, last updated in the Federal Register on 8/16/2012. For the purposes of the Greeley Natural Gas Processing Plant, this subpart applies to fugitive emissions. The Greeley Natural Gas Processing Plant has undergone construction, reconstruction and modification within the applicability timeframe and, as such, is subject to the provisions of Subpart KKK. It should be noted, however, that the 12/30/2017 updates to Colorado Regulation No. 7, Part D, Section I.G.1., which are federally enforceable, now require that a natural gas processing plant comply with the LDAR requirements of Subpart OOOO, regardless of the date of construction of the facility (see applicability discussion below). As such, the Greeley Natural Gas Processing Plant is subject to NSPS OOOO, pursuant to Colorado Regulation No. 7, Part D, Section I.G.1. For the purposes of the Greeley Natural Gas Processing Plant, compliance with NSPS KKK shall be presumed, except for compressors, provided the requirements of NSPS OOOO are met. For a more detailed discussion on the incorporation of the requirements of NSPS Subpart KKK into the operating permit, refer to Section VII of this document. 40 CFR Part 60 Subpart OOOO NSPS - Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution for which Construction, Modification or Reconstruction Commenced After August 23, 2011, and on or Before September 18, 2015 This section addresses the final version of Subpart OOOO, last updated in the Federal Register on 6/3/2016. For the purposes of the Greeley Natural Gas Processing Plant, this subpart applies to fugitive emissions for the entire facility. Affected facilities under Subpart OOOO are those which include any of the following: natural gas wells, centrifugal compressors, reciprocating compressors, natural gas driven pneumatic controllers, storage vessels, process units, sweetening units and hydraulically fractured gas well facilities that commence construction, reconstruction or modification after August 23, 2011 and before September 18, 2015. The Greeley Natural Gas Processing Plant does not have associated natural gas wells, centrifugal compressors, sweetening units or hydraulically fractured natural gas wells within the facility. All pneumatic controllers at the Greeley Natural Gas Processing Plant 123/0099 Page 11 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit are instrument air-driven, per source correspondence received 4/25/2018. Pursuant to source comments received 5/26/2020, all reciprocating compressors were constructed prior to the 8/23/2011 applicability date. All process units at the Greeley Natural Gas Processing Plant were also constructed prior to the applicability date of this subpart, and the source did not identify any qualifying modifications of these process units that subsequently took place during the applicability timeframe, pursuant to source correspondence received on 5/31/2018. The Greeley Natural Gas Processing Plant stores any condensate generated in a pressurized bullet tank. Pursuant to the definition of"storage vessel" Subpart OOOO, §60.5430, a "storage vessel"is defined as "a tank or other vessel that contains an accumulation of crude oil, condensate, intermediate hydrocarbon liquids, or produced water, and that is constructed primarily of nonearthen materials." This definition further lists the following exemptions: 1) Vessels that are skid-mounted or permanently attached to something that is mobile The condensate storage bullet at the Greeley Natural Gas Processing Plant is permanently affixed to a concrete pad. Therefore, this exclusion does not apply. 2) Process vessels such as surge control vessels, bottoms receivers or knockout vessels The condensate storage bullet is the final storage point for the condensate produced at the Greeley Natural Gas Processing Plant. This vessel is not designed to facilitate any type of gravity separation, or to provide surge capacity. There are no further downstream operations to process the condensate; it is unloaded directly from this vessel when exiting the facility. As such, the condensate storage bullet is not considered to be a process vessel and this exclusion does not apply. 3) Pressure vessels designed to operate in excess of 204.9 kilopascals (-'30 psi) and without emissions to the atmosphere The condensate storage bullet at the Greeley Natural Gas Processing Plant is a pressure vessel. As such, this vessel is designed to operate in excess of 30 psi. Furthermore, any vapor evolved from this tank is hard piped directly to a vapor recovery unit (VRU), which recompresses these vapors and routes them to the plant inlet. The condensate storage bullet is designed to accommodate any offgas in the event of VRU downtime. These vapors are therefore not routed to atmosphere at any point during operation. As such, this vessel fulfills the third exemption set forth in NSPS Subpart OOOO §60.5430, and is therefore not considered to be a storage vessel subject to this subpart. It should be noted that the 12/30/2017 updates to Colorado Regulation No. 7, Part D, Section I.G.1., which is federally enforceable, now require that a natural gas processing plant comply with the LDAR requirements of Subpart OOOO, regardless of the date of construction of the facility (see applicability discussion below). As such, the Greeley Natural Gas Processing Plant is subject to NSPS OOOO, pursuant to Colorado Regulation No. 7, Part D, Section I.G.1. It should be noted that for the purposes of the Greeley Natural Gas Processing Plant, compliance with NSPS KKK shall be presumed, except for compressors, provided the requirements of NSPS OOOO are met. 123/0099 Page 12 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit For a more detailed discussion on the incorporation of the requirements of NSPS Subpart OOOO into the operating permit, refer to Section VII of this document. 40 CFR Part 60 Subpart A §60.18 NSPS - Standards of Performance for New Stationary Sources General Control Device and Work Practice Requirements This section addresses the final version of Subpart A, §60.18, last updated in the Federal Register on 12/22/2008. For the purposes of the Greeley Natural Gas Processing Plant, this subpart applies to the plant flare. The plant flare was permitted under Colorado Construction Permit 15WE0939. In the significant modification received 5/2/2016, which addressed the incorporation of this construction permit into the Title V Operating Permit, the source indicated that the plant flare had commenced operation in 2004, and had been previously APEN and permit exempt due to uncontrolled actual emissions below the de minimis reporting threshold identified in Colorado Regulation No. 3, Part A, Section II.D.1.a and Part B, Section II.D.1.a). However, it was subsequently determined that actual uncontrolled emissions exceeded the de minimis threshold and, as such, a permit for the plant flare was requested, resulting in the issuance of Colorado Construction Permit 15WE0939. Pursuant to Subpart A, "the provisions of this part apply to the owner or operator of any stationary source which contains an affected facility, the construction or modification of which is commenced after the date of publication in this part of any standard (or, if earlier, the date of publication of any proposed standard) applicable to that facility' (§60.1(a)). The Greeley Natural Gas Processing Plant is an affected facility under the NSPS standards (see NSPS Subpart Dc, KKK and OOOO discussions above) and, as such, is subject to the requirements of Subpart A. The open flare requirements of Subpart A §60.18 are therefore applicable to the plant flare at the Greeley Natural Gas Processing Plant. For a more detailed discussion on the incorporation of the requirements of NSPS Subpart A §60.18 into the operating permit, refer to Section VII of this document. Colorado Regulation No. 7, Part D.Section I—Volatile Organic Compound Emissions from Oil and Gas Operations This section addresses the final version of Colorado Regulation No. 7, Part D, Section I., last updated 2/14/2020. For the purposes of the Greeley Natural Gas Processing Plant, this section applies to oil and gas operations located within the 8-Hour Ozone Control Area. Requirements applicable to the Greeley Natural Gas Processing Plant are as follows: • Section I.C.1. — General Requirements, including good engineering practice requirements. • Section I.G. — Gas Processing Plant Requirements, addressing fugitive emissions o It should be noted that this requirement was updated with the 12/30/2017 updates to Colorado Regulation No. 7 to require compliance with the fugitive emissions requirements of NSPS OOOO, regardless of the plant 123/0099 Page 13 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit construction date. Although the Greeley Natural Gas Processing Plant was constructed prior to the 8/23/2011 applicability date of NSPS OOOO, this requirement, which is federally enforceable for natural gas processing plants located in the 8-Hour Ozone Control Area, subjects this facility to the requirements of NSPS OOOO (see above applicability discussion) for fugitive emissions. It should be noted, however, that the Greeley Natural Gas Processing Plant is subject to NSPS KKK on a federal level, based on the plant's construction date (see Section III of this document). Since this Section I.G.1 requires compliance with NSPS OOOO, compliance with NSPS KKK shall be presumed for all components, except for compressors, provided the requirements of NSPS OOOO are met. • Section I.H. — Natural Gas Dehydration Units Requirements, addressing VOC emission reductions, monitoring and recordkeeping relating to the air pollution control equipment utilized, and semi-annual reporting • Section I.J. — Reciprocating compressor requirements, addressing periodic rod packing replacements and rod packing emissions collection systems For a more detailed discussion on the incorporation of the requirements of Colorado Regulation No. 7, Part D, Section I. into the operating permit, refer to Section VII of this document. The following requirements from Colorado Regulation No. 7, Part D, Section I. were found to be non-applicable to the Greeley Natural Gas Processing Plant pursuant to the provided justification: • Section I.C.1.c., d. and e. — These conditions set forth requirements for combustion devices used to comply with Section I.D., I.J. and I.K. The Greeley Natural Gas Processing Plant is not subject to Sections I.D. and I.K. pursuant to the justifications listed in this section below. The compressors at this facility are subject to Section I.J. However, pursuant to source correspondence received on 5/8/2018, the compliance option chosen to comply with the applicable requirements of Section I.J. does not employ a combustion device. As such, the combustion device requirements of Section I.C.1.c., d., and e. do not apply to the Greeley Natural Gas Processing Plant. • Section I.C.1.f. — This condition requires a surveillance system be installed for condensate storage tanks with uncontrolled actual emissions of VOC greater than 100 tons/year. All condensate at the Greeley Natural Gas Processing Plant is stored in a pressurized bullet tank. Overpressure emissions are hard-piped directly to the vapor recovery unit (VRU) and returned to the plant inlet. If the VRU experiences any downtime, the condensate storage bullet is designed to accommodate excess offgas during this time and does not vent to atmosphere. As such, this tank does not operate with emissions to atmosphere and, therefore, does not have associated uncontrolled actual emissions. Therefore, this condensate storage bullet is not subject to the surveillance requirements of Section I.C.1.f. 123/0099 Page 14 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit • Section I.C.2. — This condition applies to condensate storage tanks subject to Section I.D. The condensate storage bullet at the Greeley Natural Gas Processing Plant is not subject to Section I.D. (see below determination). As such, the requirements of Section I.C.2. do not apply to this facility. • Part D, Section I.D.1. — This section sets forth control requirements for condensate storage tanks located within the 8 hour ozone control area through 4/30/2020. Because the operating permit will be issued after this date, the requirements of Part D, Section I.D.1 were not included in the operating permit. • Part D, Section I.D.2. — This section sets forth control requirements for new and modified condensate storage tanks located within the 8 hour ozone control area through 3/1/2020. Because the operating permit will be issued after this date, the requirements of Part D, Section I.D.2 were not included in the operating permit. • Part D, Section I.D.3. — This section sets forth control requirements for storage tanks (including condensate and produced water tanks) with actual uncontrolled emissions of VOC greater than or equal to 4 tons/year(or 2 tons/year, as a state- only requirement) within the 8 hour ozone control area. Pursuant to the definition set forth in Section I.B.26., a "storage tank" means "any fixed roof storage vessel or series of storage vessels that are manifolded together via liquid line." The definition of "storage vessel" in Section I.B.27. states that "storage vessel does not include... pressure vessels designed to operate in excess of 204.9 kilopascals and without emissions to the atmosphere."The condensate and NGL bullet tanks at the Greeley Natural Gas Processing Plant are designed to operate in excess of this pressure and operate without emissions to atmosphere. Therefore, these storage bullets are not considered to be "storage tanks" subject to Colorado Regulation No. 7, Part D, Section I.D. As such, the requirements for storage tanks under this section are not applicable to the storage bullets at the Greeley Natural Gas Processing Plant. • Part D, Section I.D.4. — This section sets forth requirements for alternative emissions control equipment for storage vessels subject to Section I.D. As noted above, no storage tanks at the Greeley Natural Gas Processing Plant are subject to Section I.D. requirements. This section was therefore not included in the operating permit. • Section I.E. —This section addresses monitoring for storage tanks operating in a non-attainment area that are "controlled pursuant to this Section I" and "any storage tank subject to Section I.D.3.a.(ii)". The control requirements for storage tanks in Section I are contained within Section I.D, which is not applicable to the Greeley Natural Gas Processing Plant (see discussion above). As such, the condensate and NGL bullet tanks at the Greeley Natural Gas Processing Plant are not being "controlled pursuant to this Section 1.", nor are they subject to Section I.D.3.a.(ii), and are therefore not subject to Section I.E. • Section I.F — This section addresses the recordkeeping and reporting requirements for storage tanks and applies to storage tanks subject to Section I.D. The condensate and NGL bullet tanks at the Greeley Natural Gas Processing 123/0099 Page 15 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Plant are not subject to I.D. (see discussion above) and are therefore not subject to the requirements of I.F. • Section I.G.2. — This section requires that control devices for atmospheric condensate tanks achieve a control efficiency of 95%. The condensate stored at the Greeley Natural Gas Processing Plant is stored in a pressurized bullet tank that operates without emissions to the atmosphere. Because this Section I.G.2. requirement specifically applies to atmospheric (i.e., non-pressurized) condensate storage tanks, this requirement is not applicable to the Greeley Natural Gas Processing Plant and was therefore not included in the operating permit. • Section I.I. — These exemptions are applicable only to compressor stations and drip stations. The Greeley Natural Gas Processing Plant is, for the purposes of Colorado Regulation No. 7, Part D, Section I, classified as a natural gas processing plant and is not considered to be a natural gas compressor station or drip station. Therefore, this facility does not qualify for the exemptions set forth in Section I.I. • Section I.K. — This section sets forth requirements for natural gas driven pneumatic pumps operating in the ozone non-attainment area. Per source correspondence received 4/25/2018, there are no natural gas driven pneumatic pumps present at the Greeley Natural Gas Processing Plant. As such, Section I.K. does not apply to this facility. • Section I.L. — This section sets forth LDAR requirements for natural gas compressor stations and well production facilities operating in the ozone non- attainment area. The Greeley Natural Gas Processing Plant, for the purposes of Colorado Regulation No. 7, Part D, Section I, is classified as a natural gas processing plant and is not a compressor station nor a well production facility. Therefore, Section I.L. is not applicable to this facility. Colorado Regulation No. 7, Part D, Section II — Statewide Controls for Oil and Gas Operations This section addresses the final version of Colorado Regulation No. 7, Part D, Section II, last updated 2/14/2020. For the purposes of the Greeley Natural Gas Processing Plant, this section applies to oil and gas operations located within the state of Colorado. Requirements applicable to the Greeley Natural Gas Processing Plant are as follows: • Section II.B — General Provisions, including good engineering practice and air pollution control requirements • Section II.D — Dehydration Unit Requirements, addressing VOC and hydrocarbon emission reductions For a more detailed discussion on the incorporation of the requirements of Colorado Regulation No. 7, Part D, Section II. into the operating permit, refer to Section VII of this document. 123/0099 Page 16 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit The following requirements from,Colorado Regulation No. 7, Part D, Section II were found to be non-applicable to the Greeley Natural Gas Processing Plant pursuant to the provided justification: Section II.B.3. —The requirements in Section II.B.3. pertain to open ended lines located at well production facilities and natural gas compressor stations (II.B.3.a.), wet seal centrifugal compressors (II.B.3.b.) and rod packing for reciprocating compressors located at natural gas compressor stations (II.B.3.c.). Because the Greeley Natural Gas Processing Plant is classified as a "natural gas processing plant" for the purposes of Colorado Regulation No. 7, and there are no wet seal centrifugal compressors located at this facility, none of the requirements of Section II.B.3. are applicable to this facility. Section II.B.5. — This section allows for an exemption for dehydration units from complying with the Section II requirements, provided these units "are subject to an emissions control requirement in a federal maximum achievable control technology ("MACT") standard under 40 CFR Part 63, a Best Available Control Technology ("BACT") limit, or a New Source Performance Standard ("NSPS") under 40 CFR Part 60 are not subject to Section II., except for the leak detection and repair requirements in Section II.E". The natural gas dehydration unit is not subject to an applicable federal standard, including 40 CFR 63 Subpart HH (see discussion below). As such, the dehydration unit at the Greeley Natural Gas Processing Plant is subject to the provisions of Section II. Section II.C. — This section sets forth requirements for condensate storage tanks. Pursuant to the definition set forth in Section II.A.20., a "storage tank" means "any fixed roof storage vessel or series of storage vessels that are manifolded together via liquid line." The definition of "storage vessel" in Section II.A.22. states that "storage vessel does not include... pressure vessels designed to operate in excess of 204.9 kilopascals and without emissions to the atmosphere."The condensate and NGL bullet tanks at the Greeley Natural Gas Processing Plant are designed to operate in excess of this pressure and operate without emissions to atmosphere. Therefore, these storage bullets are not considered to be "storage tanks" subject to Colorado Regulation No. 7, Part D, Section II.C. As such, the requirements for storage tanks under this section are not applicable to the storage bullets at the Greeley Natural Gas Processing Plant. In addition, the pressurized loadout of NGL and condensate at the Greeley Natural Gas Processing Plant is not subject to the loadout requirements of Colorado Regulation No. 7, Part D, Section II.C.5. These requirements are applicable only if the storage tanks from which the liquids are being loaded out from are controlled. As stated above, none of these bullet-style tanks are controlled, as they are designed to operate in excess of 204.9 kpa and without emissions to the atmosphere. As such, the pressurized NGL and condensate loadout at the Greeley Natural Gas Processing Plant is not subject to the requirements of Section II.C.5. Section II.E. — Section II.E. sets forth LDAR requirements for well production facilities and natural gas compressor stations. Since the Greeley Natural Gas Processing Plant is classified as a natural gas processing plant and is not considered to be a well production facility or a compressor station, it is not subject to the LDAR requirements of II.E. 123/0099 Page 17 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Section II.F. — This section requires emissions control from well production facilities. Since the Greeley Natural Gas Processing Plant is classified as a natural gas processing plant and is not considered to be a well production facility, it is not subject to the emissions control requirements of Section II.F. Section II.G. — This section regulates venting during well maintenance, well liquids unloading and well plugging. The Greeley Natural Gas Processing Plant does not own or operate any natural gas wells within the facility and is therefore not subject to the requirements of Section II.G. Colorado Regulation No. 7, Part D, Section V — Oil and Natural Gas Operations Emissions Inventory This section addresses the final version of Colorado Regulation No. 7, Part D, Section V, last updated 2/14/2020. For the purposes of the Greeley Natural Gas Processing Plant, this section applies on a facility-wide basis. These requirements are applicable to "oil and natural gas operations and equipment at or upstream of a natural gas processing plant in Colorado" (Section V.A). The Greeley Natural Gas Processing Plant is considered to be a natural gas processing plant for the purposes of this section and therefore subject to the applicable reporting requirements for various operation and equipment categories. For a more detailed discussion on the incorporation of the requirements of Colorado Regulation No. 7, Part D, Section V. into the operating permit, refer to Section VII of this document. Colorado Regulation No. 7, Part E, Section I — Control of Emissions from Engines This section addresses the final version of Colorado Regulation No. 7, Part E, Section I, last updated 2/14/2020. For the purposes of the Greeley Natural Gas Processing Plant, this section applies to stationary engines. Requirements applicable to the Greeley Natural Gas Processing Plant are as follows: • Section I.B. — Air pollution control technology requirements for rich burn reciprocating internal combustion engines operating within the 8-Hour Ozone Control Area. o Pursuant to Section I.A., the requirements of Section I.B. apply to both new (commenced operations after 6/1/2004) and existing (commenced operation before 6/1/2004) natural gas fired stationary internal combustion engines with a manufacturer's design rating of greater than 500 hp that operate in the 8-Hour Ozone Control Area. The Greeley Natural Gas Processing Plant is located within the 8-Hour Ozone Control area. Engine sizes based on the most recent APENs are summarized in the following table: AIRS ID APEN Received Facility Manufacturer Date Identifier Design Rating 102 4/28/2017 C-124 125 hp 123/0099 Page 18 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit AIRS ID APEN Received Facility Manufacturer Date Identifier Design Rating 103 5/15/2020 C-116 1,100 hp 104 12/20/2019 C-117 1,100 hp 105 12/20/2019 C-118 1,100 hp 106 4/28/2017 C-119 1,100 hp 107 12/20/2019 C-120 1,100 hp 108 12/21/2018 C-123 896 hp 109 4/28/2017 C-152 1,100 hp 110 12/20/2019 C-122 1,100 hp Based on the engine sizes identified, all engines, except C-124 (AIRS 102), are subject to the air pollution control technology requirements of Colorado Regulation No. 7, Part E, Section I.B. • Section I.D. — Control of emissions from new, modified, existing and relocated natural gas fired reciprocating internal combustion engines o This section sets forth requirements for natural gas fired reciprocating internal combustion engines. Engines constructed or relocated to Colorado after the dates set forth in Table 1 of Section I.D.2.b. are subject to emission standards. Rich burn engines greater than 500 hp constructed or modified prior to 2/1/2009 are required to install NSCR and AFR. The following table summarizes the applicability of the Section I.D. requirements for each engine: APEN Date of Date of CO Reg. No.7, CO Reg. No.7, AIRS Facility Manufacturer Part E,Section Part E, Received Construction/ (re)Location ID Identifier Date Design Rating Modification to CO I.D.2 Section I.D.3 Requirement Requirement 102 C-124 4/28/2017 125 hp Before 5/1986 1986 -- -- 103 C-116 5/15/2020 1,100 hp Before Before 12/2002 12/2002 104 C-117 12/20/2019 1,100 hp Before Before 1986 -- -- 10/1979 105 C-118 12/20/2019 1,100 hp Before 4/1975 Before 4/1975 -- -- 106 C-119 4/28/2017 1,100 hp Before 1974 Before 2007 -- -- 107 C-120 12/20/2019 1,100 hp Before Before 6/12/2006 6/12/2006 108 C-123 12/21/2018 896 hp 12/1979 8/24/2018 7/1/2010 Limits -- 109 C-152 4/28/2017 1,100 hp Before 2001 Before 2001 -- -- 123/0099 Page 19 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit APEN Date of Date of CO Reg. No.7, CO Reg. No.7, AIRS Facility Manufacturer Part E,Section Part E, ID Identifier Received Design Rating Construction/ (re)Location I.D.2 Section I.D.3 Date Modification to CO Requirement Requirement 110 C-122 12/20/2019 1,100 hp Before 4/2006 Before 4/2006 -- As can be seen from the table above, only engine C-123 was relocated to Colorado within the applicability timeframe of emission standards listed in Table 1 of Section I.D.2.b. As such, this engine only is required to comply with the 7/1/2010 emission standards listed in Table 1 of Section I.D.2.b. No other engines have been relocated into Colorado within the timeframes specified in Table 1 and, as such, C-123 only is subject to the emission standard requirements of Colorado Regulation No. 7, Part E, Section I.D.2. All engines were constructed prior to 2/1/2009, however, none of them are subject to the Section I.D.3. control equipment installation requirements. Engine C-124 is less than 500 hp and, as such, is not required to install NSCR and AFR pursuant to this regulation (note, however, this engine is equipped with both an NSCR and AFR, pursuant to the most recent APEN). All other engines meet the Section I.D.3.a.(i)(B) exemption, which states that "(i)nternal combustion engines that are subject to an emissions control requirement in a federal maximum achievable control technology ("MACT") standard under 40 CFR Part 63 (January 1, 2011), a Best Available Control Technology("BACT") limit, or a New Source Performance Standard under 40 CFR Part 60 (January 1, 2011) are not subject to this Section II.E(D).3.a." All of the remaining engines located at the Greeley Natural Gas Processing Plant are subject to control device installation requirements under 40 CFR Part 63 Subpart ZZZZ. These requirements are considered by the Division to be sufficient "emissions control requirements", and, as such, these engines are exempt from the requirements of Colorado Regulation No. 7, Part E, Section I.D.3.a., pursuant to the Section I.D.3.a.(i)(B) exemption. Colorado Regulation No. 7, Part E, Section II — Control of Emissions from Stationary and Portable Engines and Other Combustion Equipment in the 8-Hour Ozone Control Area This section addresses the final version of Colorado Regulation No. 7, Part E, Section II, last updated 2/14/2020. For the purposes of the Greeley Natural Gas Processing Plant, this section applies to combustion equipment located within the 8-Hour Ozone Control Area. • Section II.A. — Combustion Process Adjustment requirements o The requirements of this section apply to combustion equipment with uncontrolled actual NOx emissions in excess of 5 tons/year that are located at an existing major source for NOx as of 6/3/2016, under the moderate non-attainment major source threshold of 100 tons/year. The Greeley Natural Gas Processing Plant was considered to be a major 123/0099 Page 20 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit source of NOx prior to 6/3/2016. As such, affected equipment at this facility includes the following: • Stationary internal combustion engines of any rated horsepower with uncontrolled actual emissions greater than 5 tons/year are required to comply with Section II.A. All engines at the Greeley Natural Gas Processing Plant are therefore subject to this section. • Process heaters with actual uncontrolled emissions greater than 5 tons/year are required to comply with the requirements of Section II.A. The Section II.A. definition of a process heater is "an enclosed device using controlled flame and a primary purpose to transfer heat indirectly to a process material or to a heat transfer material for use in a process". The hot oil heaters at the Greeley Natural Gas Processing Plant are used to transfer heat via combustion to a hot oil heat medium that is used to supply the heat necessary to operate process reboilers. Additionally, each heater is capable of producing actual uncontrolled emissions of NOx greater than the 5 ton/year applicability threshold for this section. As such, these heaters are affected combustion equipment under Section II.A. For a more detailed discussion on the incorporation of the requirements of Colorado Regulation No. 7, Part E, Section II.A. into the operating permit, refer to Section VII of this document. Non-Applicable Regulations The Greeley Natural Gas Processing Plant was determined to be totally exempt from the following regulations: MACT Subpart HH — Subpart HH applies to oil and natural gas production facilities. Affected facilities under this subpart include both area and major sources of HAP. Pursuant to the HAP summary table above, the Greeley Natural Gas Processing Plant is a synthetic minor source for HAP (i.e., total HAP emissions do not exceed 25 tons/year and facility-wide individual HAP emissions do not exceed 10 tons/year). As such, the Greeley Natural Gas Processing Plant is considered to be an area source of HAP pursuant to the definition of major source set forth in §63.761. Areas sources of HAP emissions are required to comply only with the TEG dehydration unit requirements of Subpart HH (§63.760(b)(2)). The Greeley Natural Gas Processing Plant does not operate a TEG dehydration unit. P-130 (AIRS 111) is an ethylene glycol (EG) dehydration unit, which is not an affected source pursuant to Subpart HH for area sources of HAP. As such, no part of Subpart HH is applicable to the Greeley Natural Gas Processing Plant. MACT Subpart DDDDD — Subpart DDDDD applies to Industrial, Commercial and Institutional Boilers and process heaters at major sources of HAP. The Greeley Natural Gas Processing Plant is a synthetic minor source of HAP (see HAP discussion above). As such, the provisions of Subpart DDDDD do not apply to this facility. 123/0099 Page 21 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit MACT Subpart JJJJJJ — Subpart JJJJJJ applies to Industrial, Commercial and Institutional Boilers located at area sources of HAP. Pursuant to §63.11237, a boiler is defined as "an enclosed device using controlled flame combustion in which water is heated to recover thermal energy in the form of steam and/or hot water... process heaters...are excluded from the definition of Boiler."The heaters P-132 (AIRS 113) and P-139 (AIRS 120) transfer heat to a hot oil media which is used to supply heat for reboilers operating in the NGL fractionation train. These heaters are therefore considered "process heaters" for the purposes of this Subpart and, as such, are not subject to the requirements of Subpart JJJJJJ. NSPS Subpart JJJJ — Subpart JJJJ applies to stationary spark ignition internal combustion engines. Affected facilities under this subpart include engines that commence construction after 6/12/2006 and were manufactured "on or after July 1, 2007, for engines with a maximum engine power greater than or equal to 500 HP (except lean burn engines with a maximum engine power greater than or equal to 500 HP and less than 1,350 HP)." (§60.4230(a)(4)(i)). For the purposes of Subpart JJJJ "the date that construction commences is the date the engine is ordered by the owner or operator." Furthermore, "owners and operators of stationary SI ICE that are modified or reconstructed after June 12, 2006, and any person that modifies or reconstructs any stationary SI ICE after June 12, 2006" are subject to NSPS JJJJ (§60.4230(a)(5)). A summary of the date of order and the date of manufacture, as indicated by the most recently submitted APENs, are summarized in the table below: APEN 40 CFR 60 AIRS Facility Date of Received Date of Order Subpart JJJJ ID Identifier Manufacture Date Applicability 102 C-124 4/28/2017 Before 5/1986 Before 5/1986 No 103 C-116 5/15/2020 Before 12/2002 Before 12/2002 No 104 C-117 12/20/2019 Before 10/1979 10/5/1979 No 105 C-118 12/20/2019 Before 4/1975 4/9/1975 No 106 C-119 4/28/2017 Before 1974 3/1/1974 No 107 C-120 12/20/2019 Before 4/1985 4/12/1985 No 108 C-123 12/21/2018 12/1979 12/1979 No 109 C-152 4/28/2017 Before 2001 Before 2001 No 110 C-122 12/20/2019 Before 4/2006 Before 4/2006 No Based on the dates listed in the table above, none of the engines are subject to Subpart JJJJ, Note that on the 12/21/2018 APEN submitted for engine C-123, a reconstruction date of 8/2018 was listed. In source comments received 5/22/2020, it was indicated that the overhaul conducted in August 2018 on this engine did not constitute a "reconstruction" for the purposes of NSPS JJJJ. Pursuant to the definitions set forth in §60.4248, date of manufacture for reconstructed engines is the date the engine is originally produced, except where "the fixed capital cost of the new and refurbished components exceeds 75 percent of the fixed capital cost of a comparable entirely new facility..._In these cases, the date of manufacture is the date of reconstruction...". A reconstruction cost analysis was submitted for engine C-123 with the source comments 123/0099 Page 22 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit received 5/22/2020, indicating that the cost of the August 2018 overhaul was roughly 22% of the fixed capital cost of a new, functionally equivalent unit. As such, the §60.4248 definition of reconstruction was not triggered, and the date of manufacture of this engine should not be updated to 8/2018. Further, it should be noted that this engine did not trigger the general NSPS definition of reconstruction set forth in §60.15(b)(1) since the fixed capital cost of new components did not exceed 50% of the fixed capital cost required to construct an entirely new, comparable engine. In summary, C-123 has not been reconstructed and is not subject to the requirements of NSPS JJJJ, nor are any of the other engines at the Greeley Natural Gas Processing Plant. NSPS Subpart Kb— Subpart Kb applies to storage vessels with a capacity greater than 75m3 (-472 bbl) used to store volatile organic liquids for which construction/reconstruction/modification took place after July 23, 1984. There are multiple pressurized bullet tanks at this facility, storing propane, butane, B-G mix NGLs, Y-Grade NGLs, isopentane, natural gasoline and condensate. Each tank is in excess of the 472 bbl threshold for NSPS Kb applicability. However, per 60.110b(d)(2), subpart Kb does not apply to pressure vessels designed to operate in excess of 204.9 kPa (-30 psi) which do not emit pollutants to atmosphere. The bullet tanks at the Greeley Natural Gas Processing Plant fulfill both of these exemption requirements and are therefore not subject to Subpart Kb. Colorado Regulation No. 7, Part B, Section IV- Section IV establishes requirements for the storage and transfer of petroleum liquid. Per the definitions set forth in Section IV, petroleum liquids are defined as "crude oil, condensate and any finished or intermediate product manufactured or extracted in a petroleum refinery". The Greeley Natural Gas Processing Plant stores condensate and NGL on its premises. However, the Division has determined that the original intent of this rule was to regulate gasoline loading stations and other sources not otherwise subject to requirements contained in Colorado Regulation No. 7. Because the Greeley Natural Gas Processing Plant is an affected facility under Colorado Regulation No. 7, Part D Sections I. and II. for oil and natural gas operations, the requirements of Section IV do not apply to this facility. Colorado Regulation No. 7, Part D, Section III — Section III. pertains to natural gas actuated pneumatic controllers associated with oil and gas operations. Per source correspondence received 4/25/2018, there are no natural gas actuated pneumatic controllers present at the Greeley Natural Gas Processing Plant. All pneumatic controllers are instrument air-driven. As such, this section does not apply to this facility. Colorado Regulation No. 7, Part D, Section IV— Section IV sets forth emissions control requirements and reporting for the natural gas transmission and storage segment. "Natural gas transmission and storage segment" is defined in Section IV.A.3. as "onshore natural gas transmission pipelines, onshore natural gas transmission compression, underground natural gas storage, and liquefied natural gas (LNG) storage, as these terms are defined in 40 CFR Part 98, Section 98.230 (October 22, 2015), that are physically located in Colorado." Subpart W (40 CFR Part 98 §98.230) defines "onshore natural gas transmission compression" as "any stationary combination of compressors that move natural gas from production fields, natural gas processing plants, or other transmission compressors through transmission pipelines to natural gas distribution pipelines, LNG storage facilities, or into underground storage." The Greeley 123/0099 Page 23 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Natural Gas Processing Plant, for the purposes of Colorado Regulation No. 7, Part D, is considered to be a natural gas processing plant. As such, this facility is not included in the natural gas transmission and storage segment for the purposes of Colorado Regulation No. 7, Part D, Section IV and is therefore not subject to these requirements. Colorado Regulation No. 7, Part E, Section III — Section III.A. requires that stationary internal combustion engines comply with the applicable NOx emission limitations and associated monitoring, recordkeeping and reporting requirements in 40 CFR Part 63, Subpart ZZZZ as expeditiously as practicable, but no later than 1/1/2017. Engine C-124 (AIRS 102) is explicitly identified in Section III.A.1.c. as an engine that must comply with the applicable requirements of 40 CFR Part 63, Subpart ZZZZ. Per the 2017 inspection report, the source is in compliance with all applicable requirements of Subpart ZZZZ. As such, this requirement for engine C-124 has been met and was not included in the operating permit. IV. CONSTRUCTION PERMIT REQUIREMENTS Colorado Construction Permit 15WE0939 - 33 MMSCFD EG Dehydration Unit P- 130, AIRS ID 111 and Plant Flare, AIRS ID 122 This section addresses the conditions established in Colorado Construction Permit 15WE0939, Issuance 1. This permit was issued on 5/16/2016 and was granted final approval to operate on 12/16/2016. It should be noted that EG dehydration unit P-130 was previously incorporated into the operating permit in the 5/1/2009 issuance. However, the source had subsequently requested modification to this point via construction permitting, and, as a result, Colorado Construction Permit 15WE0939 was issued to permit both the requested changes to dehydration unit P-130 and incorporate the plant flare as a newly permitted point. The requirements from this construction permit have been incorporated into the operating permit as follows: Conditions 1 through 6: These conditions set forth the final approval requirements for a newly issued construction permit. Final approval to operate was authorized by the Division 12/16/2016. As such, these requirements have been met and are not required to be included in the operating permit. Condition 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): P-130 -VOC: 34 lb/month, 0.2 tons/year Flare — NOx: 2.6 tons/year; VOC: 19.8 tons/year; CO: 11.4 tons/year • The requirement to comply with the monthly limitation was not included in the operating permit. Monthly limitations are required for the first 12 months of operation in order to establish a rolling 12 month total. Because the EG Dehydration Unit has operated in excess of 12 months at the time of operating permit renewal, a rolling 12 month total has been established and compliance with only the annual limitation is required. This annual limit was included in the operating permit. 123/0099 Page 24 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit • With the significant modification received 4/27/2020, the Greeley Natural Gas Processing Plant is now considered to be a synthetic minor source of HAP and requires limitations to ensure the facility retains its area source status under the 40 CFR Part 63 MACT rules. As such, this condition was modified to require the calculation of HAP emissions for both the dehydration unit and plant flare, in order to monitor compliance against the facility-wide synthetic minor HAP limits. Condition 8: Compliance with the emission limits in this permit shall be demonstrated by running the GRI GlyCalc model version 4.0 or higher on a monthly basis using the most recent wet gas analysis and recorded operational values (including gas throughput, lean glycol recirculation rate, VRU downtime and other operational values specified in the O&M Plan). Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into GRI GlyCalc and be provided to the Division upon request. • The requirements in this condition were addressed within the VOC emission limitation calculation condition of the operating permit, as well as a condition created to specifically identify monitored parameters for use in the GLYCaIc process model runs. For more information on the specific monitored parameters, refer to Section V of this document. Condition 9: 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.). P-130 — Flash Tank: VRU, combustor during downtime; Still Vent: enclosed combustor FLARE — Open flare • Each piece of control equipment listed was incorporated into the operating permit for the indicated emissions point.As such, this explicit condition was not included in the operating permit. Condition 10: Point 111 — 95% of emissions that result from the flash tank associated with this dehydrator shall be recycled and recompressed. Maximum of 5% downtime from the flash tank associated with this dehydrator shall be routed to the enclosed combustor. • This condition was modified to define the monitoring required to determine compliance with the 5% VRU downtime. The wet gas throughput to the dehydration unit during periods of VRU downtime shall not exceed 5% of the total actual wet gas throughput to the dehydration unit on a rolling twelve month basis. For more information on how this specific requirement was incorporated, refer to Section V of this document. • It should be noted that pursuant to the Equipment Table in Colorado Construction Permit 15WE0939, the ECD is allotted 5% downtime as well. This condition was incorporated into the operating permit in a similar fashion to the VRU downtime requirements listed above. The wet gas throughput to the dehydration unit during 123/0099 Page 25 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit periods of ECD downtime shall not exceed 5% of the total wet gas throughput to the dehydration unit on a rolling twelve month basis. For more information on how this specific requirement was incorporated, refer to Section V of this document. Condition 11: 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): P-130 — 1023 MMSCF/month; 12,045 MMSCF/yr FLARE - 55.91 MMSCF/yr • The requirement to comply with the monthly limitation was not included in the operating permit. Monthly limitations are required for the first 12 months of operation in order to establish a rolling 12 month total. Because the EG Dehydration Unit has operated in excess of 12 months at the time of operating permit renewal, a rolling 12 month total has been established and compliance with only the annual limitation is required. This annual limit was included in the operating permit. Condition 12: Point 111 — This unit shall be limited to the maximum lean glycol circulation rate of 6.0 gallons per minute. The lean glycol recirculation rate shall be recorded daily in a log maintained on site and made available to the Division for inspection upon request. (Reference: Regulation No. 3, Part B, II.A.4). Condition 13: 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). • This condition is considered to be a construction permit only condition and was therefore not included as a separate condition in the operating permit. Condition 14: Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section I I.A.1. & 4.). • It should be noted that the plant flare and enclosed combustion device are considered by the Division to instead be subject to the smokeless flare requirements of Section I I.A.5., which requires the source to operate below 30% opacity at all times. This Colorado Regulation No. 1 opacity requirement was included in the operating permit instead of the Section II.A.1 and 4 requirements set forth in the construction permit. • Note that Colorado Regulation No. 7 citations were significantly altered with the 2/14/2020 promulgation. The new citations for the requirements referenced in this condition are Part D, Sections 1.C.1.d. and II.B.2.b. 123/0099 Page 26 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Condition 15:This source is subject to the odor requirements of Regulation No. 2. (State only enforceable). • This condition is included in the General Conditions of Section IV in the operating permit, and was not included as a separate condition for this AIRS point in Section II of the operating permit. Condition 16: Point 111 — This equipment is subject to the control requirements for glycol natural gas dehydrators under Regulation No. 7, Section XII.H. Beginning May 1, 2005, uncontrolled actual emissions of volatile organic compounds from the still vent and vent from any gas-condensate-glycol (GCG) separator (flash separator or flash tank), if present, shall be reduced by at least 90 percent through the use of air pollution control equipment. This source shall comply with all applicable general provisions of Regulation 7, Section XII. • All applicable conditions from Colorado Regulation No. 7, Section XII.C. and Section XII.H. have been included in the operating permit. For specific requirements, refer to Section V of this document. • Note that Colorado Regulation No. 7 citations were significantly altered with the 2/14/2020 promulgation. The new citations for the requirements referenced in this condition are Part D, Sections I.C and I.H. Condition 17: Point 111 — This equipment is subject to the control requirements for glycol natural gas dehydrators under Regulation No. 7, Section XVII.D (State only enforceable). • All applicable conditions from Colorado Regulation No. 7, Section XVII.D. have been included in the operating permit. For specific requirements, refer to Section V of this document. • Note that Colorado Regulation No. 7 citations were significantly altered with the 2/14/2020 promulgation. The new citation for the requirements referenced in this condition is Part D, Section II.D. Condition 18: Point 111 —The enclosed combustor covered by this permit is subject to Regulation No. 7, Section XVII.B. General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed, have no visible emissions during normal operations, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XVII. • All applicable conditions from Colorado Regulation No. 7, Section XVII.B. have been included in the operating permit. For specific requirements, refer to Section V of this document. 123/0099 Page 27 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit • Note that Colorado Regulation No. 7 citations were significantly altered with the 2/14/2020 promulgation. The new citation for the requirements referenced in this condition is Part D, Section II.B. Condition 19: Point 122 — The Division has determined this flare shall comply with the New Source Performance Standards requirements of Subpart A Section §60.18, General Control Device and Work Practice Requirements, including, but not limited to, the following: Condition 19.a: Flares. Paragraphs (c) through (f) apply to flares (§60.18(b)). • The specific conditions of paragraphs (c) through (f) of this subpart were included in the operating permit directly. As such, this referencing condition was not included in the operating permit. Condition 19.b: Flares shall be designed for and operated with no visible emissions as determined by the methods specified in paragraph (f), except for periods not to exceed a total of 5 minutes during any 2 consecutive hours (§60.18(c)(1)). Condition 19.c: Flares shall be operated with a flame present at all times, as determined by the methods specified in paragraph (f) (§60.18(c)(2)). Condition 19.d: An owner/operator has the choice of adhering to either the heat content specifications in paragraph (c)(3)(ii) of this section and the maximum tip velocity specifications in paragraph (c)(4) of this section, or adhering to the requirements in paragraph (c)(3)(i) of this section (§60.18(c)(3)). • Per the 2017 inspection report and source correspondence received on 5/10/2018, this flare is non-assisted and the source complies with the heat content requirements of §60.18(c)(3)(ii) and §60.18(c)(4). As such, these applicable requirements were included in the operating permit. Because the source has chosen not to comply with the requirements of §60.18(c)(3)(ii), the requirements of§60.18(c)(3)(i) were not included in the operating permit. Condition 19.e: Air-assisted flares shall be designed and operated with an exit velocity less than the velocity, Vmax, as determined by the method specified in paragraph (f)(6) (§60.18(c)(5)). • Per source correspondence received 5/10/2018, this flare is non-assisted. As such, the requirements §60.18(c)(5) and (f)(6) are not applicable to the flare at the Greeley Natural Gas Processing Plant, and were therefore not included in the operating permit. Condition 19.f: Flares used to comply with this section shall be steam-assisted, air- assisted, or nonassisted (§60.18(c)(6)). • Per source correspondence received 5/10/2018, the flare at the Greeley Natural Gas Processing Plant is non-assisted. As such, this flare is regulated under this subpart. Because this requirement does not include any type of periodic monitoring and was intended for applicability and design purposes, this requirement was not included in the operating permit. 123/0099 Page 28 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Condition 19.q: Owners or operators of flares used to comply with the provisions of this subpart shall monitor these control devices to ensure that they are operated and maintained in conformance with their designs. Applicable subparts will provide provisions stating how owners or operators of flares shall monitor these control device (§60.18(d)). Condition 19.h: Flares used to comply with provisions of this subpart shall be operated at all times when emissions may be vented to them (§60.18(e)). Condition 19.i: Method 22 of appendix A to this part shall be used to determine the compliance of flares with the visible emission provisions of this subpart. The observation period is 2 hours and shall be used according to Method 22 (§60.18(f)(1)). Condition 19.i: The presence of a flare pilot flame shall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame (§60.18(f)(2)). Condition 19.k: The net heating value of the gas being combusted in a flare shall be calculated using the following equation (§60.18(f)(3)). Condition 19.1: The actual exit velocity of a flare shall be determined by dividing the volumetric flowrate (in units of standard temperature and pressure), as determined by Reference Methods 2, 2A, 2C, or 2D as appropriate; by the unobstructed (free) cross sectional area of the flare tip (§60.18(f)(4)). Condition 19.m: The maximum permitted velocity, Vmax, for flares complying with paragraph (c)(4)(iii) shall be determined by the following equation (§60.18(f)(5)). • Per the 2017 inspection report, the maximum flare tip velocity is below the 18.3 m/s threshold. As such, the requirements of §60.18(c)(4)(iii) are not applicable. This requirement was therefore not included in the operating permit. Condition 19.n: The maximum permitted velocity, Vmax, for air-assisted flares shall be determined by the following equation (§60.18(f)(6)). • Per source correspondence received on 5/10/2018, this flare is non-assisted. As such, this requirement for air-assisted flares is not applicable and was therefore not included in the operating permit. Condition 20: Upon issuance of this permit, 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.). • All applicable requirements from the O&M plan for both the plant flare and ethylene glycol dehydration unit were incorporated into the operating permit. As such, this specific requirement was not included in the operating permit. 123/0099 Page 29 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Condition 21: Initial Testing Requirement for Point 111 — The owner or operator shall demonstrate compliance with opacity standards, using EPA Method 22 to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one (1) minute in any fifteen (15) minute period during normal operation. (Reference: Regulation No. 7, Section XVII.A.II). • This initial testing requirement was completed pursuant to the self-certification received by the Division on 11/16/2016. As such, this requirement was not included in the operating permit. It should be noted, however, that periodic opacity observations are required under Condition 26 of this construction permit (see below). • Note that Colorado Regulation No. 7 citations were significantly altered with the 2/14/2020 promulgation. The new citation for the requirements referenced in this condition is Part D, Section II.A.23. Condition 22: Initial Testing Requirement for Point 111 — The owner or operator shall complete the initial annual extended wet gas analysis testing required by this permit and submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. (Reference: Regulation No. 3, Part B, Section III.E.). • This initial testing requirement was completed pursuant to the self-certification received by the Division on 11/16/2016. As such, this requirement was not included in the operating permit. It should be noted, however, that annual extended analyses are required under Condition 25 of this construction permit (see below). Condition 23: Initial Testing Requirement for Point 122 — The operator shall complete an initial site specific extended gas analysis within one hundred and eighty days (180) after commencement of operation or issuance of this permit, whichever comes later, of the natural gas routed to this emissions unit in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane content (weight fraction) of this emission stream and using volume from the flare meter along with a 95% DRE to demonstrate compliance with emission limits. Results of testing shall be used to calculate site-specific emission factors for the pollutants referenced above (in units of TPY emission limit) using Division approved methods. Results of site-specific sampling and emissions factor analysis shall be submitted to the Division as part of the self-certification and demonstrate the emissions factors established through this initial testing are less than or equal to, the emissions factors established in the permit application and "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this sampling and analysis is greater than the emissions factors established in the permit application and "Notes to Permit Holder" the operator shall submit to the Division within 60 days, a request for permit modification to update emissions factors and emissions limits specified in this permit. • This initial testing requirement was completed pursuant to the self-certification received by the Division on 11/16/2016. As such, this requirement was not included in the operating permit. It should be noted, however, that annual 123/0099 Page 30 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit extended analyses are required under Condition 27 of this construction permit (see below). Condition 24: Initial Testing Requirement for Point 122 — The owner or operator shall demonstrate compliance with opacity standards using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section I I.A.5). • This initial testing requirement was completed pursuant to the self-certification received by the Division on 11/16/2016. As such, this requirement was not included in the operating permit. Condition 25: Periodic Testing Requirement for Point 111 —The owner or operator shall complete an extended wet gas analysis prior to the inlet of the EG dehydrator on an annual basis. Results of the wet gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per this permit and be provided to the Division upon request. Condition 26: Point 111 — The owner or operator shall demonstrate compliance with opacity standards, using EPA Method 22 to determine the presence or absence of visible emissions per the frequency required in the O&M Plan. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one (1) minute in any fifteen (15) minute period during normal operation. (Reference: Regulation No. 7, Section XVII.A.II). • This condition was modified to provide for Method 9 observations, should opacity be detected during the Method 22 observations, pursuant to Division standards. If opacity is observed via Method 22 readings, a Method 9 observation, completed by a trained observer, shall be completed to demonstrate compliance with the Colorado Regulation No. 1 opacity standards. For more detailed information on the opacity standards and monitoring included in the operating permit, refer to Section V below. • Note that Colorado Regulation No. 7 citations were significantly altered with the 2/14/2020 promulgation. The new citation for the requirements referenced in this condition is Part D, Section II.A.23. Condition 27: Periodic Testing Requirement for Point 122 — On an annual basis, the operator shall complete a site specific extended gas analysis of the natural gas routed to this emissions unit in order to verify the VOC content (weight fraction) of this emission stream and using volume from the flare meter along with a 95% DRE to demonstrate compliance with emission limits. Results of testing shall be used to calculate site- specific emission factors for the pollutants referenced above (in units of TPY permit limit) 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 123/0099 Page 31 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit 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. • In order to obtain the most accurate estimation of emissions possible, an emission factor approach was not utilized in the operating permit. Instead, the source is required to conduct annual sampling of the combined purge/waste gas sent to the flare. Emissions of VOC and any reportable HAP shall then be calculated utilizing the VOC or HAP content indicated by these samples. Condition 28: Revised APEN submittal requirements and deadlines • This condition is included in the General Conditions of Section IV in the operating permit, and was not included as a separate condition for this AIRS point in Section II of the operating permit. Condition 29: This source is subject to the provisions of Regulation No. 3, Part C, Operating Permits. The provisions of this construction permit must be incorporated into the Operating Permit. The application for the modification to the Operating Permit is due within one year of the issuance of this permit. • The permit modification submitted on 5/2/2016 requested the incorporation of this construction permit 15WE0939 into the operating permit. The Division considers this one-time requirement fulfilled, and it was therefore not included in the operating permit. Condition 30: 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. • This condition is a construction permit only requirements. As such, this condition was not included in the operating permit. Condition 31: 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. 123/0099 Page 32 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit • Final authorization of this construction permit was granted by the Division on 12/16/2016, fulfilling the requirements of this condition. As such, this condition was not included in the operating permit. Conditions 32 through 36: General Terms and Conditions — these requirements are included in the Section IV General Conditions of the operating permit and/or the Colorado Revised Statutes. As such, separate conditions for these requirements were not created for the operating permit. V. NEW EMISSION SOURCES A. P-130 — Ethylene Glycol Dehydration Unit, AIRS ID: 111 1. Applicable Requirements This operating permit condition addresses the ethylene glycol dehydration unit, which was originally permitted under the previous 5/1/2009 issuance of the operating permit and subsequently amended under Colorado Construction Permit 15WE0939. All new and amended requirements, as required by 15WE0939, have been incorporated into the operating permit pursuant to the significant modification request received on 5/2/2016. The applicable requirements for the ethylene glycol dehydration unit are as follows: • VOC Emission Limitations & Compliance Monitoring o Emissions of VOC shall not exceed 0.2 tons/year. A twelve month rolling total shall be established and maintained to monitor compliance with the annual limitation (Colorado Construction Permit 15WE0939). o The inlet wet gas composition obtained from the most recent extended analysis, the average daily wet gas throughput, the average monthly values of the lean glycol circulation rate,, the unit inlet temperature and pressure, flash tank temperature and pressure and cold separator temperature and pressure shall be input into the monthly GLYCaIc model run to estimate emissions (Colorado Construction Permit 15WE0939 and Dehydration Unit O&M Plan). o A control efficiency of 95% shall apply to the ECD provided the control device requirements related to the ECD are met, as well as the general requirements of Colorado Regulation No. 7, Part D, Sections I and II are met (Colorado Construction Permit 15WE0939 and Colorado Regulation No. 3, Part C, Section V.C.5.b.). ■ The emissions determined in Colorado Construction Permit 15WE0939 were based on a 95% destruction efficiency. Although this was not an explicit requirement within the construction permit, the operating permit allows the usage of this control efficiency, provided the control device requirements and general Colorado Regulation No. 7 requirements are met. 123/0099 Page 33 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit ■ It should be noted that for the vapor recovery unit, a control efficiency of 100% is assumed, provided the unit is operating. As such, an emission calculation for the flash gas during periods of VRU operation was not included in the calculation methodologies, since these emissions are effectively 0 tons/year. o Hours of VRU downtime shall be used to determine the periods of time during which the VRU is routed to the enclosed combustion device and a control efficiency of 95% for the ECD is applicable to flash gas emissions (Colorado Construction Permit 15WE0939 and Colorado Regulation No. 3, Part C, Section V.C.5.b.). ■ Pursuant to Colorado Construction Permit 15WE0939, the vapor recovery unit is allowed a maximum of 5% downtime, during which emissions are routed to the enclosed combustion device. In order to monitor compliance with the VOC emission limitation for this dehydration unit, hours during which the vapor recovery unit was down and emissions were routed to the enclosed combustion device must be monitored. These hours of operation are also utilized to monitor compliance with the maximum allowable 5% downtime limitation. o Total hours of operation of the dehydration unit and the total hours of ECD downtime shall be used to determine the periods of time during which the ECD is operating and a control efficiency of 95% applies to the still vent emissions (Colorado Regulation No. 3, Part C, Section V.C.5.b.). • Pursuant to Colorado Construction Permit 15WE0939, the enclosed combustion device is allowed a maximum of 5% downtime, during which emissions are routed to atmosphere. In order to monitor compliance with the VOC emission limitation for this dehydration unit, hours during which the enclosed combustion device was down and emissions were routed to atmosphere must be monitored. These hours of operation are also utilized to monitor compliance with the maximum allowable 5% downtime limitation. o Hours of ECD downtime shall be used to determine periods of time during with the ECD is not operating and still vent emissions are routed to atmosphere, during which still vent emissions are uncontrolled and a control efficiency of 0% applies (Colorado Regulation No. 3, Part C, Section V.C.5.b.). • Pursuant to Colorado Construction Permit 15WE0939, the enclosed combustion device is allowed a maximum of 5% downtime, during which emissions are routed to atmosphere. In order to monitor compliance with the VOC emission limitation for this dehydration unit, hours during which the enclosed combustion device was down and emissions were routed to atmosphere must 123/0099 Page 34 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit be monitored. These hours of operation are also utilized to monitor compliance with the maximum allowable 5% downtime limitation. o Hours of concurrent downtime shall be used to determine periods of time when both the ECD and VRU are experiencing downtime and emissions from the flash tank (along with the still vent) are routed to atmosphere, during which flash tank emissions are uncontrolled and a control efficiency of 0% applies (Colorado Construction Permit 15WE0939 and Colorado Regulation No. 3, Part C, Section V.C.5.b.). o Total VOC emissions shall be the sum of the VOC contributions from the flash gas plus still vent emissions for each month. Monthly VOC emissions shall be used in a twelve month rolling total to monitor compliance with the VOC limitations (Colorado Construction Permit 15WE0939 and Colorado Regulation No. 3, Part C, Section V.C.5.b.). o Facility-wide emissions of HAP shall not exceed the synthetic minor limitations of 8 tons/year individual HAP and/or 20 tons/year total HAP. With the significant modification received 4/27/2020, the Greeley Natural Gas Processing Plant is now considered to be a synthetic minor source of HAP and requires limitations to ensure the facility retains its area source status under the 40 CFR Part 63 MACT rules. Because these HAP limitations apply on a facility-wide basis, the limits were included in a separate condition within the operating permit and a reference to that Condition 11 was included in this dehydration unit condition. ■ Note that the HAP calculation for the dehydration unit is nearly identical to the VOC calculation methodology set forth in this dehydration unit condition, but instead of the VOC emissions obtained from GLYCaIc for the flash gas and still vent streams, HAP emissions obtained from GLYCaIc for these streams should be used. • Wet Gas Throughput Limitations & Compliance Monitoring o The total amount of wet gas throughput to the dehydration unit shall not exceed 12,045 MMSCF/yr. The throughput shall be monitored using the plant inlet flowmeter. A twelve month rolling total shall be established and maintained to monitor compliance with the annual limitation. Records shall be maintained and made available to the Division upon request (Colorado Construction Permit 15WE0939). The average daily gas throughput shall be determined using the monthly wet gas throughput and the total hours of dehydration unit hours of operation. This value is required as an input to the monthly GLYCaIc model run. o The amount of wet gas throughput to the dehydration unit during periods of VRU downtime shall not exceed 5% of the total gas throughput to the dehydration unit on a rolling twelve month basis (Colorado Construction Permit 15WE0939 and Colorado Regulation No. 3, Part C, Section V.C.5.b.). 123/0099 Page 35 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit ■ Colorado Construction Permit 15WE0939 requires that the VRU control flash tank emissions to 95%, and is allowed 5% annual downtime. In order to monitor compliance with this requirement, the actual percentage of VRU downtime shall be calculated as a function of the total wet gas throughput to the dehydration unit and the amount of time the VRU experienced downtime. The total wet gas throughput to the dehydration unit during VRU downtime is not to exceed 5% of the total wet gas throughput to the dehydration unit on a rolling twelve month basis. The limitation listed in the permit is based on a percentage of actual wet gas throughput. This was done pursuant to the justification presented in the "NOTES" section of this dehydration unit condition below. o The amount of wet gas throughput to the dehydration unit during periods of ECD downtime shall not exceed 5% of the total gas throughput to the dehydration unit on a rolling twelve month basis (Colorado Construction Permit 15WE0939 and Colorado Regulation No. 3, Part C, Section V.C.5.b.). ■ Colorado Construction Permit 15WE0939 requires that the ECD control still vent emissions to 95%, and is allowed 5% annual downtime. In order to monitor compliance with this requirement, the actual percentage of ECD downtime shall be calculated as a function of the total wet gas throughput to the dehydration unit and the amount of time the ECD experienced downtime. The total wet gas throughput to the dehydration unit during ECD downtime is not to exceed 5% of the total wet gas throughput to the dehydration unit on a rolling twelve month basis. The limitation listed in the permit is based on a percentage of actual wet gas throughput. This was done pursuant to the justification presented in the "NOTES" section of this dehydration unit condition below. • Lean Glycol Circulation Rate Limitations & Compliance Monitoring o The lean glycol circulation rate shall not exceed 6 gpm. The circulation rate shall be monitored daily and records shall be made available to the Division upon request (Colorado Construction Permit 15WE0939 and O&M Plan). o A monthly average of the daily recorded values shall be used in the monthly GLYCaIc model run (Colorado Construction Permit 15WE0939). • Extended Gas Analysis o An extended gas analysis of the inlet gas to the dehydration unit shall be performed annually. Results of the extended analysis shall be maintained and made available to the Division upon request (Colorado Construction Permit 15WE0939). • Parametric Monitoring 123/0099 Page 36 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit o The inlet wet gas temperature and pressure, the cold separator temperature and pressure, and the flash tank temperature and pressure shall be monitored weekly and recorded in a log to be made available to the Division upon request (Colorado Construction Permit 15WE0939 and O&M Plan). ■ It should be noted that monitoring of the flash tank operating pressure and temperature were not required by the O&M Plan or 15WE0939. However, monitoring of these parameters is being included in the operating permit since flash tank emissions are directly correlated to the pressure and temperature at which the flash tank operates. Additionally, these parameters are required inputs into the GLYCaIc model. To ensure an accurate representation of emissions generated, the parameters entered into the GLYCalc model should be based on actual operating data. Therefore, the flash tank temperature and pressure will be monitored on the same frequency as the other parameters required by the O&M Plan. o Monthly averages of the weekly recorded values shall be used in the monthly GLYCaIc model run (Colorado Construction Permit 15WE0939). • Hours of Operation o Total hours of operation for the dehydration unit shall be monitored and recorded monthly in a log to be made available to the Division upon request. Total hours of operation shall be used to determine the average daily gas throughput, as well as still vent emissions (Colorado Regulation No. 3, Part C, Section V.C.5.b.). • Total hours of dehydration unit operation are required to be tracked in order to monitor compliance with the VOC emission limitation. This value, used in conjunction with the downtime hours of the ECD shall determine the period of time over which still vent emissions were controlled with the ECD, for the purposes of calculating emissions. o Hours of VRU downtime shall be monitored and recorded monthly in a log to be made available to the Division upon request. Hours of VRU downtime are defined as periods of time when the VRU is not operating and emissions from the dehydration unit flash tank are routed to the enclosed combustion device (Colorado Regulation No. 3, Part C, Section V.C.5.b.). • Pursuant to Colorado Construction Permit 15WE0939, the vapor recovery unit is allowed a maximum of 5% downtime, during which emissions are routed to the enclosed combustion device. In order to monitor compliance with the VOC emission limitation for this dehydration unit, hours during which the vapor recovery unit was down and emissions were routed to the enclosed combustion 123/0099 Page 37 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit device must be monitored. These hours of operation are also utilized to monitor compliance with the maximum allowable 5% downtime limitation. o Hours of ECD downtime shall be monitored and recorded monthly in a log to be made available to the Division upon request. Hours of ECD downtime are defined as periods of time when the enclosed combustion device is not operating and emissions from the dehydration unit still vent are routed to atmosphere (Colorado Regulation No. 3, Part C, Section V.C.5.b.). ■ Pursuant to Colorado Construction Permit 15WE0939, the enclosed combustion device is allowed a maximum of 5% downtime, during which emissions are routed to atmosphere. In order to monitor compliance with the VOC emission limitation for this dehydration unit, hours during which the enclosed combustion device was down and emissions were routed to atmosphere must be monitored. These hours of operation are also utilized to monitor compliance with the maximum allowable 5% downtime limitation. o Hours of concurrent downtime, when both the VRU and ECD are experiencing downtime, shall be determined monthly using the records required for monitoring VRU and ECD downtime (above). During these periods, flash tank emissions are routed to atmosphere, along with the still vent emissions (Colorado Regulation No. 3, Part C, Section V.C.5.b.). ■ Pursuant to Colorado Construction Permit 15WE0939, the enclosed combustion device and vapor recovery unit are allowed a maximum of 5% downtime, during which emissions are routed to atmosphere. It is possible that these permitted downtime periods could overlap, resulting in flash tank emissions being routed to atmosphere. In order to monitor compliance with the VOC emission limitation for this dehydration unit, hours during which both the ECD and VRU experience downtime simultaneously and flash tank emissions were routed to atmosphere must be monitored. • Opacity o 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 (Colorado Regulation No. 1, Section II.A.5). • Control Device Requirements It should be noted that a control efficiency from a condenser was not claimed for the purposes of emission calculation from this dehydration unit. As such, no monitoring associated with condensers was included in the operating permit. 123/0099 Page 38 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit o VRU Requirements • The VRU shall be operated at all times when emissions are routed to it (Colorado Regulation No. 3, Part C, Section V.C.5.b.). • Pursuant to Colorado Construction Permit 15WE0939, flash tank emissions must be 95% controlled by the VRU. To ensure adequate control, this requirement was added to the operating permit. • Daily visual inspections of the valves routing the dehydration unit flash tank emissions to the VRU are open. Results of the inspection shall be maintained and made available to the Division upon request (Colorado Regulation No. 3, Part C, Section V.C.5.b.). • Pursuant to Colorado Construction Permit 15WE0939, flash tank emissions must be 95% controlled by the VRU. Because the flash tank emissions may be routed to the VRU or, during periods of VRU downtime, to the ECD, it is necessary to ensure a proper valving configuration to achieve the required destruction of emissions. As such, this requirement was added to the operating permit. o ECD Requirements • The ECD shall be operated at all times when emissions are routed to it (Colorado Regulation No. 3, Part C, Section V.C.5.b.). • Pursuant to Colorado Construction Permit 15WE0939, still vent emissions must be 95% controlled by the ECD. To ensure adequate control, this requirement was added to the operating permit. • Daily visual inspections of the valves routing the dehydration unit still vent emissions (and, if the VRU is experiencing downtime, the flash gas emissions)to the ECD are open. Results of the inspection shall be maintained and made available to the Division upon request (Colorado Regulation No. 3, Part C, Section V.C.5.b.). • Pursuant to Colorado Construction Permit 15WE0939, still vent emissions must be 95% controlled by the ECD. Because the still vent and flash tank emissions may be routed to the ECD or, during periods of ECD downtime, to atmosphere, it is necessary to ensure a proper valving configuration to achieve the required destruction of emissions. As such, this requirement was added to the operating permit. • The ECD shall be operated with the pilot present at all times. A flame detector shall continuously monitor the presence of the pilot light. If the presence of a flame cannot be detected, an auto-igniter 123/0099 Page 39 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit shall automatically re-light the pilot. The pilot light shall be monitored as follows (Dehydration Unit O&M Plan, as referenced in Colorado Construction Permit 15WE0939): • Visual inspection of the pilot light shall be completed daily to verify pilot light presence. A daily log with the results from the visual inspection shall be maintained and made available to the Division upon request. • Records of pilot light outage events and the duration of such events shall be maintained and made available to the Division upon request. ■ EPA Method 22 observations shall be conducted daily to determine whether visible emissions are present for a period of at least one (1) minute in any fifteen (15) minute period of normal operation. The results of the daily visual observations shall be kept on file and made available to the Division upon request (Dehydration Unit O&M Plan, as referenced in Colorado Construction Permit 15WE0939). o Added monitoring requirement to conduct Method 9 observations in the event visual emissions are detected via Method 22. The Method 9 observations were included as a way to demonstrate compliance with the Colorado Regulation No. 1 Section II.A.5 opacity standards. EPA Method 9 observations shall be conducted by a certified observer. If an opacity exceedance is observed, it shall be considered to exist until another Method 9 reading is taken which demonstrates compliance with the opacity standards of Colorado Regulation No. 1, Section II.A.5. • Alternative Operating Scenario (AOS) In source comments received 5/22/2020, it was requested that an alternative operating scenario (AOS) be included in the operating permit to allow for the replacement of the glycol circulation pumps during the permit term without the requirement to apply for a permit application. Note that since the issuance of 15WE0939, this AOS allowance has become standard practice for newly issued construction permits. The AOS requirements were incorporated as follows: o Replacement pumps must operate at the same or lower glycol circulation rate as permitted. o A log must be maintained to identify the start and stop dates, manufacturer, model number, serial number and capacity of replacement pumps. • Statewide Controls for Oil and Gas Operations o Colorado Regulation No. 7, Part D, Section I.C. 123/0099 Page 40 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit The dehydration unit and associated air pollution control equipment at the Greeley Natural Gas Processing Plant is subject to the following general requirements of Colorado Regulation No. 7, Part D, Section I.C.: • Section I.C.1.a. — The facility and air pollution control equipment shall be operated pursuant to good engineering and maintenance practices, and all control equipment shall be appropriately sized to accommodate reasonably foreseeable fluctuations in unit operation. • Section I.C.1.b. — All hydrocarbon liquids and produced water handling operations shall be designed and maintained to minimize VOC emissions. It should be noted that all general facility requirements were grouped into a separate condition within the operating permit. The ethylene glycol dehydration unit condition references these applicable requirements, which are located in Condition 12 of the operating permit. o Colorado Regulation No. 7, Part D, Section I.H. The dehydration unit and associated air pollution control equipment at the Greeley Natural Gas Processing Plant is subject to the following dehydration unit requirements of Colorado Regulation No. 7, Part D, Section I.H.: • Section I.H.1. — Dehydration units shall reduce uncontrolled actual emissions of VOC by at least 90% using air pollution control equipment • This condition was supplemented with a compliance demonstration method. A 90% reduction in VOC shall be assumed, provided the source is in compliance with the general requirements of Section I.C and the specific control device requirements required by the dehydration unit O&M Plan. • It should be noted that although natural gas processing plants are not explicitly listed in this condition as facilities subject to these control requirements, Section I.G. requires dehydration units located at natural gas processing plants to comply with the dehydration unit requirements of Section I.H. • Section I.H.3. — The 90% reduction in VOC applies where actual uncontrolled emissions of a single dehydration unit are in excess of 1 ton/year, or where a group of dehydration units produce actual uncontrolled emissions in excess of 15 tons/year. • Section I.H.4. — Emissions from any dehydration unit vent shall be calculated by methods approved in advance by the Division. 123/0099 Page 41 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit • This requirement was supplemented with additional monitoring to provide a timeline of compliance, should the dehydration unit's actual uncontrolled emissions drop below the applicability threshold of Section I.H.3. In the event the source drops below this applicability threshold and then subsequently exceeds it, the source shall have 60 days to comply with the applicable Section I.H. requirements. • Section I.H.5. — Inspections of all air pollution control equipment shall be conducted weekly and records shall be kept that note the date of inspection, a description of problems found and a summary of any corrective action taken. Weekly monitoring of the pilot light and valve alignment for the pilot gas is required. Records shall be kept documenting any air pollution control device maintenance. • Section I.H.6. — The operator shall submit semi-annual reports including a list of dehydration units subject to I.H., associated air pollution control equipment, and any dates on which inspections indicated that the control devices were not operating properly. o Colorado Regulation No. 7, Part D, Section II.B. The dehydration unit and associated air pollution control equipment at the Greeley Natural Gas Processing Plant is subject to the following general requirements of Colorado Regulation No. 7, Part D, Section II.B.: • Section II.B.1.a. (State-Only Enforceable) — All hydrocarbon liquids and produced water handling operations shall be designed to minimize emissions of VOC and other hydrocarbons. • Section II.B.1.b. (State-Only Enforceable) — The facility and air pollution control equipment shall be operated at all times using good air pollution control practices. • Section II.B.2.a. (State-Only Enforceable) — Air pollution control equipment used to comply with Section II shall be operated pursuant to good engineering and maintenance practices, and all control equipment shall be appropriately sized to accommodate reasonably foreseeable fluctuations in unit operation. • Section II.B.2.b. (State-Only Enforceable) — Combustion devices shall be enclosed, have no visible emissions and be designed so that an observer can conveniently determine whether or not the equipment is operating appropriately. • Section II.B.2.d. (State-Only Enforceable) — Combustion devices shall be equipped with an auto-igniter. It should be noted that all general facility requirements were grouped into a separate condition within the operating permit. The ethylene glycol 123/0099 Page 42 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit dehydration unit condition references the applicable requirements, which are located in Condition 12 of the operating permit. o Colorado Regulation No. 7, Part D, Section II.D. The dehydration unit and associated air pollution control equipment at the Greeley Natural Gas Processing Plant is subject to the following dehydration unit requirements of Colorado Regulation No. 7, Part D, Section II.D.: ■ Section II.D.1. (State-Only Enforceable) — Uncontrolled actual emissions of VOC shall be reduced by at least 90% using air pollution control equipment. • This condition was supplemented with a compliance demonstration method. A 90% reduction in VOC shall be assumed, provided the source is in compliance with the general requirements of Section II.B. and the specific control device requirements required by the dehydration unit O&M Plan. • Section II.D.2. (State-Only Enforceable) — The 90% reduction in VOC applies where actual uncontrolled emissions of a single dehydration unit are in excess of 2 tons/year, or where a group of dehydration units produce actual uncontrolled emissions in excess of 15 tons/year. • Section II.D.3. (State-Only Enforceable) — Uncontrolled actual emissions of hydrocarbon shall be reduced by at least 95%. If a combustion device is used it shall have a design destruction efficiency of 98%, unless it was permitted prior to 5/1/2014 or the facility is not located within 1,320 feet of a building unit or designated outdoor activity area. • This condition was supplemented with a compliance demonstration method. A 95% reduction in hydrocarbon shall be assumed, provided the source is in compliance with the general requirements of Section II.B. and the specific control device requirements required by the dehydration unit O&M Plan. Compliance with the destruction efficiency requirements for the combustion device shall be presumed, provided records are kept of the design destruction efficiency and proximity of the closest building/outdoor activity area are kept. • Section II.D.4. (State-Only Enforceable) — The 95% reduction in hydrocarbon applies where actual uncontrolled emissions of a single dehydration unit constructed before 5/1/2015 are in excess of 6 tons/year, or, if the dehydration unit is located within 1,320 feet 123/0099 Page 43 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit of a building unit or outside activity area, actual uncontrolled emissions of that dehydration unit are in excess of 2 tons/year. ■ The following additional monitoring requirements were included in the operating permit to ensure compliance with the Colorado Regulation No. 7, Part D, Section II.D requirements: • Requirement to maintain a rolling 12 month calculation of total emissions for the dehydration unit to determine whether the control requirements of Section II.D.1., and/or II.D.3. apply. • Requirement to comply with Section II.D within 60 days for instances in which the dehydration unit had actual uncontrolled emissions below the thresholds set forth in Section II.D.2. and II.D.4., and then subsequently exceeds these thresholds. • Requirement to. maintain records of whether or not the facility is located within 1,320 feet of a building unit or outdoor activity area. • Requirement to maintain records of the design destruction efficiency of the combustion device. NOTES: Please note the following in regards to the permit modification application received 5/2/2016: • Suggested conditions submitted on the 2000-604 forms were derived from Colorado Construction Permit 15WE0939. All requested conditions were incorporated EXCEPT for those highlighted in Section IV of this document above. • This dehydration unit is permitted to operate with 5% VRU downtime, during which emissions from the flash tank are routed to the ECD. This dehydration unit is also permitted to operate with 5% ECD downtime, during which still vent emissions from the dehydration unit (and, if the VRU is down concurrently, flash gas emissions) are routed to atmosphere. The intent of downtime is to allow for periods of VRU and ECD maintenance in response to malfunctions, during which the dehydration unit emissions cannot be safely or practicably routed to the VRU or destructed by the ECD, and are therefore routed to atmosphere. It has been determined that downtime should be permitted as a function of actual operating time, not as a hard numerical limitation based on the maximum number of operational hours and/or maximum throughput. Numerical limits on hours, throughput or VOC emissions would necessarily be based on maximum operating parameters, or 5% of 8,760 hours of operation and/or 5% of the maximum wet gas throughput. Permitting based on maximum operational parameters would result in hard numerical limitations that would seemingly allow the source to process that numerical amount wet gas, discharge that numerical amount of pollutant or vent emissions to atmosphere for that numerical quantity of hours, regardless of actual hours of operation. Therefore, operating over a shortened timeframe and/or operating at 123/0099 Page 44 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit less than maximum capacity could result in actual downtime in excess of the allowable 5% (i.e., an hours limitation on downtime of 438 hours, or 5% of a maximum 8,760 hours of operation, would theoretically permit the source to route still vent (or flash gas) emissions to atmosphere for 438 hours, even if the source only operates for 438 hours per year, effectively equating to 100% downtime). A permit limitation of this type would allow the source to operate in direct violation of the hydrocarbon and VOC emission reduction requirements of Colorado Regulation No. 7, Part D, Section I.H. and II.D. for dehydration units. To ensure operating permit limitations do not contradict the requirements of these state regulations and generate a non-compliance situation for the source, the emission limitation for downtime was not based on maximum hours of operation and maximum wet gas throughput to the dehydration unit. Instead, the limitation was based on a percentage of actual operating parameters, which allows for a prorated amount of downtime based on actual hours of operation and actual wet gas throughput to each dehydration unit. The applicable downtime limitation was incorporated into the operating permit as a wet gas throughput limitation. Wet gas throughput to the dehydration unit during periods of VRU downtime (defined as periods of time during which flash gas emissions are routed to the ECD) and ECD downtime (defined as periods of time when still vent emissions from the dehydration unit are routed to atmosphere) shall not exceed 5% of the total wet gas throughput to the dehydration unit on a rolling twelve month basis. 2. Emission Factors Emission factors for this unit were established as follows: • VOC & HAP —A specific emission factor was not developed for VOC or HAP emissions. Instead, the GLYCaIc process model shall be used to determine the flowrate of VOC and HAP components from the flash tank and still vent, using the most recent wet gas analysis, average daily wet gas throughput, and average monthly values for inlet wet gas pressure and temperature, the cold separator operating temperature and pressure, the flash tank operating temperature and pressure and the lean glycol circulation rate as inputs to the process model. The uncontrolled and controlled hours of operation shall be used to determine the appropriate control efficiency to apply to the still vent emissions obtained from the model. A control efficiency of 100% applies to the flash gas emissions when the VRU is operating. A control efficiency of 95% shall apply when the ECD is being used to destruct still vent emissions (and, if the VRU is experiencing downtime, flash gas emissions) A control efficiency of 0% shall apply during periods of ECD downtime when still vent emissions (and, if the VRU is concurrently experiencing downtime, flash gas emissions) are routed to atmosphere. 3. Monitoring Plan The following parameters shall be monitored at the prescribed frequency to ensure compliance with the annual limitations set forth in the permit: 123/0099 Page 45 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit • Total Wet Gas Throughput — The amount of wet gas processed by this dehydration unit is monitored monthly using existing meter at the facility inlet. The monthly throughput is converted to a daily average and used as an input to the GLYCaIc model to determine compliance with VOC and throughput limitations. • Wet Gas Throughput During VRU Downtime—The amount of wet gas processed by this dehydration unit during periods of VRU downtime is monitored monthly using the VRU downtime hours in conjunction with the inlet gas throughput to the dehydration unit, as metered at the unit inlet. Wet gas throughput during VRU downtime is defined as periods during which the VRU was experiencing downtime and flash gas emissions were routed to the ECD. It should be noted that the downtime limitation of 5% of the total wet gas throughput applies to the total wet gas throughput flowrate, NOT to the flash gas flowrate. • Wet Gas Throughput During ECD Downtime—The amount of wet gas processed by this dehydration unit during periods of ECD downtime is monitored monthly using the ECD downtime hours in conjunction with the inlet gas throughput to the dehydration unit, as metered at the unit inlet. Wet gas throughput during ECD downtime is defined as periods where the ECD was experiencing downtime and still vent emissions (and, if the VRU was simultaneously experiencing downtime, flash gas emissions) were routed to atmosphere. It should be noted that the downtime limitation of 5% of the total wet gas throughput applies to the total wet gas throughput flowrate, NOT the still vent flowrate. • Lean Glycol Circulation Rate — Monitored daily and used as an input to the GLYCaIc process model to determine compliance with VOC emission limitations, as well as the glycol throughput limitation. The glycol pump outlet is equipped with a flowmeter to directly measure the circulation rate. • Extended Gas Analysis - Performed annually to be used as an input to the GLYCaIc model to determine compliance with VOC emission limitations. The analysis should identify the VOC components present in the wet gas. • Parametric Monitoring — Process parameters including inlet wet gas temperature and pressure, cold separator temperature and pressure and flash tank temperature and pressure are monitored and averaged on a monthly basis to serve as inputs to the GLYCaIc process model. • Total Hours of Operation — Monitored and recorded monthly; used to determine the duration of time for which the ECD was operating and a destruction efficiency of 95% may be applied to the still vent (and, if applicable, flash gas) emissions. • VRU Downtime — Monitored and recorded monthly; used to determine the amount of time during which flash gas emissions are routed to the ECD and the 95% destruction efficiency of the ECD applies to flash gas emissions. • ECD Downtime — Monitored and recorded monthly; used to determine the amount of time during which the still vent emissions are routed to atmosphere, during which emissions are uncontrolled. 123/0099 Page 46 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit • Concurrent Downtime — Calculated from the VRU and ECD downtime monitoring; used to determine period during which flash gas is routed to atmosphere when both the VRU and ECD are experiencing downtime. • VRU Valve Configuration Inspection — Daily inspection of the valves routing the flash gas emissions from the dehydration unit to the VRU to ensure emission destruction. • ECD Valve Configuration Inspection — Daily inspection of the valves routing the still vent (and, if applicable, flash gas) emissions from the dehydration unit to the ECD to ensure emission destruction. • Pilot Light— Presence verified via daily visual inspection. • Opacity— Method 22 observations required daily to ensure visible emissions are not present at the flare. In the event visual emissions are observed, a Method 9 reading shall be performed by a certified observer to determine compliance with the Colorado Regulation No. 1 Section II.A.5 opacity requirements. 4. Compliance Status Pursuant to the 2017 inspection report, the ethylene glycol dehydration unit is in compliance with all applicable requirements in Colorado Construction Permit 15WE0939 and a separate compliance schedule/plan is not needed. B. FLARE — Plant Flare, AIRS ID: 122 1. Applicable Requirements This operating permit condition addresses the plant flare, which was first permitted under Colorado Construction Permit 15WE0939. This point has been incorporated into the operating permit pursuant to the significant modification request received on 5/2/2016. The applicable requirements for the plant flare are as follows: • VOC Emission Limitations & Compliance Monitoring o Emissions of VOC shall not exceed 19.8 tons/year. A twelve month rolling total shall be established and maintained to monitor compliance with the annual limitation (Colorado Construction Permit 15WE0939). o Emissions of VOC resulting from pilot gas combustion shall be determined via calculation using the monthly pilot gas flowrate and the AP-42 Chapter 1.4 Natural Gas Combustion (dated 7/1998) emission factors. ■ It should be noted that the pilot gas monitoring was not explicitly included in Colorado Construction Permit 15WE0939. However, the contribution of the pilot gas was incorporated into the VOC emission limitation set forth in that permit for the plant flare. Therefore, the appropriate methodology to calculate the emissions contributed from the pilot gas was included in the operating permit. 123/0099 Page 47 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit o Emissions of VOC resulting from purge and waste gas combustion shall be determined via calculation using the monthly purge and waste gas flowrates, molecular weights, VOC content (mass fraction) and an assumed control efficiency of 95%. ■ It should be noted that the purge gas monitoring was not explicitly included in Colorado Construction Permit 15WE0939. However, the contribution of the purge gas was incorporated into the VOC emission limitation set forth in that permit for the plant flare. Therefore, the appropriate methodology to calculate the emissions contributed from the purge gas was included in the operating permit. o Total VOC emissions shall be the sum of the contributions from the pilot, purge and waste gases. Monthly VOC emissions shall be used in a twelve month rolling total to monitor compliance with the VOC limitations (Colorado Construction Permit 15WE0939; modified to explicitly include pilot and purge gas contributions). o Facility-wide emissions of HAP shall not exceed the synthetic minor limitations of 8 tons/year individual HAP and/or 20 tons/year total HAP. With the significant modification received 4/27/2020, the Greeley Natural Gas Processing Plant is now considered to be a synthetic minor source of HAP and requires limitations to ensure the facility retains its area source status under the 40 CFR Part 63 MACT rules. Because these HAP limitations apply on a facility-wide basis, the limits were included in a separate condition within the operating permit and a reference to that Condition 11 was included in this plant flare condition. ■ Note that the HAP calculation for the plant flare purge and waste gas is nearly identical to the VOC calculation methodology set forth in this plant flare condition, but instead of the VOC content obtained from the most recent extended gas analysis, the HAP content obtained from this analysis should be used. For the pilot gas, HAP emissions are calculated using the monthly pilot gas flowrate and the AP-42 Chapter 1.4 Natural Gas Combustion emission factors set forth in Table 1.4-3 (dated 7/1998). • NOx & CO Emission Limitations & Compliance Monitoring o Emissions of NOx shall not exceed 2.6 tons/year. Emissions of CO shall not exceed 11.4 tons/year. A twelve month rolling total shall be established and maintained to monitor compliance with the annual limitations (Colorado Construction Permit 15WE0939). o Emissions of NOx and CO resulting from pilot gas combustion shall be determined via calculation using the monthly pilot gas flowrate and the AP-42 Chapter 1.4 Natural Gas Combustion (dated 7/1998) emission factors. 123/0099 Page 48 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit ■ It should be noted that the pilot gas monitoring was not explicitly included in Colorado Construction Permit 15WE0939. However, the contribution of the pilot gas was incorporated into the NOx and CO emission limitations set forth in that permit for the plant flare. Therefore, the appropriate methodology to calculate the emissions contributed from the pilot gas was included in the operating permit. o Emissions of NOx and CO resulting from purge and waste gas combustion shall be determined via calculation using the monthly purge and waste gas flowrates, heat content and the AP-42 Chapter 13.5 Industrial Flares (dated 2/2018) emission factors (Colorado Construction Permit 15WE0939; modified to explicitly include pilot and purge gas contributions). ■ It should be noted that the purge gas monitoring was not explicitly included in Colorado Construction Permit 15WE0939. However, the contribution of the purge gas was incorporated into the NOx and CO emission limitations set forth in that permit for the plant flare. Therefore, the appropriate methodology to calculate the emissions contributed from the purge gas was included in the operating permit. o Total NOx and CO emissions shall be the sum of the contributions from the pilot, purge and waste gases. Monthly NOx and CO emissions shall be used in a 12 month rolling total to monitor compliance with the NOx and CO limitations (Colorado Construction Permit 15WE0939; modified to explicitly include pilot and purge gas contributions). • Flare Gas Throughput Limitations & Compliance Monitoring o The amount of each gas stream sent to the plant flare shall not exceed the following limitations (Colorado Construction Permit 15WE0939 and Plant Flare O&M Plan; modified to explicitly include pilot and purge gas contributions): • Pilot Gas: 0.88 MMSCF/yr • Purge/Waste Gas: 56.09 MMSCF/yr It should be noted that the pilot and purge flowrate limitations were not listed in Colorado Construction Permit 15WE0939. However, the emissions contributions from both the pilot and purge gases were included in the NOx, CO and VOC limitations, and the pilot gas flowrate was listed on the plant flare APEN received on 12/15/2015. As such, it is appropriate that the flowrates from each of these contributions be monitored in order to calculate the monthly emissions from each contributing source of emissions routed to the flare. o The flowrate of the pilot gas stream shall be considered to be constant at 100 SCFH. Monthly pilot gas throughput shall be calculated by multiplying 123/0099 Page 49 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit this hourly throughput by the flare hours of operation and used in a twelve month rolling total to monitor compliance with the throughput limitations (Colorado Construction Permit 15WE0939; modified to explicitly include pilot gas contributions). ■ Pursuant to source correspondence received 11/28/2018, the pilot gas is not metered. As such, the manufacturer's specification value for hourly pilot throughput may be assumed. ■ In the source comments received 5/22/2020, it was indicated that the correct pilot light flowrate is 100 SCFH. As such, this value, instead of the 150 SCFH value used in the issuance of 15WE0939, was incorporated into the operating permit. o The flowrate of the purge and waste gas shall be monitored and recorded monthly using the flare header flowmeter. This monthly throughput shall be used in a twelve month rolling total to monitor compliance with the throughput limitations (Colorado Construction Permit 15WE0939; modified to explicitly include purge gas contributions). ■ Because the purge gas is combined with the waste gas at various points throughout the flare header system, the flare header flowmeter will read both the purge throughput and the waste gas throughput. In source comments received 5/22/2020, it was indicated that the purge gas is not separately metered. As such, the total metered flowrate of both the purge and waste gas combined will be compared to the annual limitation, which is based on the sum of the purge and waste gases. ■ For instances in which the flare meter is unable to read the flowrate to the flare, due to a flowrate lower than the detection limit of the meter, the lower detection limit of the meter shall be used as the flowrate during those periods of time. Because purge gas is always routed to the flare to prevent oxygen intrusion, a flowrate always exists in these headers. However, the required purge flowrate is relatively small, such that some flare header meters may not be able to detect the low purge flow. As such, the lower detection limit of the meter shall be used in these instances. o The monthly throughput of the pilot, purge and waste gases shall be used in a twelve month rolling total to monitor compliance with the throughput limitations (Colorado Construction Permit 15WE0939; modified to explicitly include pilot and purge gas contributions). • Extended Gas Analysis o An extended analysis of the combined purge/waste gas stream routed to the flare shall be completed annually to identify the relevant VOC and HAP constituents of the purge/waste gas. The waste gas sent to the flare is highly variable in composition, depending on plant operations and 123/0099 Page 50 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit maintenance. As such, the permit specifies that the composition utilized shall be representative of the purge/waste gas flared for each month. Engineering judgement shall be used to determine the appropriate composition of the waste gases routed to the flare, which shall be representative of the unit's actual operation (Colorado Construction Permit 15WE0939). • Hours of Operation o Monthly hours of flare operation shall be monitored and recorded in a log to monitor compliance with the annual pilot gas throughput limitation (Colorado Regulation No. 3, Part C, Section V.C.5.b.). ■ This condition was included in order to appropriately monitor the pilot gas contribution to flare emissions and pilot gas throughput limitation, as requested on the plant flare APEN received on 12/15/2015. • Opacity o 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 (Colorado Regulation No. 1, Section II.A.5). • Control Device Requirements o The plant flare shall be operated at all times when emissions are routed to it (Colorado Regulation No. 3, Part C, Section V.C.5.b.). o The flare shall be operated with the pilot present at all times. A flame detector shall continuously monitor the presence of the pilot light. If the presence of a flame cannot be detected, an auto-igniter shall automatically re-light the pilot. The pilot light shall be monitored as follows (Plant Flare O&M Plan, as referenced in Colorado Construction Permit 15WE0939): • Visual inspection of the pilot light shall be completed daily to verify pilot light presence. A daily log with the results from the visual inspection shall be maintained and made available to the Division upon request. • Records of pilot light outage events and the duration of such events shall be maintained and made available to the Division upon request. o EPA Method 22 observations shall be conducted daily to determine whether visible emissions are present for a period of at least one (1) minute in any fifteen (15) minute period of normal operation. The results of the daily visual observations shall be kept on file and made available to 123/0099 Page 51 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit the Division upon request (Plant Flare O&M Plan, as referenced in Colorado Construction Permit 15WE0939). • Added monitoring requirement to conduct Method 9 observations in the event visual emissions are detected via Method 22. The Method 9 observations were included as a way to demonstrate compliance with the Colorado Regulation No. 1 Section II.A.5 opacity standard. EPA Method 9 observations shall be conducted by a certified observer. If an opacity exceedance is observed, it shall be considered to exist until another Method 9 reading is taken which demonstrates compliance with the opacity standards of Colorado Regulation No. 1, Section II.A.5. • Statewide Controls for Oil and Gas Operations o Colorado Regulation No. 7, Part D, Section II.B. The plant flare at the Greeley Natural Gas Processing Plant is subject to the following general requirements of Colorado Regulation No. 7, Part D, Section II.B.: ■ Section II.B.1.b. (State-Only Enforceable) — The facility and air pollution control equipment shall be operated at all times using good air pollution control practices. It should be noted that all general facility requirements were grouped into a separate condition within the operating permit. The Plant Flare condition references these applicable requirements, which are located in Condition 12 of the operating permit. • 40 CFR Part 60, Subpart A §60.18 NSPS o The plant flare is subject to the federal requirements set forth in 40 CFR Part 60, Subpart A §60.18 "General Control Device and Work Practice Requirements". The applicable requirements from §60.18 were included in the operating permit as follows: • (§60.18(c)(1) & §60.18(f)(1) - Smokeless operation verified by Method 22 • §60.18(c)(2) & §60.18(f)(2) — Continuous pilot light presence, detected by a thermocouple or equivalent • §60.18(c)(3) — Source shall adhere to the heat content requirements of §60.18(c)(3)(ii) and the maximum tip velocity specifications of§60.18(c)(4), or, alternatively, to the requirements of§60.18(c)(3)(i). • Pursuant to the 2017 inspection report, the source demonstrates compliance with the heat content 123/0099 Page 52 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit requirements and the maximum tip velocity specifications. These specific requirements were therefore included in the operating permit. • §60.18(c)(3)(ii) & §60.18(f)(3) — Non-assisted flares shall only be used if the net heating value of the gas is greater than 200 Btu/SCF. • Pursuant to the 2017 inspection report, the plant flare at the Greeley Natural Gas Processing Plant is non-assisted. • §60.18(c)(4)(i) & §60.18(0(4) — Non-assisted flares shall be designed and operated with an exit velocity of less than 18.3 m/s. • §60.18(d) — Monitoring to ensure operational conformance with intended design and use. • §60.18(e) — Continuous operation when emissions are routed to the flare. NOTES: Please note the following in regards to the permit modification application received 5/2/2016: • Suggested conditions submitted on the 2000-604 forms were derived from Colorado Construction Permit 15WE0939. All requested conditions were incorporated EXCEPT as noted in Section IV of this document above. • It should be noted that the permit modification application received 5/2/2016 did not request monitoring for the pilot and purge gases. Requirements to monitor the flowrates of the pilot gas and combined purge/waste gas stream, as well as to perform an extended analysis on the combined purge/waste gas stream, were included in the operating permit since the NOx, CO and VOC emission limitations include contributions from these sources. 2. Emission Factors Emission factors for this unit were established as follows: • NOx & CO — Emissions of NOx & CO are generated from pilot gas, purge gas and waste gas destruction. The emission factor used to calculate NOx and CO emissions based off of the heat content of the waste and purge gas burned was obtained from AP-42 Chapter 13, Section 13.5 for Industrial Flares, Table 13.5-1 and Table 13.5-2 (dated 2/2018), respectively. Additionally, NOx and CO is generated via pilot gas combustion. The governing emission factors for this method of combustion were obtained from AP-42 Chapter 1, Section 1.4, Table 1.4-1 (dated 7/1998). • VOC & HAP - VOC and HAP emissions from pilot gas destruction were calculated using the emission factors obtained from AP-42 Chapter 1, Section 1.4, Tables 1.4-2 and 1.4-3 (dated 7/1998), respectively. Emission factors were not developed for the calculation of VOC and HAP emissions resultant from purge and waste gas destruction. Instead, VOC and HAP content (in 123/0099 Page 53 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit wt%) is obtained from the most recent extended analysis for the combined purge/waste gas stream. The purge/waste gas composition utilized shall be based on actual monthly operations and good engineering judgement. This VOC and HAP content is used in conjunction with the combined purge/waste gas flowrate and heat content (also obtained from the most recent extended analysis) to obtain monthly actual VOC and HAP emissions. 3. Monitoring Plan The following parameters shall be monitored at the prescribed frequency to ensure compliance with the annual limitations set forth in the permit: • Flare Gas Throughput — The amount of pilot and combined purge/waste gases processed by the plant flare shall be monitored using dedicated flowmeters for each. • Extended Gas Analysis - Performed annually on the combined purge/waste gas stream routed to the flare to be used to determine compliance with NOx, CO, and VOC emission limitations. The analysis should identify the VOC and HAP components. This analysis is also used to determine the heat content of the combined purge/waste gas. The purge/waste gas composition used for the purposes of emissions calculations shall be representative of the plant flare's actual operation and shall be based on good engineering judgement. • Pilot Light— Presence verified via daily visual inspection • Opacity— Method 22 observations required daily to ensure visible emissions are not present at the flare. In the event visual emissions are observed, a Method 9 reading shall be performed by a certified observer to determine compliance with the Colorado Regulation No. 1 Section II.A.5 opacity requirements. 4. Compliance Status Pursuant to the 2017 inspection report, the plant flare is in compliance with all applicable requirements in Colorado Construction Permit 15WE0939 and a separate compliance schedule/plan is not needed. C. Exempt Non-Emergency Natural Gas Fired Engines 1. Applicable Requirements This operating permit condition addresses the following miscellaneous engines located at this facility: • One (1) 16hp Briggs & Stratton Model No. 303447-1295-E1 Engine • One (1) 10hp Kohler Command Pro 10 Sweeper Brush Engine • One (1) 8.5hp Kohler Command Pro 8.5 Engine • One (1) 7.9hp Honda GX240 Engine 123/0099 Page 54 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Although these engines meet the insignificant activity criterion of Colorado Regulation No. 3, Part C, Section II.E.3.nnn.(iii) by having "uncontrolled actual emissions less than five tons per year or manufacturer's site-rated horsepower of less than fifty', they cannot be considered to be an insignificant activity pursuant to Section II.E., which prohibits such exemptions from being taken if a federal or state rule would be avoided by taking that exemption. Each engine is an existing SI 4SRB engine located at an area source of HAP emissions, and is therefore subject to 40 CFR 63 Subpart ZZZZ, as discussed in Section III above. Because these engines are subject to requirements in a federal rule, the insignificant activity exemption cannot be taken. As such, the applicable MACT ZZZZ requirements were incorporated into the body of the operating permit for these engines, as discussed below. It should be noted that these engines are exempt from the APEN reporting requirements of Colorado Regulation No. 3, Part A, Sections II.D.1.a and b, as they have uncontrolled actual emissions of less than 1 ton/year VOC and NOx (2 tons/year CO) and 250 lb/year non-criteria reportable pollutants. • State Requirements o Colorado Regulation No. 1, Section II.A.1 and I I.A.4 Opacity Each engine shall not emit in excess of 20% opacity, except for certain operational activities, where 30% opacity is permitted. Compliance with this condition shall be monitored by performing an annual Method 9 observation. A Method 9 observation is not required for any year during which the engine did not operate. • Federal Requirements o 40 CFR 63 Subpart ZZZZ For applicability purposes of Subpart ZZZZ, each engine is considered to be an existing, non-emergency, non-black start 4-stroke rich burn stationary RICE ≤ 500 hp located at an area source of HAP emissions. As such, each engine is required to comply with work practice, maintenance and recordkeeping requirements only. 2. Emission Factors As noted above, each engine produces actual uncontrolled emissions below the APEN reporting thresholds set forth in Colorado Regulation No. 3, Part A. As such, each engine is considered to be APEN-exempt and has no associated limitations. In addition, emissions from these engines do not need to be tracked for the purposes of comparison with the facility-wide HAP limitations set forth in Condition 11 of this permit. Facility-wide HAP limitations of 8 tons/year individual HAP and 20 tons/year total HAP were taken to permit a sufficient buffer between the major source threshold of 10 tons/year individual HAP and 25 tons/year total HAP, such that the tracking of emissions from units below APEN reporting thresholds is considered by the Division to be unnecessary. As such, any HAP emissions 123/0099 Page 55 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit generated by these engines do not need to be calculated for comparison against the facility-wide HAP limitations set forth in Condition 11 of this permit. 3. Monitoring Plan • Opacity — Method 9 observations required annually by a certified observer to monitor compliance with the Colorado Regulation No. 1 Section II.A.1 and 4 opacity requirements. A Method 9 observation is not required for any year during which the engine did not operate. 4. Compliance Status These engines were not included in a permit previous to this XX/XX/XXX issuance, and, as such, there is no compliance status to report. D. Exempt Emergency Natural Gas Fired Engine 1. Applicable Requirements This operating permit condition addresses the 14hp Briggs & Stratton Emergency Genset (model no. 030549). Although this engine meets the insignificant activity criterion of Colorado Regulation No. 3, Part C, Section II.E.3.nnn.(iii) by having "uncontrolled actual emissions less than five tons per year or manufacturer's site-rated horsepower of less than fifty', it cannot be considered to be an insignificant activity pursuant to Section II.E., which prohibits such exemptions from being taken if a federal or state rule would be avoided by taking that exemption. This engine is an existing emergency SI engine located at an area source of HAP emissions, and is therefore subject to 40 CFR 63 Subpart ZZZZ, as discussed in Section III above. Because this engine is subject to requirements in a federal rule, the insignificant activity exemption cannot be taken. As such, the applicable MACT ZZZZ requirements were incorporated into the body of the operating permit for this engine, as discussed below. It should be noted that this engine is exempt from the APEN reporting requirements of Colorado Regulation No. 3, Part A, Sections II.D.1.a and b, as it has uncontrolled actual emissions of less than 1 ton/year VOC and NOx (2 tons/year CO) and 250 lb/year non- criteria reportable pollutants. • State Requirements o Colorado Regulation No. 1, Section II.A.1 and II.A.4 Opacity This engine shall not emit in excess of 20% opacity, except for certain operational activities, where 30% opacity is permitted. Compliance with this condition shall be monitored by performing an annual Method 9 observation. A Method 9 observation is not required for any year during which the engine did not operate. • Federal Requirements o 40 CFR 63 Subpart ZZZZ For applicability purposes of Subpart ZZZZ, this engine is considered to be an existing, emergency spark ignition stationary RICE ≤ 500 hp located 123/0099 Page 56 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit at an area source of HAP emissions. As such, this engine is required to comply with work practice, maintenance and recordkeeping requirements only. On May 1st, 2015, the US Court of Appeals for the District of Columbia issued a decision to remand and vacate 40 CFR Part 63.6640(f)(2)(ii)-(iii). This decision leaves the other, non-demand response bases for granting a 100-hour exemption (e.g., testing, maintenance periods) in effect. Part 63.6640(f)(4)(ii) was voluntary remanded by EPA but not vacated. However, EPA has not yet finalized the proposed revisions to MACT ZZZZ. After internal discussions, and because official revisions have not been published, these sections were left in the permit. RICE operating as part of emergency demand response need to comply with all applicable requirements during such periods as per the rule language. 2. Emission Factors As noted above, this engine produces actual uncontrolled emissions below the APEN reporting thresholds set forth in Colorado Regulation No. 3, Part A. As such, this engine is considered to be APEN-exempt and has no associated limitations. In addition, emissions from this engine do not need to be tracked for the purposes of comparison with the facility-wide HAP limitations set forth in Condition 11 of this permit. Facility-wide HAP limitations of 8 tons/year individual HAP and 20 tons/year total HAP were taken to permit a sufficient buffer between the major source threshold of 10 tons/year individual HAP and 25 tons/year total HAP, such that the tracking of emissions from units below APEN reporting thresholds is considered by the Division to be unnecessary. As such, any HAP emissions generated by this engine do not need to be calculated for comparison against the facility-wide HAP limitations set forth in Condition 11 of this permit. 3. Monitoring Plan • Opacity — Method 9 observations required annually by a certified observer to monitor compliance with the Colorado Regulation No. 1 Section II.A.1 and 4 opacity requirements. A Method 9 observation is not required for any year during which the engine did not operate. 4. Compliance Status This engine was not included in a permit previous to this XX/XX/XXX issuance, and, as such, there is no compliance status to report. VI. MODIFICATIONS REQUESTED BY THE SOURCE In their modification applications submitted on since the last renewal of the operating permit on 5/1/2009, the source requested that the permit be revised to reflect the changes described in each application. A summary of the applications received is as follows: 123/0099 Page 57 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit The renewal application received on 5/1/2013 requested the following changes: • Cancellation of compressor engine P-120 o This request was processed as an administrative modification in the 9/6/2017 revision of the operating permit, and was therefore not addressed in the operating permit renewal. • Cancellation of dehydration unit P-136 o This request was processed as an administrative modification in the 9/6/2017 revision of the operating permit, and was therefore not addressed in the operating permit renewal. • Update serial number for compressor engine C-123 o This request was processed as an administrative modification in the 9/6/2017 revision of the operating permit, and was therefore not addressed in the operating permit renewal. • Update compressor engine identifiers from PXXX to C-XXX o This request was processed as an administrative modification in the 9/6/2017 revision of the operating permit, and was therefore not addressed in the operating permit renewal. • Modification to the AOS language for engines located at area source of HAP o The AOS language is Division-standard language and cannot be modified. This request was therefore not incorporated into the operating permit. However, all applicable MACT ZZZZ requirements were included in the operating permit as outlined in this request. Refer to Section VII of this document for more information regarding the incorporation of the new area source MACT ZZZZ requirements. • Updates to the insignificant activity list o This request was incorporated into the operating permit renewal. The permit modification application received on 5/2/2016 requested the following changes: • Incorporate Colorado Construction Permit 15WE0939 into the operating permit. Since this modification involves the incorporation of a new construction permit, the modification was processed as a significant modification as required by Colorado Regulation No. 3, Part C, Section I.A.7.c. The incorporation of this construction permit is addressed in detail in Section IV of this document. The permit modification application received on 12/21/2018 requested the following changes: 123/0099 Page 58 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit • Update the emission limitations and corresponding emission factors for engine C-123, pursuant to the alternative operating scenario (AOS) executed on 9/6/2018. Because the aforementioned modification does not: result in an increase in emissions above the significance threshold (40 tons/year), trigger a Title I modification (i.e., is not defined as a modification under an NSPS or MACT), require a case-by-case determination of emission limitations, require determinations for temporary sources, require or change a visibility or increment analysis, significantly alter monitoring requirements, relax reporting or recordkeeping requirements, establish a limit with the purpose of avoiding an otherwise applicable requirement, or establish a plant-wide emission limitations, this modification is considered minor in nature and was processed under the Colorado Regulation No. 3, Part C, Section X provisions for minor modifications. The permit modification application received on 12/20/2019 requested the following changes: • Update the fugitive emissions limit for P-133 based on an updated extended gas analysis and component count. • Incorporate the most recent requirements for fugitive emissions set forth in Colorado Regulation No. 7 for natural gas processing plants located in the 8 hour ozone control area. Because the aforementioned modification does not: result in an increase in emissions above the significance threshold (40 tons/year), trigger a Title I modification (i.e., is not defined as a modification under an NSPS or MACT), require a case-by-case determination of emission limitations, require determinations for temporary sources, require or change a visibility or increment analysis, significantly alter monitoring requirements, relax reporting or recordkeeping requirements, establish a limit with the purpose of avoiding an otherwise applicable requirement, or establish a plant-wide emission limitations, this modification is considered minor in nature and was processed under the Colorado Regulation No. 3, Part C, Section X provisions for minor modifications. The permit modification application received on 4/27/2020 requested the following changes: • Reduce NOx emission limitations for engines C-116 (AIRS 103), C-117 (AIRS 117), C-118 (AIRS 105), C-120 (AIRS 107) and C-122 (AIRS 110) below the significance threshold of 25 tons/year for a serious non-attainment area to allow these engines to use the permanent replacement alternative operating scenario (AOS), as defined in PS Memo 98-06. • Updated the emission calculation methodology for pressurized product truck loadout rack P-135 (AIRS 115) to base emissions estimation on truck traffic tracking, as opposed to product volumetric tracking. 123/0099 Page 59 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Since this modification involves the establishment of synthetic minor limits for the engines, the modification was processed as a significant modification as required by Colorado Regulation No. 3, Part C, Section I.A.7.c. Additionally, it should be noted that with the change in pressurized product truck loading, the Greeley Natural Gas Processing Plant is now considered to be a synthetic minor source of HAP emissions. Previously, this facility was true minor. As such, synthetic minor HAP limits were introduced in this renewal of the operating permit. The incorporation of this permit modification is addressed in detail in Section VII of this document. The permit modification addendum to the 4/27/2020 modification application received on 5/15/2020 requested the following changes: • Update serial number for engine C-116 (AIRS 103) pursuant to an alternative operating scenario (AOS) executed 5/1/2020. The serial number update was incorporated into the operating permit. Note that in order for a permanent AOS swing to occur, this engine must first be permitted with the reduced NOx limitations requested in the 4/27/2020 application. The swing conducted on 5/1/2020 was in accordance with the temporary AOS provisions set forth in the 5/1/2009 issuance of this operating permit. As such, this engine may operate for 270 days under the temporary provisions, providing the Division with the required time to permit engine C-116 with the reduced NOx limitations, as requested in the 4/27/2020 modification application. Other source-requested modifications were addressed as follows: Section I — General Activities and Summary • Updated responsible official contact information, pursuant to source comments received 5/22/2020. • Updated permitted activities description pursuant to the summary received in the 5/2/2016 significant modification application. • Included reference to the glycol pump alternative operating scenario (AOS) set forth in the EG dehydration unit Section II condition. Inclusion of this AOS allowance was requested in source comments received 5/22/2020. Section III — Permit Shield • The following requests for permit shield were granted pursuant to the justification given: o Colorado Regulation No. 1 Section III.A.1.b — for engines only ■ Colorado Regulation No. 1 Section III.A.1.b sets the particulate matter standards for fuel burning equipment. Engines, pursuant to the Colorado Common Provisions Regulation, are not considered fuel burning equipment and are therefore not subject to the Colorado Regulation No. 1 PM standards. As such, the permit 123/0099 Page 60 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit shield for these requirements for the engines only has been granted. o Colorado Regulation No. 7, Part B, Section IV.B.1 —Storage of Petroleum Distillates ■ The Greeley Natural Gas Processing Plant is not subject to any part of Colorado Regulation No. 7, Part B, Section IV, as these requirements were not intended to apply to liquids stored at gas processing plants (see discussion in Applicable Requirements Section III of this document). Therefore, the permit shield was granted for this section. o Colorado Regulation No. 7, Part B, Section IV.B.2 —Storage of Petroleum Distillates ■ The Greeley Natural Gas Processing Plant is not subject to any part of Colorado Regulation No. 7 Section IV, as these requirements were not intended to apply to liquids stored at gas processing plants (see discussion in Applicable Requirements Section III of this document). Therefore, the permit shield was granted for this section. o Colorado Regulation No. 7, Part B, Section V.C — Crude Oil Storage ■ This requirement subjects crude oil storage tanks in excess of 40,000 gallons to comply with selected requirements from Colorado Regulation No. 7, Part B, Section IV. The Greeley Natural Gas Processing Plant is not subject to any part of Colorado Regulation No. 7, Part B, Section IV, as these requirements were not intended to apply to liquids stored at gas processing plants (see discussion in Applicable Requirements Section III of this document). Therefore, the permit shield was granted for this section. • The following requests for permit shield were denied pursuant to the justification given: o Colorado Regulation No. 1 Section VI.B.5.a —for engines only ■ These requirements set forth the SO2 emission limitations for "any new source of sulfur dioxide not specifically regulated above". Engines are not "regulated above" in Colorado Regulation No. 1 Section VI. While engines are not considered fuel burning equipment for the purposes of the Colorado Regulation No. 1 particulate matter standard (see above), the SO2 requirements in Colorado Regulation No. 1 are applicable to new and existing S02- emitting equipment, regardless of whether or not that equipment is classified as "fuel burning" under the Common Provisions 123/0099 Page 61 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Regulation. Therefore, since these engines could be subject to this SO2 limitation, the permit shield was not granted. It should be noted, however, that the engines at the Greeley Natural Gas Processing Plant are natural gas fired. As such, emissions of SO2 are significantly below the 2 tons/day requirement in Colorado Regulation No. 1 Section VI.B.5.a. Because it is highly unlikely that these engines will operate anywhere near this 2 tons/day limitation, this requirement was not included in the operating permit. o Colorado Regulation No. 3 Section B.IV.D.3— PSD Review Requirements • It should be noted that the condition number referenced for this permit shield request has been updated to Colorado Regulation No. 3 Part D. Because a future modification to this source could trigger PSD review, the source may become subject to the PSD requirements of this section. Therefore, the permit shield was not granted for this regulation. o Colorado Regulation No. 3 Section B.X—Air quality modeling • It should be noted that the condition number referenced for this permit shield request no longer exists in the current form of the regulation. However, a future modification to this source may trigger the modeling requirements set forth in Colorado Regulation No. 3. Therefore, the permit shield was not granted. o Colorado Regulation No. 3 Section B.XI —Visibility requirements • The referenced section no longer exists in Colorado Regulation No. 3. As such, the permit shield was not granted. o Colorado Regulation No. 4 —Wood-burning stoves • The requirements of Colorado Regulation No. 4 are not addressed by the operating permit program. Therefore, the permit shield was not granted. o Colorado Regulation No. 6 Part A, NSPS Subpart 0000 — Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution • The Greeley Natural Gas Processing Plant is subject to the requirements of NSPS 0000, pursuant to Colorado Regulation No. 7, Part D, Section I.G. Therefore, this permit shield was not granted. o Colorado Regulation No. 7 Section V.C — Disposal of Volatile Organic Compounds 123/0099 Page 62 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit • Since the submittal of this application, Section V.C has been removed from Colorado Regulation No. 7. Therefore, this permit shield request is not applicable and the permit shield was not granted. o Colorado Regulation No. 8 Section E.I — NESHAPs • The Greeley Natural Gas Processing Plant is subject to the requirements of NESHAP Subpart ZZZZ. Therefore, this permit shield was not granted. o Colorado Regulation No. 8 Section E.III — 40 CFR Part 63, MACT HH — National Emission Standards for Hazardous Air Pollutants from Oil and Natural Gas Production Facilities • The Greeley Natural Gas Processing Plant, as an area source of HAP, is not subject to the requirements of Subpart HH since it does not operate a TEG dehydration unit. However, should this facility undergo a modification that triggers the major source thresholds for HAP, this facility could become subject to the requirements of Subpart HH. Therefore, this permit shield was not granted. o Colorado Regulation No. 10 — Criteria for Analysis of Transportation Conformity • The requirements of Colorado Regulation No. 10 do not apply to stationary sources. Therefore, this permit shield request is not applicable and the permit shield was not granted. Appendices • Appendix A o Updated facility plot plan with the copy received in the 5/2/2016 significant permit modification application. o Updated insignificant activities list based on the renewal application received on 5/1/2013 and source correspondence received on 4/25/2018. VII. OTHER MODIFICATIONS In addition to the source requested modifications, the Division has included changes to make the permit more consistent with recently issued permits, include comments made by EPA on other Operating Permits, as well as correct errors or omissions identified during inspections and/or discrepancies identified during review of this renewal. These changes are as follows: Page Following Cover Page • Modified the language concerning postmarked dates for report submittals to reflect the Division's current standard language. 123/0099 Page 63 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Section I — General Activities and Summary • Condition 1.1 o Corrected street address pursuant to email received on 5/31/2018. o Relocated carbon monoxide (CO) backsliding requirements for CO attainment/maintenance areas from the NANSR/PSD requirements (Condition 3.1) to this Condition 1.1 to be consistent with current Division- standard formatting. Updated CO backsliding requirement language to the most current Division-standard (ver. 1/21/2020). o Revised list of Federal Class I designated areas to include the Rawah Wilderness, which is within 100 km of the Greeley Natural Gas Processing Plant. • Condition 1.3 o Added reference to Colorado Construction Permit 15WE0939, which was absorbed into the operating permit as a part of the renewal process. • Condition 1.4 o Updated to reference all conditions within the operating permit that are state-only enforceable. • Condition 2 o Updated alternative operating scenario (AOS) language for natural gas fired engines to the most current Division standard (ver. 10/12/2012 updated to reflect regulatory citation changes). It should be noted that since the revision of the AOS language, some regulatory citations have changed. The updated citations were included in the operating permit as follows: • The significance levels, for the purposes of PSD/NANSR, are found in Colorado Regulation No. 3, Part D, Section II.A.44. • The RACT requirements are found in Colorado Regulation No.3, Part B, Section III.D.2. • Colorado Regulation No. 7, Part E, Section I was reorganized with the 2/14/2020 promulgation. The referenced Section XVI requirements are now included in Part E, Section I.B, and the Section XVII requirements are now included in Part E, Section I.D. • Relocation requirements for stationary internal combustion engines are found in Colorado Regulation No. 6, Part B, Section I.C. • Condition 3.1 123/0099 Page 64 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit o Updated the NANSR/PSD facility status language to the most current Division-standard (ver. 1/21/2020) • Condition 5 o Updated CAM list to included engine C-123, which has the potential to emit NOx in excess of the major source threshold of 50 tons/year, complies with an emission limitation and utilizes a control device to achieve that limitation. • Condition 6 o Updated table to include new information regarding the EG dehydration unit and to add the plant flare, as required by Colorado Construction Permit 15WE0939. Section II — Specific Permit Terms Condition 1 —C-116/C-117/C-118/C-119/C-120/C-122/C-152—Waukesha L-7042GSI 1,100 hp Compressor Engines, AIRS ID: 103/104/105/106/107/109/110; C-123 — Waukesha L-7042 GU 896 hp Compressor Engine, AIRS ID: 108 It should be noted that in the previous operating permit issuance, C-123 had been addressed in Condition 2 of the operating permit, since the conditions applicable to that engine were more closely aligned with that of C-124. However, since the previous issuance, area source provisions under 40 CFR Part 63 Subpart ZZZZ and new Colorado Regulation No. 7, Part E, Section I and II requirements have been promulgated. Due to certain applicability thresholds in these rules, the requirements of C-123 are now more closely aligned with the larger 1,100 hp engines. As such, C-123 is now addressed in this Condition 1. Engine C-124, which is significantly smaller, is subject to different requirements under these regulations. As such, C-124 is addressed in a separate, dedicated condition in the operating permit. The following updates were made to Condition 1 of the operating permit: • Condition 1.1 — NOx & CO Emission Limitations & Compliance Monitoring o Split condition into two separate conditions in order to address VOC separately from NOx and CO. Although portable monitoring is required for NOx and CO emissions, VOC emissions are not monitored in this manner. For clarity, the monitoring and compliance demonstration requirements specific to VOC were separated into a new condition. o Updated emission limitations for engines C-116, C-117, C-118, C-120 and C-122 pursuant to the significant modification application received 4/27/2020, and engine C-123 pursuant to the minor modification application received 12/21/2018. o Added requirement to maintain records of the monthly emission calculations to be made available to the Division upon request. • Condition 1.2—VOC Emission Limitations & Compliance Monitoring 123/0099 Page 65 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit o Created this new condition to specifically address VOC compliance monitoring requirements. Emissions of VOC shall be calculated monthly using the approved emission factors listed in the summary table, the monthly fuel gas throughput and the heat content from the most recent fuel analysis. This calculation shall be used in a 12 month rolling total to monitor compliance with the annual limitations. Records of this calculation shall be maintained and made available to the Division upon request. o Updated emission limitations for engine C-123 pursuant to the minor modification application received 12/21/2018. o Created new reference condition to the facility-wide synthetic minor HAP limitations. With the significant modification received 4/27/2020, the Greeley Natural Gas Processing Plant is now considered to be a synthetic minor source of HAP and requires limitations to ensure the facility retains its area source status under the 40 CFR Part 63 MACT rules. Because these HAP limitations apply on a facility-wide basis, these limits, as well as the engine calculation methodologies for HAP, were included in a separate condition within the operating permit and a reference to that Condition 11 was included in this engine condition. • Condition 1.3 — Natural Gas Consumption Limitations & Compliance Monitoring o Moved partitioning calculation from previous Condition 11 to this condition for clarity. o Updated partitioning calculation to account for all fuel users (i.e., the hot oil heaters, pilot gas, etc.) as opposed to the engines only. This ensures a more accurate allocation of fuel gas consumption among equipment. • Condition 1-.4— Natural Gas Heat Content o Added requirement to maintain records of the heat content verification results to be made available to the Division upon request. • Condition 1.5 — Hours of Operation o Added requirement to record hours of operation on the first day of the month, mirroring the natural gas consumption condition. This ensures accurate partitioning of the fuel gas among users. • Condition 1.6 — Opacity o Added Colorado Regulation No. 1, Section II.A.4 allowance for emissions of 30% opacity for a limited period during certain operational activities. • Condition 1.7— Control Device Requirements o Added requirement to maintain records of the monthly AFR millivolt reading and relevant manufacturer recommendations to be made available to the Division upon request. 123/0099 Page 66 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit o Removed requirement to operate engines in accordance with manufacturer recommendations at all times. Since the previous issuance of the operating permit on 5/1/2009, this requirement has been incorporated into Colorado Regulation No. 7, Part D, Section II.B.1.b. Because the Greeley Natural Gas Processing Plant is an oil and gas operation within the state of Colorado, this entire facility is subject to Section II.B.1.b. This general requirement of Colorado Regulation No. 7 was included in a separate condition within the operating permit. • Condition 1.8 — Portable Monitoring o Added condition to indicate that each engine is subject to quarterly portable monitoring. Included reference to specific portable monitoring requirements set forth in Condition 14 of the operating permit. • Condition 1.9 — Compliance Assurance Monitoring o Removed requirement to comply with CAM within 180 days of the operating permit issuance. Per the 2017 inspection report, the source is in compliance with this one-time requirement. o Updated condition to specifically identify the engines subject to CAM and the pollutant (NOx) for which each engine is subject. ■ It should be noted that in the previous issuance of the operating permit, engine C-123 was excluded from the CAM requirements. However, this engine does have uncontrolled NOx emissions in excess of the 50 tons/year major source threshold, and utilizes a control device (Non-Selective Catalytic Reduction; NSCR) to comply with a limitation, thereby satisfying the applicability criteria of the CAM rule, set forth in §64.2(a)(1)-(3). This engine is therefore subject to CAM. • Condition 1.10 - Statewide Controls for Oil and Gas Operations o Colorado Regulation No. 7, Part E, Section I.B. These requirements, including the installation of an NSCR and AFRC (Section I.B.1) and maintaining the engine according to manufacturer specification (Section I.B.3), were included in the previous issuance of the operating permit on 5/1/2009. However, these conditions were modified to exactly mirror the most current version of Colorado Regulation No. 7 to eliminate paraphrasing, pursuant to Division-standard practice. o Engine C-123 Only: Colorado Regulation No. 7, Part E, Section I.D. At the time of the previous issuance of the operating permit on 5/1/2009, the engine requirements of Colorado Regulation No. 7, Part E, Section I.D had not yet been promulgated. The applicable requirements were included as follows: 123/0099 Page 67 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit ■ Section I.D.2. (State-Only Enforceable) — Requirement to comply with the Table 1 limitations. Note that based on the date of (re)location into Colorado that only Engine C-123 is subject to these limitations. • For clarity, compliance demonstration methods were included in the operating permit to specify how the operator is expected to demonstrate compliance with these limitations. Compliance with the NOx and CO limitations will be assessed using the quarterly portable analyzer test results. For the purposes of VOC, compliance is presumed provided the portable monitoring indicates compliance with the NOx and CO emission limitations. o Colorado Regulation No. 7, Part E, Section II.A. At the time of the previous issuance of the operating permit on 5/1/2009, the combustion process adjustment requirements for engines of Colorado Regulation No. 7, Part E, Section II.A. had not yet be promulgated. These requirements apply to engines operating in the non-attainment area at a facility considered to be a major source of NOx emissions as of 6/3/2016, under the moderate non-attainment major source threshold of 100 tons/year. The Greeley Natural Gas Processing Plant was a major source of NOx emissions prior to this date. As such, the engines at this facility are considered to be affected combustion equipment. Engines with uncontrolled actual NOx emissions greater than or equal to 5 tons/year are subject to Section II.A. Each engine addressed in this Condition has uncontrolled, actual NOx emissions in excess of 5 tons/year. As such, the requirements of Section II.A. were incorporated into the operating permit as follows: • Section II.A.2. — This section lists exemptions from the requirements of Section II.A.4. (emission limitations), Section II.A.5. (compliance demonstration), certain parts of Section II.A.7. (recordkeeping) and Section II.A.8. (reporting). All engines included in this condition qualify for the Section II.A.2.e. exemption, as each engine is greater than 500 hp and located in the 8 hour ozone control area and are therefore subject to the emission control requirements of Colorado Regulation No. 7, Part E, Section I.B. As such, these engines are not required to comply with the aforementioned sections. • Section II.A.6. — This section sets forth the required combustion process adjustment procedures for combustion equipment with uncontrolled actual NOx emissions greater than or equal to 5 tons/year. Each engine included in this condition is permitted to produce NOx emissions in excess of this threshold and are therefore required to perform combustion process adjustments. Combustion process adjustments for engines include annual 123/0099 Page 68 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit inspection of oil, filters, hoses, belts and spark plugs and maintaining the engines pursuant to manufacturer specification. ■ Section II.A.7. — This section sets forth the recordkeeping requirement to demonstrate compliance with Sections II.A.2. and II.A.6. Records must be kept of the combustion process adjustments performed (Section II.A.7.f.) and documentation must be maintained to demonstrate that an exemption set forth in Section II.A.2. applies (Section II.A.7.g). • Condition 1.11 —40 CFR Part 63 Subpart ZZZZ MACT At the time of the previous issuance of the operating permit on 5/1/2009, the area source requirements of Subpart ZZZZ had not yet been promulgated. Compliance with these new area source requirements was mandated by October 19, 2013. Pursuant to the 2017 inspection report, the Greeley Natural Gas Processing Plant is in compliance with all applicable Subpart ZZZZ requirements. Because the initial compliance date of October 19, 2013 has passed and the source is in compliance with Subpart ZZZZ, initial compliance requirements were not included in the operating permit. For applicability purposes of Subpart ZZZZ, all engines are considered to be existing, non-emergency, non-black start, 4- stroke rich burn engines > 500 hp located at an area source of HAP that are not remote stationary RICE and that operate more than 24 hours per calendar year. The following requirements were found to be applicable to these engines and were included in the operating permit: o General Requirements • Each engine shall be in compliance with the applicable requirements of Subpart ZZZZ at all times (§63.6605(a)). • Each engine and associated air pollution control equipment must operate in a manner consistent with good air pollution control practices (§63.6605(b)). o Emission Limitations • Each engine shall comply with the emission limitations set forth in Table 2d of Subpart ZZZZ. For the purposes of the Greeley Natural Gas Processing Plant, this includes operating each engine with an NSCR to reduce HAP emissions (§63.6603(a) &Table 2d Item 12). • It should be noted that §63.6603 also requires compliance with the operating limitations set forth in Table 2b. All operating limitations in this table apply only to major sources of HAP emissions. Because the Greeley Natural Gas Processing Plant is an area source of HAP emissions, none of these requirements are applicable. o Monitoring, Installation, Collection, Operation and Maintenance Requirements 123/0099 Page 69 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit • The time during which the engine idles during startup shall be minimized, not to exceed 30 minutes (§63.6625(h)). o Data Collection for Continuous Requirements • Each engine shall be monitored at all times (§63.6635(b)). • Only valid data (i.e., data not collected during monitoring malfunctions or repairs) shall be used to report emission or operating levels (§63.6635(c)). o Continuous Compliance Demonstration • Annual compliance demonstration of CO and THC reductions shall be conducted annually (§63.6640(a) & Table 6, Item 15.a.i). • Engines shall be immediately shut down should the catalyst inlet temperature exceed 1250°F (§63.6640(a) & Table 6, Item 15.a.iii). • It should be noted that Table 6 also allows for an option to install a CPMS system to continuously monitor catalyst inlet temperature, in lieu of installing a high temperature shutdown interlock. Pursuant to source correspondence received on 4/18/2018, the source utilizes the high temperature shutdown interlock to demonstrate continuous compliance with Subpart ZZZZ. As such, none of the CPMS requirements of Subpart ZZZZ are applicable. • The source shall report each instance in which the emission or operating limitation was not met (§63.6640(b)). • The annual compliance demonstration shall be carried out as required by §63.6640(c). • Instances in which the applicable General Provisions of Subpart A were not complied with must also be reported (§63.6640(e)). o Notification, Recordkeeping and Reporting Requirements • The applicable notifications required per §63.9 shall be submitted (§63.6645(a)). • A report containing the annual compliance demonstration shall be submitted annually (§63.6650(a) & Table 7, Item 3.a.i). • Compliance report schedule and submittal requirements (§63.6650(b) and (c)). • For each deviation, the compliance report must contain the information in §63.6650(c) and (d) (§63.6650(d)). • Deviations and compliance reports may be submitted with the Title V semi-annual report (§63.6650(f)). 123/0099 Page 70 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit ■ Recordkeeping requirements, retention periods and record formatting (§63.6655(a) & (d); §63.6660(a)-(c)). • Condition 1.12 —40 CFR Part 63 Subpart A MACT As required by 40 CFR Part 63, Subpart ZZZZ §63.6665, certain requirements of the General Provisions of Subpart A are applicable to the engines at the Greeley Natural Gas Processing Plant as follows: o Prohibited activities and circumvention (§63.4) o Notification requirements (§63.9) o Recordkeeping and reporting requirements (§63.10) Condition 2 — C-124—Waukesha F-11 G 125 hp Compressor Engine, AIRS ID: 102 It should be noted that in the previous operating permit issuance, C-123 had been addressed in Condition 2 of the operating permit, since the conditions applicable to that engine were more closely aligned with that of C-124. However, since the previous issuance, area source provisions under 40 CFR Part 63 Subpart ZZZZ and new Colorado Regulation No. 7, Part E, Section I and II requirements have been promulgated. Due to certain applicability thresholds in these rules, the requirements of C-123 are now more closely aligned with the larger 1,100 hp engines. As such, C-123 is now addressed in this Condition 1. Engine C-124, which is significantly smaller, is subject to different requirements under these regulations. As such, C-124 only is addressed in this Condition 2 of the operating permit. The following updates were made to Condition 2 of the operating permit: • Condition 2.1 — NOx & CO Emission Limitations & Compliance Monitoring o Removed VOC emission limitation and associated monthly monitoring. Uncontrolled emissions of VOC are below the 1 ton/year de minimis threshold for sources operating in non-attainment areas (Colorado Regulation No. 3, Part A, Section II.B.3.a.). As such, a permit limitation for this pollutant is not required. o Added requirement to maintain records of the monthly emission calculations to be made available to the Division upon request. o Created new reference condition to the facility-wide synthetic minor HAP limitations. With the significant modification received 4/27/2020, the Greeley Natural Gas Processing Plant is now considered to be a synthetic minor source of HAP and requires limitations to ensure the facility retains its area source status under the 40 CFR Part 63 MACT rules. Because these HAP limitations apply on a facility-wide basis, these limits, as well as the engine calculation methodologies for HAP, were included in a separate condition within the operating permit and a reference to that Condition 11 was included in this engine condition. • Condition 2.2 — Natural Gas Consumption Limitations & Compliance Monitoring 123/0099 Page 71 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit o Moved partitioning calculation from previous Condition 11 to this condition for clarity. o Updated partitioning calculation to account for all fuel users (i.e., the hot oil heaters, pilot gas, etc.) as opposed to the engines only. This ensures a more accurate allocation of fuel gas consumption among equipment. • Condition 2.3 — Natural Gas Heat Content o Added requirement to maintain records of the heat content verification results to be made available to the Division upon request. • Condition 2.4 — Hours of Operation o Added requirement to record hours of operation on the first day of the month, mirroring the natural gas consumption condition. This ensures accurate partitioning of the fuel gas among users. • Condition 2.5 — Opacity o Added Colorado Regulation No. 1, Section II.A.4 allowance for emissions of 30% opacity for a limited period during certain operational activities. • Condition 2.6— Control Device Requirements o Removed requirement to operate engines in accordance with manufacturer recommendations at all times. Since the previous issuance of the operating permit on 5/1/2009, this requirement has been incorporated into Colorado Regulation No. 7, Part D, Section II.B.1.b. Because the Greeley Natural Gas Processing Plant is an oil and gas operation within the state of Colorado, this entire facility is subject to Section II.B.1.b. This general requirement of Colorado Regulation No. 7 was included in a separate condition within the operating permit. o Added requirement to maintain records of the monthly AFR millivolt reading and relevant manufacturer specifications to be made available to the Division upon request. • Condition 2.7— Portable Monitoring o Added condition to indicate that each engine is subject to quarterly portable monitoring. Included reference to specific portable monitoring requirements set forth in Condition 14 of the operating permit. • Condition 2.8— Statewide Controls for Oil and Gas Operations At the time of the previous issuance of the operating permit on 5/1/2009, the combustion process adjustment requirements for engines of Colorado Regulation No. 7, Part E, Section II.A. had not yet be promulgated. These requirements apply to engines operating in the non-attainment area at a facility considered to be a major source of NOx emissions as of 6/3/2016, under the moderate non-attainment major source threshold of 100 tons/year. The Greeley 123/0099 Page 72 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Natural Gas Processing Plant was a major source of NOx emissions prior to this date. As such, the engines at this facility are considered to be affected combustion equipment. Engines with uncontrolled actual NOx emissions greater than or equal to 5 tons/year are subject to Section II.A. Engine C-124 has uncontrolled, actual NOx emissions in excess of 5 tons/year. As such, the requirements of Section II.A. were incorporated into the operating permit as follows: o Section II.A.2. — This section lists exemptions from the requirements of Section II.A.4. (emission limitations), Section II.A.5. (compliance demonstration), certain parts of Section II.A.7. (recordkeeping) and Section II.A.8. (reporting). Engine C-124 qualifies for the Section II.A.2.f. exemption, as this engine is subject to the requirements of Colorado Regulation No. 7, Part E, Section III.A. As such, this engine is not required to comply with the aforementioned sections. o Section II.A.6. — This section sets forth the required combustion process adjustment procedures for combustion equipment with uncontrolled actual NOx emissions greater than or equal to 5 tons/year. This engine is permitted to produce NOx emissions in excess of this threshold and is therefore required to perform combustion process adjustments. Combustion process adjustments for engines include annual inspection of oil, filters, hoses, belts and spark plugs and maintaining the engines pursuant to manufacturer specification. o Section II.A.7. — This section sets forth the recordkeeping requirement to demonstrate compliance with Sections II.A.2. and II.A.6. Records must be kept of the combustion process adjustments performed (Section II.A.7.f.) and documentation must be maintained to demonstrate that an exemption set forth in Section II.A.2. applies (Section II.A.7.g). • Condition 2.9 —40 CFR Part 63 Subpart ZZZZ MACT At the time of the previous issuance of the operating permit on 5/1/2009, the area source requirements of Subpart ZZZZ had not yet been promulgated. Compliance with these new area source requirements was mandated by October 19, 2013. Pursuant to the 2017 inspection report, the Greeley Natural Gas Processing Plant is in compliance with all applicable Subpart ZZZZ requirements. Because the initial compliance date of October 19, 2013 has passed and the source is in compliance with Subpart ZZZZ, initial compliance requirements were not included in the operating permit. For applicability purposes of Subpart ZZZZ, this engine is considered to be an existing, non-emergency, non-black start 4- stroke rich burn stationary RICE ≤ 500 hp. The following requirements were found to be applicable to C-124 and were included in the operating permit: o General Requirements • This engine shall be in compliance with the applicable requirements of Subpart ZZZZ at all times (§63.6605(a)). 123/0099 Page 73 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit • This engine and associated air pollution control equipment must operate in a manner consistent with good air pollution control practices (§63.6605(b)). o Emission Limitations • This engine shall comply with the emission limitations set forth in Table 2d of Subpart ZZZZ. For the purposes of C-124, this includes changing the oil and filter and inspecting the spark plugs and hoses every 1,440 hours or annually (§63.6603(a) & Table 2d Item 10.a- c). • It should be noted that §63.6603 also requires compliance with the operating limitations set forth in Table 2b. All operating limitations in this table apply only to major sources of HAP emissions. Because the Greeley Natural Gas Processing Plant is an area source of HAP emissions, none of these requirements are applicable. o Monitoring, Installation, Collection, Operation and Maintenance Requirements • The engine and control device shall be maintained according to manufacturer's specification, or the source shall develop its own maintenance plan (§63.6625(e)). • The time during which the engine idles during startup shall be minimized, not to exceed 30 minutes (§63.6625(h)). o Continuous Compliance Demonstration • Continuous compliance with the work practices listed in Table 2d shall be demonstrated by operating the engine in accordance with manufacturer specification or by developing and following a source-specific maintenance plan (§63.6640(a) & Table 6, Item 9.a.i & ii). • The source shall report each instance in which the emission or operating limitation in Table 2d was not met (§63.6640(b)). • Instances in which the applicable General Provisions of Subpart A were not complied with must also be reported (§63.6640(e)). o Notification, Recordkeeping and Reporting Requirements • Deviations shall be submitted with the Title V semi-annual report (§63.6650(f)). • For the purposes of C-124, deviations are defined in §63.6640(b) as instances in which the requirements of Table 2d are not met. 123/0099 Page 74 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit ■ Recordkeeping requirements, retention periods and record formatting (§63.6655(a), (d), (e); §63.6660(a)-(c)). • Condition 2.10—40 CFR Part 63 Subpart A MACT As required by 40 CFR Part 63, Subpart ZZZZ §63.6665, certain requirements of the General Provisions of Subpart A are applicable to the engines at the Greeley Natural Gas Processing Plant as follows: o Prohibited activities and circumvention (§63.4) o Recordkeeping and reporting requirements (§63.10) Condition 3-P139-G.C. Broach Natural Gas Fired 35.1 MMBtu/hr Hot Oil Heater, AIRS ID: 120 • Condition 3.1 — NOx and CO Emission Limitations & Compliance Monitoring o Supplemented condition with calculation methodology, requiring that emissions be calculated monthly using the listed emission factor and the amount of fuel used each month. ■ In the previous issuance of the operating permit on 5/1/2009, emission factors for VOC, S02, PM and PM10 from AP-42 Table 1- 4.2 (dated 7/1998) were included in the summary table. All emissions of these pollutants are significantly below the de minimis reporting threshold of 2 tons/year (1 ton/year for VOC), and, as such, a permit limitation is not required for any of these pollutants (Colorado Regulation No. 3, Part A, Section II.B.3.a.). However, it should be noted that particulate matter emissions are subject to the Colorado Regulation No. 1 PM standard, as detailed in the following condition. o Created new reference condition to the facility-wide synthetic minor HAP limitations. With the significant modification received 4/27/2020, the Greeley Natural Gas Processing Plant is now considered to be a synthetic minor source of HAP and requires limitations to ensure the facility retains its area source status under the 40 CFR Part 63 MACT rules. Because these HAP limitations apply on a facility-wide basis, these limits, as well as the heater calculation methodologies for HAP, were included in a separate condition within the operating permit and a reference to that Condition 11 was included in this heater condition. • Condition 3.2 — PM Emission Limitations & Compliance Monitoring Fuel burning equipment within the state of Colorado is subject to the requirements of Colorado Regulation No. 1, Section III.A. Fuel burning equipment is defined in the Colorado Common Provisions Regulation as "any furnace, boiler, or other equipment and appurtenances thereto, burning fuel solely for the purpose of producing heat, but not including: (1) internal combustion engines, or (2) combustion sources that are a part of a 123/0099 Page 75 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPW'E038 Technical Review Document—Renewal Operating Permit manufacturing process where the emissions are intermixed with the process emissions". The hot oil heaters at the Greeley Natural Gas Processing Plant are, for the purposes of this regulation, considered to be fuel burning equipment. As such, these heaters are subject to the applicable requirements of Colorado Regulation No. 1, Section III.A. These requirements were included in the operating permit as follows: o This heater shall comply with the Colorado Regulation No. 1, Section III.A.1.b particulate matter limitation of 0.198 lb/MMBtu for P-139, which is based on the design heat input of the heater (35.1 MMBtu/hr). It should be noted, however, that this limitation is significantly higher than what the total PM emission factor from AP-42 Chapter 1.4, Table 1.4-2 (dated 7/1998) predicts for natural gas combustion. Because combustion of natural gas results in significantly lower actual emissions of total PM, the Division has determined that compliance with this limit may be presumed at all times, provided natural gas only is used as fuel for this heater. As such, this heater is permitted to use natural gas only as fuel and the source shall demonstrate compliance with this Colorado Regulation No. 1 requirement by maintaining records to verify natural gas only is used. No ongoing numerical compliance demonstration for the Colorado Regulation No.1, Section III.A.1.b. PM limit is necessary. • Condition 3.3 — Natural Gas Consumption Limitations & Compliance Monitoring o Moved partitioning calculation from previous Condition 11 to this condition for clarity. o Updated partitioning calculation to account for all fuel users (i.e., the hot oil heaters, engines, pilot gas, etc.) as opposed to the heaters only. This ensures a more accurate allocation of fuel gas consumption among equipment. • Condition 3.4— Natural Gas Heat Content o Added requirement to verify the heat content of the natural gas to be used as fuel for the heater. The heat content of the natural gas is required to perform the partitioning calculation of the fuel gas from the facility-wide meter reading to the individual users. • Condition 3.5— Hours of Operation o Added requirement to track the hours of operation for the heater, to be made available to the Division upon request. Hours of operation are required to perform the partitioning calculation of the fuel gas from the facility-wide meter reading to the individual users. ■ It should be noted that this condition contains the requirement to record the hours of operation on the first day of the month, mirroring the engine hours of operation condition. This was done to ensure accurate partitioning among fuel gas users. 123/0099 Page 76 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit • Condition 3.6 — Opacity o Added Colorado Regulation No. 1, Section II.A.4 allowance for emissions of 30% opacity for a limited period during certain operational activities. o Added Colorado Regulation No. 6, Part B, Section II.C.3 requirement to limit particulate matter discharge to 20% opacity or less (State-Only Enforceable) ■ This heater is subject to the Colorado Regulation No. 1 Section II.A.1 20% opacity requirement and the Section II.A.4 30% opacity requirement for certain specific operational activities. The Section II.A.1 20% opacity requirement applies at all times, except for certain specific operating conditions under which the Section II.A.4 30% opacity requirement applies. As fuel burning equipment (see applicability discussion under Condition 3.2 above), the heaters are also subject to the state-only Colorado Regulation No. 6 Part B Section II.C.3 20% opacity requirement. Colorado Regulation No. 6 Part B Section I.A, adopts, by reference, the 40 CFR Part 60 Subpart A general provisions. 40 CFR Part 60 Subpart A§60.11(c) specifies that the opacity requirements are not applicable during periods of startup, shutdown and malfunction. The Colorado Regulation No. 1 Section II.A.1 and II.A.4 20%/30% requirements are more stringent than the Colorado Regulation 6 Part B Section II.C.3 opacity requirements during periods of startup, shutdown and malfunction. However, the Colorado Regulation No. 6 Part B Section II.C.3 20% opacity requirement is more stringent during fire building, cleaning of fire boxes, soot blowing, process modifications and adjustment or occasional cleaning of control equipment. Therefore, since no one opacity requirement is more stringent than the other at all times, all three opacity requirements are included in the operating permit. • Condition 3.7 — Statewide Controls for Oil and Gas Operations At the time of the previous issuance of the operating permit on 5/1/2009, the combustion process adjustment requirements for process heaters of Colorado Regulation No. 7, Part E, Section II.A. had not yet been promulgated. These requirements apply to combustion equipment operating in the non-attainment area at a facility considered to be a major source of NOx emissions as of 6/3/2016 under the moderate non-attainment major source threshold of 100 tons/year. The Greeley Natural Gas Processing Plant was a major source of NOx emissions prior to this date. As such, the process heaters at this facility are considered to be affected combustion equipment. Applicable requirements were included as follows: o Section II.A. — This section establishes the requirements for emission limitations, compliance demonstrations, combustion process adjustments, reporting and recordkeeping applying to stationary combustion equipment 123/0099 Page 77 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit located at major sources of NOx. In Section II.A.2., exemptions from the requirements of Section II.A.4. (emission limitations), Section II.A.5. (compliance demonstration), certain parts of Section II.A.7. (recordkeeping) and Section II.A.8. (reporting) are listed. Heater P-139 does not qualify for any of these exemptions. However, heater P-139 is considered to be a process heater for the purposes of Section II.A. Requirements for process heaters do not exist in Sections II.A.4 or II.A.5 and, thus, neither of these sections, nor the associated recordkeeping and reporting apply to this heater. However, process heaters are affected equipment under the combustion process adjustment requirements of Section II.A.6. and the associated recordkeeping under Section II.A.7. Affected operations, pursuant to Section I I.A.6.a., include process heaters with greater than or equal to 5 tons/year of actual uncontrolled NOx emissions. Heater P-139 produces uncontrolled actual NOx emissions in excess of this threshold, and is therefore subject to Sections II.A.6. and II.A.7. The requirements set forth in these sections include annual inspection of burner, combustion controls, flame pattern and air to fuel ratio controller, measurement of CO and NOx before and after each adjustment and maintenance of records of any adjustments made pursuant to this section. • Condition 3.8 —40 CFR Part 60 Subpart Dc NSPS o Updated condition to include recordkeeping requirement of the daily amount of fuel combusted (§60.48c(g)(1)) or, if using natural gas, the monthly amount of fuel combusted (§60.48c(g)(2)). • Condition 3.9—40 CFR Part 60 Subpart A NSPS Because this heater is subject to 40 CFR Part 60 Subpart Dc, this heater is also subject to the applicable general requirements of Subpart A. This condition was reformatted to simply list the applicable requirements of Subpart A, instead of including the rule text. The following sections are applicable to this heater: o Notification and Recordkeeping (§60.7) o Standards and Maintenance Requirements (§60.11(d)) o Circumvention (§60.12) • Conditions Removed o APEN submittal requirements ■ In the previous issuance of this operating permit on 5/1/2009, APEN submittal requirements were included for this heater, which was directly incorporated into the permit and did not go through a separate construction permit process, pursuant to Colorado Regulation No. 3, Part C Section III.B. This requirement was removed from the permit body as it is addressed in the Section IV general requirements of the operating permit. 123/0099 Page 78 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit o Colorado Regulation No. 6 Part A Subpart A General Requirements ■ Because this heater is subject to 40 CFR Part 60 Subpart Dc, it is also subject to the general requirements set forth in 40 CFR Part 60 Subpart A, including the notification and recordkeeping requirements of §60.7 and the circumvention requirements of §60.12. As such, The Colorado Regulation No. 6 text was removed in favor of the more generalized listing of each applicable Subpart A requirement. These requirements were included in Condition 3.9 above. Condition 4 — P-132 — Born Natural Gas Fired 15 MMBtu/hr Hot Oil Heater, AIRS ID: 113 • Condition 4.1 — NOx and CO Emission Limitations & Compliance Monitoring o Supplemented condition with calculation methodology, requiring that emissions be calculated monthly using the listed emission factor and the amount of fuel used each month. ■ In the previous issuance of the operating permit on 5/1/2009, emission factors for VOC, SO2, PM and PMio from AP-42 Table 1- 4.2 (dated 7/1998) were included in the summary table. All emissions of these pollutants are significantly below the de minimis reporting threshold of 2 tons/year, and, as such, a permit limitation is not required for any of these pollutants (Colorado Regulation No. 3, Part A, Section I1.B.3.a.). However, it should be noted that particulate matter emissions are subject to the Colorado Regulation No. 1 PM standard, as detailed in the following condition. o Created new reference condition to the facility-wide synthetic minor HAP limitations. With the significant modification received 4/27/2020, the Greeley Natural Gas Processing Plant is now considered to be a synthetic minor source of HAP and requires limitations to ensure the facility retains its area source status under the 40 CFR Part 63 MACT rules. Because these HAP limitations apply on a facility-wide basis, these limits, as well as the heater calculation methodologies for HAP, were included in a separate condition within the operating permit and a reference to that Condition 11 was included in this heater condition. • Condition 4.2 — PM Emission Limitations & Compliance Monitoring Fuel burning equipment within the state of Colorado is subject to the requirements of Colorado Regulation No. 1, Section III.A. Fuel burning equipment is defined in the Colorado Common Provisions Regulation as "any furnace, boiler, or other equipment and appurtenances thereto, burning fuel solely for the purpose of producing heat, but not including: (1) internal combustion engines, or (2) combustion sources that are a part of a manufacturing process where the emissions are intermixed with the process emissions". The hot oil heaters at the Greeley Natural Gas Processing Plant are, 123/0099 Page 79 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit for the purposes of this regulation, considered to be fuel burning equipment. As such, these heaters are subject to the applicable requirements of Colorado Regulation No. 1, Section III.A. These requirements were included in the operating permit as follows: o This heater shall comply with the Colorado Regulation No. 1, Section III.A.1.b particulate matter limitation of 0.247 lb/MMBtu for P-132, which is based on the design heat input of the heater (15 MMBtu/hr). Compliance with this limitation shall be presumed since only natural gas is permitted to be used as fuel for this heater. It should be noted, however, that this limitation is significantly higher than what the total PM emission factor from AP-42 Chapter 1.4, Table 1.4-2 (dated 7/1998) predicts for natural gas combustion. Because combustion of natural gas results in significantly lower actual emissions of total PM, the Division has determined that compliance with this limit may be presumed at all times, provided natural gas only is used as fuel for this heater. As such, this heater is permitted to use natural gas only as fuel and the source shall demonstrate compliance with this Colorado Regulation No. 1 requirement by maintaining records to verify natural gas only is used. No ongoing numerical compliance demonstration for the Colorado Regulation No.1, Section III.A.1.b. PM limit is necessary. • Condition 4.3— Natural Gas Consumption Limitations & Compliance Monitoring o Moved partitioning calculation from previous Condition 11 to this condition for clarity. o Updated partitioning calculation to account for all fuel users (i.e., the hot oil heaters, engines, pilot gas, etc.) as opposed to the heaters only. This ensures a more accurate allocation of fuel gas consumption among equipment. • Condition 4.4— Natural Gas Heat Content o Added requirement to verify the heat content of the natural gas to be used as fuel for the heater. The heat content of the natural gas is required to perform the partitioning calculation of the fuel gas from the facility-wide meter reading to the individual users. • Condition 4.5 — Hours of Operation o Added requirement to track the hours of operation for the heater, to be made available to the Division upon request. Hours of operation are required to perform the partitioning calculation of the fuel gas from the facility-wide meter reading to the individual users. • It should be noted that this condition contains the requirement to record the hours of operation on the first day of the month, mirroring the engine hours of operation condition. This was done to ensure accurate partitioning among fuel gas users. 123/0099 Page 80 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit • Condition 4.6 — Opacity o Added Colorado Regulation No. 1, Section II.A.4 allowance for emissions of 30% opacity for a limited period during certain operational activities. o Added Colorado Regulation No. 6, Part B, Section II.C.3 requirement to limit particulate matter discharge to 20% opacity or less (State-Only Enforceable) ■ This heater is subject to the Colorado Regulation No. 1 Section II.A.1 20% opacity requirement and the Section II.A.4 30% opacity requirement for certain specific operational activities. The Section II.A.1 20% opacity requirement applies at all times, except for certain specific operating conditions under which the Section II.A.4 30% opacity requirement applies. As fuel burning equipment (see applicability discussion under Condition 4.2 above), the heaters are also subject to the state-only Colorado Regulation No. 6 Part B Section II.C.3 20% opacity requirement. Colorado Regulation No. 6 Part B Section I.A, adopts, by reference, the 40 CFR Part 60 Subpart A general provisions. 40 CFR Part 60 Subpart A§60.11(c) specifies that the opacity requirements are not applicable during periods of startup, shutdown and malfunction. The Colorado Regulation No. 1 Section II.A.1 and II.A.4 20%/30% requirements are more stringent than the Colorado Regulation 6 Part B Section II.C.3 opacity requirements during periods of startup, shutdown and malfunction. However, the Colorado Regulation No. 6 Part B Section II.C.3 20% opacity requirement is more stringent during fire building, cleaning of fire boxes, soot blowing, process modifications and adjustment or occasional cleaning of control equipment. Therefore, since no one opacity requirement is more stringent than the other at all times, all three opacity requirements are included in the operating permit. • Condition 4.7 — Statewide Controls for Oil and Gas Operations At the time of the previous issuance of the operating permit on 5/1/2009, the combustion process adjustment requirements for process heaters of Colorado Regulation No. 7, Part E, Section II.A had not yet been promulgated. These requirements apply to combustion equipment operating in the non-attainment area at a facility considered to be a major source of NOx emissions as of 6/3/2016 under the moderate non-attainment major source threshold of 100 tons/year. The Greeley Natural Gas Processing Plant was a major source of NOx emissions prior to this date. As such, the process heaters at this facility are considered to be affected combustion equipment. Applicable requirements were included as follows: o Section II.A. — This section establishes the requirements for emission limitations, compliance demonstrations, combustion process adjustments, reporting and recordkeeping applying to stationary combustion equipment 123/0099 Page 81 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit located at major sources of NOx. In Section II.A.2., exemptions from the requirements of Section II.A.4. (emission limitations), Section II.A.5. (compliance demonstration), certain parts of Section II.A.7. (recordkeeping) and Section II.A.8. (reporting) are listed. Heater P-132 does not qualify for any of these exemptions. However, heater P-132 is considered to be a process heater for the purposes of Section II.A. Requirements for process heaters do not exist in Sections II.A.4 or II.A.5 and, thus, neither of these sections, nor the associated recordkeeping and reporting apply to this heater. However, process heaters are affected equipment under the combustion process adjustment requirements of Section II.A.6. and the associated recordkeeping under Section II.A.7. Affected operations, pursuant to Section II.A.6.a., include process heaters with greater than or equal to 5 tons/year of actual uncontrolled NOx emissions. Heater P-132 produces uncontrolled actual NOx emissions in excess of this threshold, and is therefore subject to Sections II.A.6. and II.A.7. The requirements set forth in these sections include annual inspection of burner, combustion controls, flame pattern and air to fuel ratio controller, measurement of CO and NOx before and after each adjustment and maintenance of records of any adjustments made pursuant to this section. • Condition 4.8 —40 CFR Part 60 Subpart A NSPS (State-Only Enforceable) Colorado Regulation No. 6 requires compliance with the state-adopted subparts of the federal NSPS rules. Pursuant to the APEN received on 4/30/2015, this heater commenced operation in 1987, which predates the 40 CFR Part 60 Subpart Dc applicability date of 6/9/1989. As such, this heater is not subject to this federal NSPS. However, this heater is subject to the NSPS Subpart A General Provisions, which have been adopted into Colorado Regulation No. 6, Subpart A. It should be noted, however, that these requirements are State-Only Enforceable, since, at a federal level, this heater is not subject to Subpart A because P-132 is not also subject to another NSPS subpart. The Subpart A requirements were included in the permit because they were adopted in Colorado Regulation No. 6 and applicable to any source subject to Colorado Regulation No. 6. These heaters are considered "fuel-burning equipment" pursuant to the Colorado Common Provisions Regulation and are therefore subject to the fuel-burning requirements of Colorado Regulation No. 6, including the particulate matter and opacity standards, which were incorporated into the operating permit (see above). Because P-132 is subject to Colorado Regulation No. 6, the state-adopted requirements of NSPS Subpart A are applicable to this heater and shall be enforced at a state-only level. The requirements included are as follows: • Recordkeeping of startup, shutdown or malfunction events (40 CFR Part 60, Subpart A, §60.7(b), as adopted by reference in Colorado Regulation No. 6) • Good air pollution control practices (40 CFR Part 60, Subpart A, §60.11(d), as adopted by reference in Colorado Regulation No. 6) 123/0099 Page 82 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit • Prohibition of circumvention (40 CFR Part 60, Subpart A, §60.12, as adopted by reference in Colorado Regulation No. 6) • Conditions Removed o APEN submittal requirements • In the previous issuance of this operating permit on 5/1/2009, APEN submittal requirements were included for this heater. This requirement was removed from the permit body as it is covered in the Section IV general requirements of the operating permit. o NSPS Dc Non-applicability • As noted in the operating permit, this heater is not subject to 40 CFR Part 60 Subpart Dc because it was constructed prior to the 6/1/1989 applicability date of this rule. However, this statement of fact is not a permit limitation and has no associated monitoring or compliance demonstration requirements. Typically, statements of fact are included in the technical review document. As such, this condition was removed from the operating permit and was noted in this document (see applicability discussion in Section III above). Condition 5 — P-133 — Fugitive Emissions from Fractionation and Natural Gas Liquids (NGL) Processing Plants, AIRS ID: 114 • Condition 5.1 —VOC Emission Limitations & Compliance Monitoring o Moved component count requirement to separate condition for clarity. o Updated VOC limitation pursuant to the minor modification application received 12/20/2019. o Updated summary table of approved emission factors with the light and heavy liquid factors, in addition to the gas factors, for ease of reference. All factors are from EPA — 453/R 95-017 "EPA's Protocol for Equipment Leak Emission Estimates", Table 2-4. o Summarized component-specific control factors in table for clarity. Note that the controls factors for gas and light liquid were obtained from the Division-standard control factors set forth on the fugitive emissions APEN, for sources subject to NSPS OOOO monitoring (derived from EPA — 453/R 95-017). The APEN does not specify control factors for components in heavy liquid service. As agreed upon in the source comments received 6/3/2020, the control factors set forth in the 5/1/2009 issuance of the operating permit were retained for the components in heavy liquid service. o Added requirement to maintain records of the calculation to be made available to the Division upon request. o Created new reference condition to the facility-wide synthetic minor HAP limitations. With the significant modification received 4/27/2020, the 123/0099 Page 83 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Greeley Natural Gas Processing Plant is now considered to be a synthetic minor source of HAP and requires limitations to ensure the facility retains its area source status under the 40 CFR Part 63 MACT rules. Because these HAP limitations apply on a facility-wide basis, these limits were included in a separate condition within the operating permit and a reference to that Condition 11 was included in this fugitive emissions condition. ■ Note that the HAP calculation for fugitive emissions is nearly identical to the VOC calculation methodology set forth in this fugitive emission condition, but instead of the VOC content obtained from the most recent extended gas analysis, the HAP content obtained from this analysis should be used. • Condition 5.2 — Component Count o Relocated requirements to perform a hard count every 5 years and maintain a running total of components from the VOC limitation condition to this new, separate condition for clarity. o Added requirement to differentiate between components in different services (i.e., gas, light liquid, heavy liquid) to ensure an accurate estimation of fugitive emissions. • Condition 5.3 — Extended Gas Analysis o Added clarification that it is permissible to assume a VOC content of 100% and a HAP content identical to the speciation indicated by the extended gas analysis for components in light or heavy liquid service, as indicated by the emission calculations submitted with the 6/30/2017 minor modification application to update the fugitive equipment emission limitation based on a new extended gas analysis and component count. • For liquid services, it was determined to be permissible to assume the HAP content of the vapor is the same as the HAP content of the liquid. Although the light and heavy liquids should have more HAP than the processed vapor stream, since most HAP constituents are liquid at normal temperatures and pressures, much of the liquid service components at gas plants operate at elevated pressures. Equipment leaks occurring through components at elevated pressure will therefore flash to atmospheric pressure as they are released. This flashed material will most likely have a composition more similar to the gas stream subject to the extended analysis requirement at Greeley, since lighter materials vaporize more easily than heavier ends. A liquids analysis of, for example, pressurized condensate will have a much higher concentration of HAP than what is most likely released into the atmosphere as fugitive emissions throughout the facility, resulting in an artificially high HAP estimation for this point. Therefore, it is considered acceptable to assume the HAP 123/0099 Page 84 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit concentration in the sampled gas stream applies to the components in light and heavy liquid service for the calculation of HAP emissions. o Added requirement to maintain records of the extended gas analysis to be made available to the Division upon request. • Condition 54 — Statewide Controls for Oil and Gas Operations At the time of the previous issuance of the operating permit on 5/1/2009, the fugitive emissions requirements for gas plants of Colorado Regulation No. 7, Part D, Section I had not yet be promulgated. These requirements apply to gas plants operating in the non-attainment area. For the purposes of Colorado Regulation No. 7, Part D, Section I, the Greeley Natural Gas Processing Plant is considered to be a "natural gas processing plant," and, as such, is subject to the requirements of Colorado Regulation No. 7, Part D, Section I.G. These requirements were included in the operating permit as follows: o Section I.G.1. — The LDAR program of NSPS OOOO applies to fugitive equipment leaks, regardless of the date of plant construction. ■ It should be noted that the Greeley Natural Gas Processing Plant was constructed prior to the 8/23/2011 applicability of NSPS OOOO. However, pursuant to this section, this gas plant must comply with NSPS OOOO regardless of the date of construction. The Greeley Natural Gas Processing Plant is subject to NSPS KKK on a federal level, based on the plant's construction date (see Section III of this document). However, since this Section I.G.1 requires compliance with NSPS OOOO, compliance with NSPS KKK shall be presumed for all components, except for compressors, provided the requirements of NSPS OOOO are met. o Section I.G.3. — Compliance with this Section I.G. requirement shall be achieved by 1/1/2019. • Condition 5.5 —40 CFR Part 60 Subpart KKK NSPS o Pursuant to Colorado Regulation No. 7, Part D, Section I.G.1, the Greeley Natural Gas Processing Plant is subject to NSPS OOOO (see Condition 5.4 above). As such, compliance with NSPS KKK is presumed, provided the requirements of NSPS OOOO are met. The operating permit was updated to reflect this presumption. • Condition 5.6 —40 CFR Part 60 Subpart OOOO NSPS The applicable LDAR requirements of NSPS OOOO were incorporated into the operating permit, pursuant to Colorado Regulation No. 7, Part D, Section I.G.1. (see above). It should be noted that as of this permit issuance date of XX/X)(/XXXX, the requirements of Section I.G.1. are both state and federally enforceable. The following applicable requirements were included in the operating permit: 123/0099 Page 85 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit o Good air pollution control practices at all times, including startup, shutdown and malfunction (§60.5370(b)). o Equipment leak standards at natural gas processing plants (§60.5400) o Exceptions to equipment leak standards (§60.5401). o Alternative emission limitation requirements for equipment leak standards (§60.5402). o Continuous compliance demonstration for natural gas processing plants (§60.5415(f)). o Recordkeeping requirements for natural gas processing plants (§60.5421). o Reporting requirements for natural gas processing plants (§60.5422). • Condition 5.7—40 CFR Part 60 Subpart A NSPS o Added references to the Incorporations by Reference (§60.17) and General Notification and Reporting Requirements (§60.19) sections from the NSPS Subpart A General Provisions. These two sections are applicable requirements under NSPS Subpart OOOO. Condition 6 — P-135— Pressurized Product Truck Loadout Rack, AIRS ID: 115 • Condition 6.1 —VOC Emission Limitations & Compliance Monitoring o Updated condition to include specific calculation methodology, in which a specific emission factor for each species is multiplied by the number of trucks loaded each month (assuming a 10,000 gal/truck capacity), pursuant to the significant modification application received 4/27/2020. o Created new reference condition to the facility-wide synthetic minor HAP limitations. With the significant modification received 4/27/2020, the Greeley Natural Gas Processing Plant is now considered to be a synthetic minor source of HAP and requires limitations to ensure the facility retains its area source status under the 40 CFR Part 63 MACT rules. Because these HAP limitations apply on a facility-wide basis, these limits were included in a separate condition within the operating permit and a reference to that Condition 11 was included in this pressurized product truck loadout rack emissions condition. ■ Note that the HAP calculation for the pressurized product truck loadout rack is nearly identical to the VOC calculation methodology set forth in this condition, but instead of the VOC content obtained from the most recent extended liquids analysis for the B-G mix, Y- grade, NGL and condensate, the HAP content obtained from this analysis should be used. Note that propane, butane and isopentane are considered to be pure species and are assumed not to contain contaminant HAP. 123/0099 Page 86 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit • Condition 6.2 —Throughput Limitations & Compliance Monitoring o Separated throughput requirements from the VOC requirements into this new condition for clarity. o Added requirement to monitor truck traffic based on sales or haul tickets, pursuant to source correspondence received on 4/25/2018 and the significant modification application received 4/27/2020. o Included requirement to distinguish between species loaded, to ensure the correct emission factor is utilized for VOC emission limitation calculations. • Condition 6.3 — Extended Liquids Analysis of Loaded Products o Created new condition to perform extended liquids analyses once every 5 years on the B-G mix, Y-grade, NGL and condensate to obtain the appropriate VOC and HAP mass fractions to monitor compliance with the annual limitations. In source comments received 5/22/2020 and 6/3/2020, it was requested that instead of sampling all four species simultaneously, the initial samples be taken roughly once per year, over the next 5 years. Thereafter, subsequent sampling would be conducted every 5 years, based on the date that the previous sample was taken. This request was incorporated into the operating permit. • Condition 6.4 — Maintenance Plan o Removed requirement to develop a maintenance plan within 6 months of permit issuance. Per the 2017 inspection report, the source has developed a maintenance plan based on the requirements of 40 CFR Part 60 Subpart KKK. As such, this one-time requirement has been fulfilled and may be removed from the operating permit. Condition 7 — P-130 — Ethylene Glycol Regeneration Unit, AIRS ID: 111 • This condition was modified significantly to incorporate the requirements set forth in Colorado Construction Permit 15WE0939, which was issued to incorporate the use of control devices for the dehydration unit. The requirements included in the operating permit are addressed in Section V of this document. Condition 8 — FLARE — Plant Flare, AIRS ID: 122 • This condition was created to incorporate the Plant Flare requirements, as permitted under Colorado Construction Permit 15WE0939. These requirements are addressed in Section V of this document. Condition 9 — Exempt Non-Emergency Natural Gas Fired Engines • This condition was created to address the requirements applicable to the APEN exempt non-emergency natural gas fired engines located at the Greeley Natural 123/0099 Page 87 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Gas Processing Plant. These requirements are addressed in Section V of this document. Condition 10— Exempt Non-Emergency Natural Gas Fired Engines • This condition was created to address the requirements applicable to the APEN exempt emergency natural gas fired engine located at the Greeley Natural Gas Processing Plant. These requirements are addressed in Section V of this document. Condition 11 — Facility-Wide Hazardous Air Pollutant (HAP) Emission Limitations Pursuant to the summary table in Section III above, the Greeley Natural Gas Processing Plant is a synthetic minor source of Hazardous Air Pollutants (HAP). As such, synthetic minor HAP limitations were included in the operating permit to ensure that the facility maintains its synthetic minor HAP status for the purposes of MACT applicability. The Division-standard synthetic minor limits of 8 tons/year individual HAP and 20 tons/year total HAP were therefore included in the operating permit. These lower limits (i.e., less than the major source threshold of 10 tons/year individual HAP and 25 tons/year total HAP) allow sufficient buffer for HAP emissions from insignificant activities. It should be noted that the permitted points at the Greeley Natural Gas Processing Plant have a controlled potential to emit below the 8 tons/year individual HAP and 20 tons/year total HAP limitations. As such, insignificant activity tracking is not required for this facility. The requirements associated with the HAP limitation were incorporated as follows: • HAP Emission Limitations & Compliance Monitoring o Included HAP calculation methodology for 4-stroke rich burn engines, using emission factors from EPA's AP-42: Compilation of Emission Factors, Section 3.2, Table 3.2-3 (dated 7/2000), the Division- approved HAP control efficiencies of 76% for formaldehyde and 50% for all other HAP, the monthly natural gas consumption and the natural gas heat content. o Included HAP calculation methodology for natural gas fired heaters, using emission factors from EPA's AP-42: Compilation of Emission Factors, Section 1.4, Table 1.4-3 (dated 7/1998) and the monthly natural gas consumption. o Included reference to the HAP calculation methodology for fugitive emissions, pressurized truck loading and the dehydration unit, which were retained in their respective Section II unit-specific conditions since the calculation of HAP emissions is nearly identical to the VOC calculation set forth in the those conditions. o Included HAP calculation methodology for the plant flare pilot gas, using emission factors from EPA's AP-42: Compilation of Emission 123/0099 Page 88 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Factors, Section 1.4, Table 1.4-3 (dated 7/1998) and the monthly pilot gas throughput. Inserted reference to HAP calculation methodology for purge and waste gas emissions, which were retained in the unit- specific condition, since the calculation of HAP emissions from these streams is nearly identical to the VOC calculation set forth in the plant flare condition. o Added requirements to calculate both individual and total monthly HAP emissions for each point at the facility, to be used in a rolling 12 month total to monitor compliance with the 8 tons/year individual HAP and 20 tons/year total HAP limitations. Condition 12 — Facility-Wide General Conditions This condition was created to address the general requirements from Colorado Regulation No. 7 that apply on a facility-wide basis. Specific conditions were incorporated as follows: • Condition 12.1 — Colorado Regulation No. 7, Part D, Section I.C. General Requirements o Section I.C.1.a. — Air pollution control equipment used to comply with Section I shall be adequately designed and sized for operating scenarios, and shall be maintained pursuant to manufacturer specifications. o Section I.C.1.b. —Condensate collection, storage and handling operations shall be designed to minimize the leakage of VOCs. • Condition 12.2 — Colorado Regulation No. 7, Part D, Section I.G. Natural Gas Processing Plant Requirements o Section I.G.4. — Requirement for natural gas processing plants to comply with the requirements of Section I.G. for fugitive emissions, I.B definitions, I.C. general requirements, I.H. dehydration unit requirements, I.J. compressor requirements and Part E, Section I.A. through C. engine requirements. Note that the actual requirements of the referenced sections were not included within this condition. Instead, these sections were incorporated throughout the permit in the conditions addressing the specific equipment each section pertains to. References to these sections were included in this condition I.G.4 for ease of reference. • Condition 12.3 — Colorado Regulation No. 7, Part D, Section I.J. Compressor Requirements o Section I.J.2.a. — Control requirements, including option on replace the rod packing every 26,000 hours (or 36 months). • Pursuant to source correspondence received on 5/8/2018, the Greeley Natural Gas Processing Plant complies with Section I.J. 123/0099 Page 89 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit by monitoring and replacing the rod packing on their compressors. Therefore, the alternative compliance option of routing all packing vent gases through a closed vent system and all associated recordkeeping (Sections I.J.2.b., I.J.2.c.(i)(D) and (E)) was not included in the operating permit. o Section I.J.2.c. — Recordkeeping requirements, including compressor identification, rod packing monitoring and replacement information. o Section I.J.2.e. — Alternative option to comply with an applicable NSPS standard in lieu of the requirements of Section I.J.2.a. • Condition 12.4 — Colorado Regulation No. 7, Part D, Section II.B. General Requirements (State-Only Enforceable) o Section II.B.1.a. —All intermediate liquid hydrocarbon and produced water operations shall be designed to minimize VOC emissions. o Section II.B.1.b. — All air pollution control equipment shall be maintained and operated consistent with good air pollution control practices. o Section II.B.2.a. — Air pollution control equipment used to comply with Section II shall be adequately designed and sized for operating scenarios, and shall be maintained pursuant to manufacturer specifications. o Section I1.B.2.b. — Combustion devices used to control emissions pursuant to Section II shall be enclosed, have no visible emissions and be designed such that proper operation can be conveniently monitored. o Section II.B.2.d. — Combustion devices used to comply with Section II shall be equipped with an autoigniter. • Condition 12.5 — Colorado Regulation No. 7, Part D, Section V. (State-Only Enforceable) — Inventory Reporting Requirements o Section V.A. — Requirement to submit an annual report including actual emissions and operating information on Division-supplied reporting forms. o Section V.B. — Requirement to include basic identifying information, company-wide monthly actual emissions of NOx, CO, VOC, methane and ethane (for ozone season only; May-September), company-wide annual actual emissions of NOx, CO, VOC, methane and ethane, and a certification of accuracy of the information reported. o Section V.C. — Requirement to submit emissions and calculation information for the source categories listed in this section. The following conditions were removed from the operating permit: • Previous Condition 10 — General Operation 123/0099 Page 90 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit o This condition is exactly encompassed in Colorado Regulation No. 7, Part D, Section II.B.1.b. Therefore, this general operation condition was removed from the operating permit in favor of Colorado Regulation No. 7, Part D, Section II.B.1.b. • Previous Condition 11 — Calculations o This condition had previously been utilized to demonstrate the fuel partitioning calculations required for the engines and heaters. These calculations have been moved into the point-specific conditions for the engines and heaters. These calculations have also been updated to reflect the most current operations at the Greeley Natural Gas Processing Plant. As such, this calculation condition has been removed in its entirety from the operating permit. Section III — Permit Shield • Removed Colorado Regulation No. 6 Part A Shield o The Greeley Natural Gas Processing Plant is subject to the requirements of NSPS Dc, KKK and OOOO. Therefore, the permit shield is not applicable and was removed from the operating permit. • Updated shields pursuant to those requested in the 5/1/2013 operating permit renewal application. For additional details of the shields granted, refer to Section VI of this document. Section IV— General Permit Conditions • Updated the general permit conditions to the most current Division-standard (ver. 1/21/2020) Appendices • Appendix A— Inspection Information o Updated plant directions to refer to Section 25, instead of Section 35. Per the Title V Renewal Application received on 5/1/2013, the Greeley Natural Gas Processing Plant is located in Section 25. o Inserted most recent plot plan, received with the 5/2/2016 significant modification application. o Updated list of insignificant activities, pursuant to the specific activities identified in the updated insignificant activity list received on 5/31/2018. • It should be noted that many of these insignificant activities are required to have documentation supporting the applicability of the exemption claimed, pursuant to Colorado Regulation No. 3, Part C, Section II.E. These activities are marked with an asterisk (*) in the operating permit. 123/0099 Page 91 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit • The 5/31/2018 insignificant activities list designated the Compressor Blowdown activities under the Colorado Regulation No. 3, Part C, Section II.E.3.bbb. exemption of "venting of compressed natural gas, butane or propane gas cylinders, with a capacity of one gallon or less." Compressor blowdowns are typically significantly in excess of a one gallon volume. Pursuant to the emissions inventory reported on the insignificant activity list, these blowdowns result in 0.15 tons/year VOC emissions. As such, the compressor blowdowns were exempted in the operating permit under Colorado Regulation No. 3, Part C, Section II.E.3.a. for activities resulting in emissions of less than 1 ton/year VOC for sources located in areas of ozone non-attainment. • The 5/31/2018 insignificant activities list did not list an exemption for the CIG Line Blowdown. Pursuant to the emission inventory reported on the insignificant activities list, this activity results in VOC emissions of 0.29 tons/year.As such, the CIG Line Blowdown was exempted in the operating permit under Colorado Regulation No. 3, Part C, Section II.E.3.a. for activities resulting in emissions of less than 1 ton/year VOC for sources located in areas of ozone non-attainment. • The 5/31/2018 insignificant activities list designated the two 80 bbl produced water tanks S-1086 and S-1089 as exempted under the provisions of Colorado Regulation No. 3, Part C, Section II.E.3.uu., for produced water tanks containing less than 1% by volume annual average crude oil. In the 2/14/2020 promulgation of Colorado Regulation No. 3, this exemption was removed. However, based on the emissions calculated for these tanks listed in the 5/31/2018 insignificant activities list, total emissions from both tanks in aggregate are 0.49 tons/year VOC. As such, these tanks do not exceed the APEN reporting threshold of 1 ton/year for sources of VOC emissions located in the ozone non-attainment area and retain their qualification as insignificant activities pursuant to Colorado Regulation No. 3, Part C, Section II.E.3.a. This reference was updated in the operating permit. • It should be noted that Colorado Regulation No. 7, Part D, Section II.C.1.c. requires control devices for storage tanks with uncontrolled actual emissions of VOC greater than or equal to 2 tons/year. Pursuant to the insignificant activities summary provided on 5/31/2018, all listed storage tanks in aggregate produce VOC emissions of 0.63 tons/year. As such, at the time of permit issuance on XX/XX/XXXX, these tanks are not subject to the requirements of Colorado Regulation No. 7, Part D, Section II.C.1.c. • The engines listed in the 5/31/2018 insignificant activities list were not included in the insignificant activities list in Appendix A of the operating permit. Although these engines meet the insignificant 123/0099 Page 92 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit activity criterion of Colorado Regulation No. 3, Part C, Section II.E.3.nnn.(iii) by having "uncontrolled actual emissions less than five tons per year or manufacturer's site-rated horsepower of less than fifty', they cannot be considered to be an insignificant activity pursuant to Section II.E., which prohibits such exemptions from being taken if a federal or state rule would be avoided by taking that exemption. Each engine is an existing SI 4SRB engine located at an area source of HAP emissions, and is therefore subject to 40 CFR 63 Subpart ZZZZ, as discussed in Section III above. Because these engines are subject to requirements in a federal rule, the insignificant activity exemption cannot be taken. As such, the applicable MACT ZZZZ requirements were incorporated into the body of the operating permit for these engines, as discussed in Section V above. ■ Pursuant to source correspondence received 4/25/2018, the following corrections were made to the insignificant activities list: • Updated service for 30,000 gallon methanol storage tank. This tank stores natural gasoline, not methanol. • Appendix B — Monitoring and Permit Deviation Reports o Updated monitoring and permit deviation reports to the most current Division-standard (ver. 8/20/2014) • Appendix C — Compliance Certification Reports o Updated compliance certification reports to the most current Division- standard (ver. 8/20/2014) • Appendix D — Notification Addresses o Updated addresses to the most current Division-standard (ver. 1/27/2020) • Appendix F — Permit Modifications o Cleared table of previous modifications • Appendix G — Compliance Assurance Monitoring o Added C-123 to the list of affected units under the "Emission Unit Description". Per the most recent emission inventory, uncontrolled potential emissions of NOx for Engine C-123 are in excess of the major source threshold of 50 tons/year.As such, CAM is required for this engine. o Removed references to the CO emission limitation for the purposes of CAM. All engines have uncontrolled potential CO emissions below the major source threshold of 100 tons/year. As such, the CO emission limitations for these engines are not subject to CAM. 123/0099 Page 93 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit o Updated "Applicable Regulation, Emission Limit and Monitoring Requirements" to reflect the updated emission limitation all engines modified during the previous permit term, and to add the affected emission limitation for C-123. o Added requirement to maintain records of any shutdowns resulting from a high catalyst inlet temperature excursion, to ensure records for each applicable CAM requirement are maintained. o Explicitly stated requirements to maintain records of the daily catalyst inlet temperature and monthly catalyst pressure drop and to make these records available to the Division upon request. o Supplemented CAM condition with the required "Justification" section. This summary includes a listing of the indicators chosen, an explanation of how each indicator is related to emission control device performance, and a rationale of the ranges for each indicator selected. • Appendix H —Applicability Reports o Updated AOS applicability reports to the most current Division-standard (ver. 10/12/2012 w/ updated web links and Colorado Regulation No. 3 citations from 2014). VIII. STREAMLINING OF APPLICABLE REQUIREMENTS This section addresses the conditions streamlined from this permit: • Colorado Regulation No. 6, Part B, Section II.C.2 The Colorado Regulation No. 6, Part B, Section II.C.2 requirement has been streamlined out in favor of Colorado Regulation No. 1, Section III.A.1.b. These requirements set forth the equation to calculate allowable particulate emissions for fuel burning equipment generating between 1 MMBtu/hr and 250 MMBtu/hr. Since Colorado Regulation No. 1 is federally enforceable, and Colorado Regulation No. 6 is state-only enforceable, the state-only enforceable requirement has been streamlined out in favor of the federally enforceable requirement. This requirement is applicable to heaters P-132 and P-139, which are considered fuel burning equipment pursuant to the Colorado Regulation Common Provisions. • 40 CFR Part 60 Subpart Dc §60.48c(i) The NSPS Dc requirement to maintain records for a period of 2 years only has been streamlined out of the operating permit, in favor of the more stringent Title V operating permit records retention requirement of 5 years, as required by Colorado Regulation No. 3. Because the five year retention period is more stringent than the NSPS Dc 2 year requirement, §60.48c(i) of NSPS Dc was streamlined out in favor of the 5 year requirement from Colorado Regulation No. 3, Part A, Section II and Part C, Sections V.C.6 and V.C.7. 123/0099 Page 94 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit IX. FACILITY-WIDE EMISSION SUMMARY Controlled Emissions(tons/year) Uncontrolled Emissions(tons/year) AIRS ID Facility ID Source Fugitive Reportable Fugitive Reportable NOx CO VOC VOC HAP NOx CO VOC VOC HAP 102 C-124 Compressor Engine 3.02 4.22 -- -- -- 9.58 16.13 -- -- 103 C-116 Compressor Engine 24.00 26.55 5.31 -- 0.26 138.09 95.60 5.31 -- 0.96 104 C-117 Compressor Engine 24.00 26.55 5.31 -- 0.26 138.09 95.60 5.31 -- 0.96 105 C-118 Compressor Engine 24.00 26.55 5.31 -- 0.26 138.09 95.60 5.31 -- 0.96 106 C-119 Compressor Engine 21.24 26.55 5.31 -- 0.26 138.09 95.60 5.31 -- 0.96 107 C-120 Compressor Engine 24.00 26.55 5.31 -- 0.26 138.09 95.60 5.31 -- 0.96 108 C-123 Compressor Engine 8.65 17.30 4.33 -- 0.16 112.48 77.87 4.33 -- 0.68 109 C-152 Compressor Engine 21.24 26.55 5.31 -- 0.26 138.09 95.60 5.31 -- 0.96 110 C-122 Compressor Engine 24.00 26.55 5.31 -- 0.26 138.09 95.60 5.31 -- 0.96 111 P-130 EG Dehydration Unit -- -- 0.20 -- 0.05 -- -- 6.45 -- 0.48 113 P-132 Hot Oil Heater 6.32 5.31 -- -- -- 6.32 5.31 - 114 P-133 Fugitive Equipment Leaks -- -- -- 10.34 0.49 -- -- 112.24 5.39 115 P-135 Pressurized Truck Loadout -- -- 43.15 -- 7.93 -- 43.15 -- 7.93 120 P-139 Hot Oil Heater 14.64 12.30 -- -- 0.26 14.64 12.30 -- -- 0.26 122 Flare Plant Flare 2.58 11.35 19.83 -- 0.41 2.58 11.35 396.50 -- 8.26 Total Permitted Facility Emissions(tons/year) 197.69 236.33 104.68 10.34 11.16 1112.23 792.16 487.60 112.24 29.76 123/0099 Page 95 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Uncontrolled HAP Emissions (Reportable) Calculated Reportable HAP Uncontrolled Emissions(tons/year) AIRS ID Facility ID Source n- 2,2,4- Ethyl Acetaldehyde Acrolein Methanol Formaldehyde Benzene Toluene Xylenes Hexane TMP benzene 102 C-124 Compressor Engine -- -- -- - 103 C-116 Compressor Engine -- -- 0.13 0.84 -- -- -- -- -- -- 104 C-117 Compressor Engine -- -- 0.13 0.84 -- -- - 105 C-118 Compressor Engine -- -- 0.13 0.84 -- - 106 C-119 Compressor Engine -- -- 0.13 0.84 -- -- -- -- -- -- 107 C-120 Compressor Engine -- -- 0.13 0.84 -- -- -- -- -- -- 108 C-123 Compressor Engine -- -- -- 0.68 -- -- -- -- -- -- 109 C-152 Compressor Engine -- -- 0.13 0.84 -- -- -- -- -- -- 110 C-122 Compressor Engine -- -- 0.13 0.84• -- -- -- -- -- -- 111 P-130 EG Dehydration Unit -- -- -- -- -- -- 0.48 -- -- -- 113 P-132 Hot Oil Heater -- -- -- -- -- -- -- -- -- -- 114 P-133 Fugitive Equipment Leaks -- -- -- -- 3.59 -- 0.68 0.90 -- 0.22 115 P-135 Pressurized Truck Loadout -- -- -- -- 6.41 0.15 0.84 0.53 -- -- 120 P-139 Hot Oil Heater -- -- -- -- 0.26 -- -- -- -- -- 122 Flare Plant Flare -- -- -- -- 5.87 -- 1.19 1.02 -- 0.19 Total Permitted Facility Emissions(tons/year) 0.00 0.00 0.88 6.56 16.13 0.15 3.18 2.45 0.00 0.41 123/0099 Page 96 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document-Renewal Operating Permit Controlled HAP Emissions (Reportable) Calculated Reportable HAP Controlled Emissions(tons/year) AIRS ID Facility ID Source n- 2,2,4- Ethyl Acetaldehyde Acrolein Methanol Formaldehyde Benzene Toluene Xylenes Hexane TMP benzene 102 C-124 Compressor Engine -- -- -- -- -- -- -- -- -- _ 103 C416 Compressor Engine -- -- 0.06 0.20 -- -- -- -- -- -- 104 C417 Compressor Engine -- -- 0.06 0.20 -- -- -- -- -- -- 105 C418 Compressor Engine -- -- 0.06 0.20 106 C419 Compressor Engine -- -- 0.06 0.20 -- -- -- -- -- -- 107 C420 Compressor Engine -- -- 0.06 0.20 -- -- -- -- -- -- 108 C-123 Compressor Engine -- -- -- 0.16 -- -- -- -- -- -- 109 C-152 Compressor Engine -- -- 0.06 0.20 -- -- -- -- -- -- 110 C422 Compressor Engine -- -- 0.06 0.20 -- -- -- -- 111 P-130 EG Dehydration Unit -- -- -- -- -- -- 0.05 -- 113 P-132 Hot Oil Heater -- -- -- -- -- -- -- -- -- -- 114 P-133 Fugitive Equipment Leaks -- -- -- -- 0.33 -- 0.06 0.08 -- 0.02 115 P-135 Pressurized Truck Loadout -- -- -- -- 6.41 0.15 0.84 0.52 120 P-139 Hot Oil Heater -- -- -- -- 0.26 -- -- -- 122 Flare Plant Flare -- -- -- -- 0.29 -- 0.06 0.05 -- 0.01 Total Permitted Facility Emissions(tons/year) 0.00 0.00 0.44 1.57 7.30 0.15 1.01 0.65 0.00 0.03 2018 Actual Facility Emissions(tons/year) 0.00 0.00 0.00 1.39 0.72 0.00 0.02 0.00 0.00 0.00 123/0099 Page 97 of 98 DCP Operating Company, LP—Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Technical Review Document—Renewal Operating Permit Information Relied Upon Facility ID Information Source APEN rec'd 4/28/2017;mfg.EF's for NOx,CO,VOC;uncontrolled HAP EF's from AP-42 Table 3.2-3;69%CE for NOx,74%CE for CO;0%CE for VOC;76%CE for CH2O; C-124 50%CE for HAP C-116 APEN rec'd 5/15/2020;mfg.EF's for NOx,CO,VOC;uncontrolled HAP EF's from AP-42 Table 3.2-3;83%CE for NOx,72%CE for CO;0%CE for VOC;76%CE for CH2O; 50%CE for HAP C-117 APEN rec'd 12/20/2019;mfg.EF's for NOx,CO,VOC;uncontrolled HAP EF's from AP-42 Table 3.2-3;83%CE for NOx,72%CE for CO;0%CE for VOC;76%CE for CH2O; 50%CE for HAP C-118 APEN rec'd 12/20/2019;mfg.EF's for NOx,CO,VOC;uncontrolled HAP EF's from AP-42 Table 3.2-3;83%CE for NOx,72%CE for CO;0%CE for VOC;76%CE for CH2O; 50%CE for HAP C-119 APEN rec'd 4/28/2017;mfg.EF's for NOx,CO,VOC;uncontrolled HAP EF's from AP-42 Table 3.2-3;85%CE for NOx,72%CE for CO;0%CE for VOC;76%CE for CH2O; 50%CE for HAP C-120 APEN rec'd 12/20/2019;mfg.EF's for NOx,CO,VOC;uncontrolled HAP EF's from AP-42 Table 3.2-3;83%CE for NOx,72%CE for CO;0%CE for VOC;76%CE for CH2O; 50%CE for HAP APEN reed 12/21/2018;mfg.EF's for NOx,CO,VOC;uncontrolled HAP EF's from AP-42 Table 3.2-3;92%CE for NOx,78%CE for CO;0%CE for VOC;76%CE for CH2O; C-123 50%CE for HAP C-152 APEN rec'd 4/28/2017;mfg.EF's for NOx,CO,VOC;uncontrolled HAP EF's from AP-42 Table 3.2-3;85%CE for NOx,72%CE for CO;0%CE for VOC;76%CE for CH2O; 50%CE for HAP C-122 APEN rec'd 12/20/2019;mfg.EF's for NOx,CO,VOC;uncontrolled HAP EF's from AP-42 Table 3.2-3;83%CE for NOx,72%CE for CO;0%CE for VOC;76%CE for CH2O; 50%CE for HAP P-130 APEN rec'd 4/28/2017;composition based on 12/19/2014 sample;emissions based on 5/2/2016 significant modification application P-132 APEN rec'd 4/30/2015;NOx and CO EF's from AP-42 Table 1.4-1;VOC,PM and 5O2 EF's from AP-42 Table 1.4-2;HAP EF's from AP-42 Table 1.4-3 Fugitives APEN rec'd 12/20/2019;composition based on 11/19/2018 sample;emissions based on 12/20/2019 minor modification application P-135 APEN rec'd 12/20/2019;emissions based on 4/27/2020 significant modification application P-139 APEN rec'd 12/2/2013;NOx and CO EF's from AP-42 Table 1.4-1;VOC,PM and SO2 EF's from AP-42 Table 1.4-2;HAP EF's from AP-42 Table 1.4-3 APEN rec'd 12/15/2015;NOx and CO EF's from AP-42 Table 1.4-1;VOC,PM and SO2 EF's from AP-42 Table 1.4-2;HAP EF's from AP-42 Table 1.4-3;waste gas Flare composition based on 12/19/2014 sample;waste gas NOx and CO EF's from AP-42 Table 13.5-1 and 13.5-2;emissions based on 5/2/2016 significant modification application&source comments received 5/22/2020 123/0099 Page 98 of 98 dr� DCP Midstream 7th St.,Suite 2500 �s Denver,CO 80202 '> Midstream. am. (303)605.2039 Val trG www.dcpmidstream.com April 24, 2020 Via UPS: 1Z F46 915 02 9210 8013 Colorado Department of Public Health and Environment Air Pollution Control Division ATTN: Elie Chavez 4300 Cherry Creek Drive South Denver. CO 80246-1530 Re: Greeley Natural Gas Processing Plant Title V Modification: 95OPWE038 AIRS ID 123/0099 Dear Ms. Chavez • DCP Operating Company, LP (DCP) is submitting the attached minor modification application for the Greeley Natural Gas Processing Plant (Greeley), located at Section 25, Range 66W, Township 5N in Weld County, Colorado. This facility currently operates under Title V permit 95OPWE038 originally issued on May 1, 1999. A minor modification package was submitted for the facility in December 2019 that included some of the changes discussed below. However, the specific revisions requested in this package were determined to require a significant modification, rather than a minor modification. DCP has included the APEN forms provided with the December 2019 minor modification application, but is not resubmitting supporting emission calculations, per Division request. Summary of Changes I. Waukesha L-7042 GSI Compressor Engines C116, C117. C118. C120. C 122 (AIRS 103, 104, 105, 107, 110) DCP is requesting a decrease in the NOY emission limits and corresponding compliance emission factors for the above-listed five compressor engines. DCP has previously submitted summaries of 2019 quarterly portable analyzer results in support of the requested emission limit decreases. DCP is requesting these reduced emission limits to ensure that N0x emissions from each unit are permitted below NA-NSR Major Modification significance levels,and that this facility can continue to perform permanent engine replacements under the Alternative Operating Scenarios (AOS) provisions detailed in Section 1.0, Condition 2.0 of Title V Operating Permit 95OPWE038 following the reclassification of the Colorado ozone non-attainment area from moderate to serious. • � 1 Additionally, DCP is requesting that the serial numbers listed for engines Cl 17 and C120 (AIRS 104 and 107) be updated to reflect permanent engine replacements that occurred on May 8, 2019 and November 19, 2018. respectively. 2. Pressurized Product Truck Loadout Rack P135 (AIRS 115) DCP has recalculated the VOC emission factors for the various products loaded and unloaded using this equipment and determined that Condensate (rather than B-G Mix) provides more conservative VOC and HAP emission profiles. DCP is requesting redlines to the Title V permit reflecting this updated calculation methodology, as well as including speciated I IAP emissions for this source. Additionally, DCP would like to update the throughput limit for this source to reflect individual truck loading and unloading events. rather than a combined throughput calculated in MMgaI/yr. The above changes, while requiring updates to the Title V permit as well as a slight decrease in the annual throughput limit. don't require any changes to the underlying emission limits for this source. This source will continue to operate under the current VOC emission limit of 43.15 tpy (uncontrolled). These changes require a decreased liquids throughput limit from 560 MMgal/yr to 557 MMgal/yr(conservatively based on 100% condensate throughput). DCP is also requesting a throughput limit unit conversion from MMgal to loadout events (557 MMgal/yr updated to 55,714 loadout events /yr at 10,000 gal/event). The updated calculation methodology, and a review of actual rolling 12-month throughput values indicate these existing limits are still representative of potential activity at this source. Reeulatory Analysis There are no changes in regulatory applicability for the live compressor engines listed above based on the requested decreased emission limits. DCP will continue to comply with all applicable state and federal requirements for these engines. There arc no changes in regulatory applicability for the pressurized product truck loadout rack based on the proposed updates to the emissions calculation methodology. DCP will continue to comply with all applicable state and federal requirements for this source. Attachments We are including the 100 series Title V forms pertaining to the facility,as well as forms specific, as well as forms specific to each emission unit and stack, where applicable. The list of the most recent APENs that have been submitted for the facility has been updated (form 102A)and copies of the relevant APE forms from the December 2019 submission have been included. Emission calculations and supporting documentation were included in the previous submission for these engines and have not been resubmitted with this package. There has been a change in the calculations for the pressurized product truck loadout rack since the December submission based on Division feedback. The revised calculations are being submitted with this package. , As appropriate we are including forms 200 (stack). 300 series (emission unit), 600 (emission unit HAPs). 601 (emission unit criteria pollutants). 604(applicable requirements), 606 (compliance certification), and a form 700 (to provide information regarding compliance methods). Only applicable requirements that are being revised are shown on form 604. Facility-wide HAP and criteria pollutant forms have also been included (forms 602 and 603)and well as the necessary signed certification forms (800 series). The insignificant activities list for the facility has been updated. The following attachments needed to make the requested changes to operating permit 950PWE038 have been included: • Attachment A: Updated PI35 Emission Calculations & Form APCD-102 • Attachment B: Operating Permit Forms • Attachment C: Plot Plan • Attachment D: December 2019 minor modification APEN forms If you have any questions or require any additional information about this submittal, please contact me at (303) 605-2039 or rhankaran@dcpmidstream.com. Sincerely. • DCP Operating Company, LP Roshini Shankaran Senior Environmental Engineer Attachment A: Updated P135 Emission Calculations & Form APCD-102 Greeley Natural Gas Processing Plant PRESSURIZED TRUCK LOADOUT EMISSIONS(P135) Greeley Natural Gas Plant DCP Operating Company,LP Calculation of Potential VOC Emissions from Propane,Butane,B-G Mix,Y-Grade,Isopentane,Natural Gasoline and Condensate Truck Loading Losses Assumptions: There are two hoses connected to each truck during loadout. liquid Hose Diameter e 2 0 Inches Vapor Hose Diameter = 2 0 Inches Liquid Hose Length _ 1 5 feet Vapor Hose Length 2.0 feet liquid Hose volume . 0.0327 cubic(eel Vapor Hose Volume 0 0436 cubic feet Each truck is pressurized to storage tank pressure as listed below. Propane Tank Pressure= 704 4 psia Butane Tank Pressure - 57 4 psra B-G Mei Tank Pressure= 21 4 psia V-Grade Tank Pressure= 212 4 psi.) Isopentane Tank Pressure= 21 4 psra Natural Gasoline Tank Pressure 22 4 psia Condensate Tank Pressure= 52.4 psia Tot.volume of products loaded/year and tot.loadout events/year as listed below. Product loads/yr bbl/yr gal/yr Propane loaded Out 7.215 1,717,857 72,150.000 Butane loaded Out 6.391 1,521.667 63.910:000 B-G Mil,loaded In 1 787 425,476 17,870,000 Y Grade loaded In 4.675 1,113,095 46,750.000 Isopentane Loaded Out 976 132,381 9,760.000 Natural Gasoline Loaded Out 1.908 692,381 29.080.000 Condensate Loaded Out 611 145,476 6,110 000 Total loads/yr(Max Annual) 24,563 5.848,333 245.630.000 Potential loads/yr' 55,718 13,266,125 557,177,250 Anru.rr rr_ror455r,,r 1&t/u'l IpJ4>7ye'inner g.lkrmj.caa'Ig-diem/47 hhI MA.annual Dr,+dolt throughput Ii,ydqyrl tep,eoen1 ma•vnum rot ng-I1 rimruu l,put :g s/s VI, 'Pa,,.u,,.r 'ep'roents m Jxunun±patenl,al loadcwt e,ents under rerjn,ed Vrrf emrsvon nrv,d 0,91 I,rpy • All liquid lines contain liquid products at individual specific gravity All vapor return lines contain products that behave as Ideal Gases at 60 deg.F and storage tank press P'V -n•R•T Where P=pressure in hose at time of disconnect=storage tank pressure(pug) v=volume of hoses(cubic feetl n,number of lb-moles of product in hoses R=Universal Gas Constant=10 73 cubic feet•par/lbmol•deg R T>ave loadout temp - 60 deg F = 519 67 deg R Propane: n- 0.0367 Ibmol/ft'•44 Ib/Ibmol = 1 6127 18/111 Butane: n= 0 0103 Ibmol/fl'.58 Ib/Ibmol = 0.5968 lb/fr' 8-G Mix: n= 0.0040 Ibmol/fC•58 lb/lbrnol= 0.2328 Ib/ft' V Grade n= 0.0381 Ibmol/ft' 11 l lb/Ibmol, 04609 lb/ft' Isopentane n= 00040 Ibmol/It''717 lb/tbmoi= 01878 lb/ft' Natural Gasoline. n= 0.0040 Ibmol/ft'•73 5 Ib/Ibmol= 0.2950 lb/It' Condensate n= 0 0094 Ibmol/ft'•94 1 Ib/Ibmol= 0 8840 lb/ft' Potential VOC Emissions(Loading and Unloading) Liquid Hoses Vapor Hoses Total Emission Annual Liq.Density Hose Vol. imission Factor Vap.Density Hose Vol. Emission Factors Factors Emissions' Product (Ib/h') (ft) lb/load (lb/Ft') (ft') lb/load lb/load tpy Propane 31.78 0.0327 1.04 16121 00436 0.07 111 0.00 Butane 36.20 0 0327 1.18 0.5968 0 0436 0.03 1.11 000 J 8-G MIX 46.15 00327 1.51 0.2323 00436 0.01 1.52 0.00 Y'Grade 46,15 00327 151 04009 00436 002 153 000 Isopentane 3897 00327 128 0.2878 0.0436 0.01 179 0.00 Natwal Gasoline liquids(N611 4615 00327 151 02950 00436 001 152 000 Condensate 46.15 0.0327 1.51 0.8840 0 0436 0 X04 1 55 43.15 Total; 43.15 4 In oi9ri lo e,nrmr Phe moil[onset a1,nr n.h mate or potential 1,a„nn rmM on,.all th,oughout was.,fumed to be C4,a atr.n INC 1.- ,ern,,,,nn cakula,nn, Potential HAP Emissions(Loading and Unloading) Emission Factors Emissions HAP wt%s (lb/load) (Ib/yr) HAP Natural Gasoline n-Hexane 15.04'% 2.30E-01 12826 Benzene 197% 30IE 02 1679 Toluene 1 23% 1.88E-02 1047 Ethylbenuene 0.03% 4 85604 27 xylene _ 0 16% 2 47E 03 138 2,2,4-Trimelhylpentane 0.35% 5 391 03 300 Methanol 0001% 1.84E-05 10 Total HAPs 0.29 16,018 1/:5/7919 Pill P..enJrd iva.,7 n,.1,.,, Colorado Department of Public Health and Environment r Form APC'D-102 I Air Pollution Control Division C D P H E Facility Wide Emissions Inventory Fortn � Vcr.April,2015 't:://, Company Name:DCI'Operulinp Company,LP 74 iti, Source Name:Greeley Gas Pala Source AIRS ID:123/0009 Uoco,Dolled Pctenlinl to F; '(P1'0:) Controlled Putenllul to Emil(1"1'14) Criteria 0190Y) I OAP)150y)10.0Csilerin(1'Y)) I OAPs(109/yr) MRS ID Equipment Deseriplion ESE P5410 P312.5 SO2 5501 WC (70 1 DOR) Acelol Acre Bt TO E0 X51 n-Iles :SEelb 224-'1'511' 151. P0518 P113.5 502 H11x 4'0(' CO I IRMO Metal Arm BE I Tut ER ' Xyl n-Ilee Ale. 124.10P I..—12970099%lOJ 59001,0(-IIMp-i^^- 079 0'19 019 (1 U: 11809 6..1) 1$60 1617 728 ZIS 104 4lr IG II :515. B G19 IJ10 0 7 002 24 110 531 2459 I 403 114 108 65 3;1 8 0 125 0 123(0099:104 b0l,e C-I I711'-I21 079 070 Ott 00' 13809 511 0340 1677 228 215 IM 46 2 16 0 250. 0 070 070 0.70 002 2400 5.11 20551 co4 III 108 65 21 8 0 125 (I 121!0099!105 Istone Csl18a•-ILI 0.79 079 079 002 13809 5.31 9500 1,677 228 015 129 40 2 16 0 250 0 0 —.79 070 079 002 240D 5.31 16.55 I 403 114 108 65 23 8 0 125 0 1230090/06 rnou.C 11A'P-125 079 079 0.79 002 13809 5.31 9560 1,677 278 215 129 46 7 16 0 250 0 079 079 079 0.02 21.24 5.31 24.55 I 403 114 - 109 65 23 8 0 125 0 12110090/07 EOg10u C-12'(09.170 079 079 019 002 13804 511 9560 1677 228 215 129 46 2 In _I 0 250 0 079 079 079 072 2400 531 2655 403 114 108 65 11 8 0 125 0 12]/0019210 E0,0C-12219-129 079 077 079 007 11809 531 0560 1.677 228 215 120 44 2 16 0 250 0 079 079 079 0 -02 2400 511 26.55 7 407 114 108 65 21 8 0 125 0 125/0097/108 pnpne C-12119-127 040 Otis 045 002 11248 4.07 '1707 7.004 186 175 103 37 2 13 0 204 0 065 11.65 065 002 865 433 17301 328 93 38 51 17 - IJ 0 204 0 1M/0107/102 Engine C-124/9-121 008 fi Utl 008 _00(1 958 061 16.11 IJS 34 23 14 5 0 2 0 27 I 0 008 008 008 0OD 102 040 422 40 12 11 7 2 0 I 0 13 0 121/0099/109 Engine(6152/P228 079 0 7 11.79 002 1:3809 931 95.60 1070 228 215 129 46 2 10 0 200 0 0.79 0.79 079 007 2124 5.11 26.55 7 400 114 108 65 11 1 16 0 125 0 123/0099/111 PI30 00 Dehydmlm 0.00 000 0.00 0.00 000 9.75 0,00 0 0 0 953 46 2 32 48 0 0 000 0.00 000 0.00 0.14 02(1 071 ; 11 n 0 101 5 0 4 E 0 Il 121!0099/113 1'142/1101 nil heater 041 0.48 0.44 004 6.32 0.15 541 0 0 0 0 0 0 0 227 0 0 0.48 048 048 004 612 0.15 5.11 I 9 0 0 0 0 0 0 227 0 0 I23/0099/1 20 P1344,105(01 H per 1.11 1.11 1.11 009 ]444 08) 1290 22 II 0 I 0 0 1,. 0 0 I U 0 0 527 0 0 n 527 0 0 1 II 1.11 III 0,09 14.64 OM 113 22 173/00990 IT PIJ5R exed neck t eOI, 000 000 000 000 000 43 IS 000 0 0 0 1.909 30 27 718 1.,826 I 300 0011 011D 000 0.00 000 4}13 000 41 + I 0 0 0 0:679.' 1,01'0 2'7 1,18 12,826 I 100 12700099/114 Fugitives 000 0.00 0.00 000 000 112.24 BOO 0 0 0 1.152 1,807 47 447 7.176 9 12 000 000 000 000 1100 10.14 000 I 0 0 0 125 100 4 4I 661 1 121/0099/122 Flare 0.01 0.01 0,01 000 262 19049 036 0 0 0 2,179 2049 12 172 11,746 0 0 0.01 0.01 001 000 2.02 19,82 11.36• 0 0 0 119 102 s 2 14 587 0 0 rr Yerm10m1 Sources Subtotal- 7.9 7.9 7.9 0.4 1112.8 601.6 192.1 I 18,314 1,8118 1,704 7,387 5,311 125 1,115 32,50 1,992 312 7.9 1.9 1.9 0.3 197.4 116.8 237.1 I 1,217 904 851 2,537 1,520 42 279 14,831 1,095 332 APES Only-Permit Exempt Sources 1 I C I AVER Only Sabl91a1= 0.0 0,0 0.0 0.0 0,0 0.0 0.0 0 0 0 0 0 0 0 0 0 0 0.0 0,11 0.0 0.0 ILO 0.0 0,0 I 0 0 0 0 0 0 0 0 0 0 APES Eamp,/imignill6.l sole rtes hsogni0cgnt AcOsniea 00 00 00 00 68 109 52 O0 O -_- ....._.0--_ 0 0 0 21 0 0 0 152 273 U 00U 00 6.9 10.7 5.2 0 0 U 21 0 0 0 IS[ 173 0 MAWS..59619121— 00 0.0 0.0' 00 6.8 111,9 5.2 0 11 0 21 0 0 0 182 273 0 0.0 0.0 0.11 0.0 6.8 111.9 5.2 0 0 0 21 0 0 0 152 273 0 Tn0a1,All Sources=I 7,9 I 7.9 I 1.9 I 0.3 11119,1 1012.51 791.3 8 13,314 I 1.808 11,704 17,408 15,3111 115 11,115 112,103 I 2,765 I 312 11.9 I 7.9 I 7.9 10.3 1204.1 1127.1 1242.3 3,219 I 9114 I 852 12,558 11,520 142 I 279 i 14,9831 7,368 I 302 Uncer,IrolleJ HAP'Summary(TPY)`I 6,7 I 0.9 I 0.9 I 37 I 2.7 I 0.1 I 0.6 I_ 16.4 I 1.1 I 0,2 renlralledllol's Senmmry(TI'Y)—I 1.6 I 0.5 I 04 I 1,3 I 0.8 I Ito I o.1 I 7.5 I 0.7 I 0.2 Uncontrolled Totol,All IIAYs Fr FIX)=l 33.0 I Control,.2 I,,:,All DAMN Er I'll A 13.0 I POuln0tex: 1.This form.should he completed to include both existing snout's and all proposed new 0r modifications to existing emissions sources 2 If the emissions 000100 is new then enter"proposed"under the Permit No.and AIRS ID data columns 3.HAP abbreviations include' DL=Benzene 224-TMP=2 Z 4-Trimelhylpentane Tot=Toluene Metal=Acetaldehyde ES-Ethylbeozenc Aces—Acrolein Xyl=Xylene 8-11ex—o-Hcganc HCHO=Formaldehyde Meth=Methanol 4.APrN Exempt/Insignificant Sources should be included when warranted. DCP operating company,LP 3/15/2020 Page 1 of 1 )peraungl'cnniiApplica0.,n FAC11.FfV IDENTIFICATION FORM 2000-100 ('olorado Dcp:umtcnt of PublIL I lealth and I n uunment R.,' 06.95 An Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name and Name Greeley Natural Gas Processing Plant mailing address Street or Route PO Box 5493 City,State,lip Code Denver,CO 80217 2.. Facility location Street Address 3009 West 44'h Avenue (No P.O. Box) City,County,Zip Code Greeley,Weld County,CO 3, Parent corporation Name DCP Operating Company, LP Street or Route 370 17th Street,Suite 2500 City,State,Zip Code Denver,CO 80202 Country(if no( 11.S.) 4. Responsible Name 'fauna Rignall official Title General Manager, North Area Operations Telephone 970-352-3104 5. Permit contact person Name Roshini Shankaran Title Environmental Engineer (If Different than 4) Telephone 303-605-2039 6,, Facility SIC code:1311 7. Facility identification code: CO 123-0099 Federal Tax I. D.Number:84-1041166 9, Primary activity of the operating establishment: Natural Gas Liquids Processing and Gathering 10. Type of operating permit ❑ New Z Modified ❑ Renewal I I. Is the facility located in a"nonattainmenl"area: ® Yes ❑ No If"Yes",check the designated "non-attainment" pollutant(s): Attainment for all Pollutants ❑ Carbon Monoxide. ® Ozone ❑ PN1I0 ❑ Other(specify) 12. List all (Federal and State)air pollution permits(including grandfathered units),plan approvals and exemptions issued to this facility. List the number,date and what unitfprocess is covered by each permit. l'or a Modified Operating Permit,do not complete this item. Clperuling Permit Application FACILITY PLOT PLAN FORM 2000-101 Colorado t) panuxul or Public I teatth and I:mirurumut Rea l0G-')5 Air Pollution control I)ivisi n Facility Name: Greeley Natural Gas Processint!Plant Facility Identification Code:CO 123-0099 The operating permit must he prepared and submitted on forms supplied by the Division. Use of this form is required for all operating permit applications. The Division will not consider or act upon your application unless each form used has been entirely completed. Completion of the information in the shaded area of this form is optional. Use"NA" where necessary to identify an information request that does not apply and is nut in the optional shaded area. In order for a comprehensive air quality analysis to be accomplished, a facility plot plan MUST be included with the permit application. Drawings provided must fit on generic paper sizes of 8 1/2" X 11",8 1/2" X 14" or 11" X 15", as appropriate to display the information being provided. Include the facility name and facility identification code on all sheets. For facilities with large areas, sketches of individual buildings, on separate drawings, may be needed to allow easy identification of stacks or vents. Insignificant activities do not need to be shown. ►:1 1. A plant layout (plan view) including all buildings occupied by or located on the site of the facility and any outdoor process layout. O 2. The maximum height of each building (excluding stack height). ® 3. The location and coded designation of each stack. Please ensure these designations correspond to the appropriate stacks listed on the other permit forms in this application. The drawings need not be to scale if pertinent dimensions are annotated, including positional distances of structures, outdoor processes and free standing stacks to each other and the property boundaries. [] 4. The location of property boundary lines. ® 5. Identify direction "North" on all submittals. Are there any outdoor storage piles on the facility site with air pollution emissions that need to be reported? [J Yes 1 No If "Yes", what is the material in the storage pile(s)? Are there any unpaved roads or unpaved parking lots on the facility site? ® Yes U No List the name(s)of any neighboring state(s) within a 50 mile radius of your facility: Wyoming Otxtating Penns Appheatu,n SOURCE AND SITE DESCRIPTIONS FORM 2000-102 ('nturado Depatvnent of Public I tealth and t to(foment Rev 06-95 An I'utlutton(ontiol tlRiston Facility Name: Greeley Natural Gas Processint_Plant Facility Identification Code:CO 123-0099 The operating permit must be prepared and submitted on forms supplied by the Division. Use of this form is required for all operating permit applications. The Division will not consider or act upon your application unless each form used has been entirely completed. Completion of the information in the shaded area of this form is optional. Use"NA"where necessary to identify an information request that does not apply and is not in the optional shaded area. 1.Briefly describe the existing Unit(s)to be permitted. Attach copies of Form 2000-700 as needed to provide the information. Process flowsheets or line diagrams showing major features and locations of air pollution control equipment can be most effective in showing the location and relationships of the units. Providing mass flowrates/balances at critical points on the diagrams is very helpful when developing an understanding of the processes involved. ' The Greeley Natural Gas Processing Plant is designed to extract natural gas liquids from field produced natural gas and recompress the processed gas prior to transmission to a sales pipeline. Field gas is first piped to a separator where liquids formed during transport to the plant are separated from the gas stream.The gas stream discharged from the separator is processed through an ethylene glycol dehydration unit(AIRS 111),where moisture contained in the gas stream is absorbed by ethylene glycol.The moisture laden glycol discharged from the contactor is regenerated in a reboiler.The glycol solution is then re-circulated to the contactor. Emissions from the dehydration unit still vent are routed to an enclosed combustor. Emissions from the dehydration unit flash tank are routed to a vapor recovery unit(VRU,AIRS 102)and routed back to the plant inlet. During periods of VRU downtime,flash tank emissions are routed to the enclosed combustor. After the moisture in the gas has been removed by the contactor,the gas stream is piped to the processing plant where it is chilled by a refrigeration system coupled with the Joule-Thompson process to create a natural gas liquid(NGL)product and a residue gas stream.A fractionation assembly separates the NGL product into ethane,propane, butane, isopentane and other NGL streams that are stored in separate pressurized bullet tanks and transported offsite by truck.The residue gas is recompressed by eight(8)compressors, powered by natural gas fired internal combustion engines(AIRS 103, 104, 105, 106, 107, 108, 109, 110)and is then routed to a sales gas pipeline.The facility operation also requires two natural gas fired hot oil heaters(AIRS 113, 120),a pressurized truck loadout rack for condensate,a pressurized NGL truck loadout rack (AIRS 115)and various pressurized storage tanks for the NGL and condensate products.The plant flare(AIRS 122)serves as a control device for facility and equipment blowdowns,as well as maintenance,malfunction,startup and shutdown emissions. Fugitive equipment leaks(AIRS 114)are also permitted at this facility. Emission control devices include: nine(9)NSCR beds to control compressor engine exhaust emissions,one(1) vapor recovery unit (VRU)permitted 5%downtime,to control the flash tank emissions from the dehydration unit,one(1)enclosed combustion device (ECD)permitted 5%downtime,to control the still vent emissions from the dehydration unit,as well as flash tank emissions during periods of VRU downtime, and one(1)plant flare,to control facility-wide process emissions. 2.Site Location and Description (Include instructions needed to drive to remote sites not identified by street addresses) The address of the Greeley Natural Gas Processing Plant is 3009 49th Street,Greeley(SE'/a& SW1/4 of SW'/e of Section 25,T5N,R66W). The plant is located at the southern edge of Greeley near Highway 85. 3. Safety Equipment Identify safety equipment required for performing an inspection of the facility: Protection ® Other, specify Fire Retardant Clothing ►4. Hard Hat Eye Protection L.. Safety shoes _-- ►� Hearing Protection Q Gloves OIxraung Pemut Application SOURCE DESCRIPTION - AP ENS NS FORM 2000-102A Colorado I)epalUnenlur Puhlic Ilcaldi:urd I nironment Rey/16-95 Air Pollution(bntioI I),ision facility Name:Credo'Natural Gas Processine Plant Facility Identification Code: CO 123-0099 NOTE: Each new or updated Air Pollutant Emission Notice (APEN) submitted must be accompanied by payment of$191.13 per APEN. 1.For each emission unit enclose a copy of the most current complete Air Pollutant Emission Notice (APEN) on file with the Division. If the most current APEN was not completely and correctly filled out, a revised APEN is required. List an APEN number, date, and a brief description of the unit/process covered by the APEN. (No filing fees are needed for these copies) P121 / C124 123-0099-102 Waukesha F-11 G 04/27/2017 P125/ C119 123-0099-106 Waukesha L7042 GSI 04/27/2017 P127/ C123 123-0099-108 Waukesha L 7042 GU 12/20/2018 P128/C152 123-0099-109 Waukesha L7042 GSI 04/27/2017 P130 123-0099.111 Ethylene Glycol Dehydrator 04/27/2017 P132 123-0099.113 15.0 MMBtu/hr Hot Oil Heater 04/30/2015 P133 123-0099-114 Fugitive VOC emissions from Equipment Leaks 12/18/2019 P139 123-0099-120 35.1 MMBtu/hr Hot Oil Heater 04/24/2018 F-1 123-0099.122 Plant Flare 04/12/2019 2.No APEN exists for an emission unit. List the new APEN and the appropriate descriptive information here. Submit the APEN with a construction permit application. New APEN and permit application submitted ❑ with this application OR ❑ under separate cover to Construction Permits Section 3.A revised APEN was prepared and enclosed for an emission unit. List the APEN and the appropriate descriptive information here. A revised APEN is needed where a significant increase in emissions has occurred, or is planned; or a major modification of the unit has occurred or is planned; or the existing information needs correction or completion. A construction permit application may need to be submitted. Revised APEN submitted as part of this application: ❑ Yes ® No* ❑ Filing Fee Enclosed New permit application enclosed: ❑ Yes ® No Permit modification application enclosed: ® Yes O No P122/C116 123-0099-103 Waukesha L7042 GSI 12/18/2019 P123 /C117 123-0099-104 Waukesha L7042 GSI 12/18/2019 P124/C118 123-0099.105 Waukesha 17042 GSI 12/18/2019 P126/C120 123-0099-107 Waukesha 17042 GSI 12/18/2019 P129/C122 123-0099-110 Waukesha 17042 GSI 12/18/2019 P135 123-0099-115 Pressurized Product Truck Loadout Rack 04/12/2019 *Revised APENs for modified units C122,C123,C124, C126, C129 and P135 provided with 12/18/2019 minor modification application NOTE: Use additional copies of Form 2000-700 as needed to provide the above information. ()peraii g vomit Apphcan ,t STACK IDENTIFICATION FORM 2000-200 t-olinad*'l)gsuunem ol'public I lealth and i nvironment Rev pb-VS Air t'ottution control Di%isinn SEE INSTRUCTIONS ON REVERSE SIDE'. I. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code:CO 123-0099 3. Stack identification code:C116 3a. Construction Permit Number:9 OPWE038 4. Exhausting Unit(s),use Unit identification code from appropriate Form(s)2000-300, 301,302,303.304, 305,306. 307 2000-30(1 2000-301 - 2000-302 Cl I6 2000-303 2000-304 2000-305 2000.306 2000-307 5. Stack identified on the plot plan required on Form 2000-101 ® No Change in Engine Location 6. Indicate by checking: ►� This stack has an actual exhaust point.The parameters arc entered in Items 7-13. ❑ This stack serves to identify fugiti'e emissions. Skip items 7-13. Go to next form. ❑ When stack height Good Engineering Practice(GEI')exceeds 65 meters(Colorado Air Quality Reg 3.A,\'III_D)data entry is required Item 7. 7. Discharge height above ground level: 14.6 (feet) 8. Inside dimensions at outlet(check one and complete): ®Circular 1.0 (feet) ❑ Rectangular length(feet) width(feet) 9. Exhaust flow rate: Normal 5,377 (ACFM) Maximum (ACFM) Velocity 114 (FPS) ❑ Calculated ❑ Stack Test 10. Exhaust gas temperature(normal): 1.100 ('F) 11. Does process modify ambient air moisture content? ❑ Yes ® No If"Yes",exhaust gas moisture content: Normal percent Maximum percent 12. Exhaust gas discharge direction: ®Up ❑ Down ❑Horizontal 13. Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack?O Yes®No ****'Complete the appropriate Air Permit Application Forms(s)20(10-300,301, 302,303, 304, ***** 305, 306,or 307 for each I Init exhausting through this stack. Operating Penult,Application STACK IDENTIFICATION FORM 2000-200 Colorado Department of I'uhhc I Icatth and Emu-omen( Rev t1G-95 Air Pollution('omen!Division SEE. INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code:CO 123-0099 3. Stack identification code:C 11 3a.Construction Permit Number:95OPWE038 4. Exhausting Unit(s).use Unit identification code from appropriate Form(s)2000-300, 301, 302,303, 304,305,306,307 2000-300 2000-301 2000-302 CI17 2000-303 2000-304 2000-305 2000-306 2000-307 5. Stack identified on the plot plan required on Form 2000-101 F No Change in Engine Location 6. Indicate by checking: This stack has an actual exhaust point.The parameters are entered in Items 7-13. ❑ This stack serves to identify fugitive emissions. Skip items 7-13. Go to next form. ❑ When stack height Good Engineering Practice((4 l )exceeds 65 meter;(Colorado Air Quality Reg 3.A.VI II_I))data entry is required for Item 7. 7. Discharge height above ground level: 26 (feet) 8, Inside dimensions at outlet(check one and complete): 11 Circular 1.0 (feet) ❑Rectangular length(feet) width(feet) 9. Exhaust flow rate: Normal 5,377 (ACFM) Maximum (ACFM) Velocity 114 (FPS) ❑Calculated ❑ Stack Test 10. Exhaust gas temperature(normal): 1,055 (3F) 11. Does process modify ambient air moisture content? ❑ Yes 11 No If"Yes",exhaust gas moisture content: Normal^percent Maximum_percent 12. Exhaust gas discharge direction: ®Up D Down O Horizontal 13. Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack?O Yes®No *****Complete the appropriate Air Permit Application Forms(s) 2000-300,301,302,303, 304, ***** 305, 306,or 307 for each tinit eshaustin g through this stack. operating Pennit Application STACK IDENTIFICATION FORM 2000-200 Colorado Department of Public I Iralth and Fn ironmeut kev t)6-9ti Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE I. Facility name:Creeks Natural Gas Processing Plant 2. Facility identification code: CO 123-0099 3. Stack identification code: C118 3a. Construction Permit Number:95OPWVE038 4. Exhausting Unit(s),use Unit identification code from appropriate Form(s)2000-300, 301,302,303, 304,305,306, 307 2000-300 2000-301 21)00-302 C 118 2000-303 2000-304 2000-305 2000-306 2000-307 5, Stack identified on the plot plan required on Form 2000-101 I. No Change in Engine Location 6. Indicate by checking: This stack has an actual exhaust point.The parameters are entered in Items 7-13. ❑ This stack serves to identify fugitive emissions. Skip items 7-13. Go to next form. ❑ When stack height Good Engineering Practice[( EI')exceeds 65_meters(Colorado Air Quality Reg 3.A.VIII.D)data entry is rec aired for Item 7. 7. Discharge height above ground level: 26 (feet) 8. Inside dimensions at outlet(check one and complete): ►1 Circular 1.0 (feet) ❑ Rectangular length(feet) width(feet) 9. Exhaust flow rate: Normal 5,377 (ACFM) Maximum (ACFM) Velocity 114 (FPS) El Calculated ❑ Stack Test 10. Exhaust gas temperature(normal): 1,055 (°F) 11. Does process modify ambient air moisture content? ❑ Yes E. No If"Yes",exhaust gas moisture content: Normal percent Maximum percent 12. Exhaust gas discharge direction: / Up ❑Down ❑ Horizontal 13. Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack?❑Yes ii No *****Complete the appropriate Air Permit Application Forms(s)2000.300.301,302, 303, 304, ***** 305. 306.or 307 for each Unit exhausting through this stack. it Ulkmuing I'rnnii Appheauon STACK IDENTIFICATION FORM 2000-200 Coloatto Department of Public I I alth and t nviruiunenl Rev 114-95 Au Pollution Cimhol Division SEE INSTRUCTIONS ON REVERSE RSE SIDE I. Facility name:Greeley Natural Gas Processing Plant Facility identification code:CO (23-0099 3, Stack identification code: C120 3a. Construction Permit Number:95©PWVE038 4, Exhausting Unit(s), use Unit identification code from appropriate Form(s)2000-300, 301. 302,303, 304. 305, 306,307 2000-300 2000- t)I 2000-302 C120 2000-303 2000-304 2000-305 2000-306 2000-307 5. Stack identified on the plot plan required on Form 2000-101 1 No Change in Engine Location t�. Indicate by checking: This stack has an actual exhaust point. The parameters are entered in Items 7-13. © This stack serves to identify fugitive emissions. Skip items 7-13. Go to next font. El When stack height Good Engineering Practice(GEPIsxceed GS meters(Colorado Air Quality Reg 3,A.VIII,D)data entry is required for Item 7, 7. Discharge height above ground level: 28 (feet) 8. Inside dimensions at outlet(check one and complete): Circular 1.0 (feet) ❑Rectangular length(feet) width(feet) 9. Exhaust flow rate: Normal 5,377 (ACFM) Maximum (ACFM) Velocity __114 (I-'PS) ❑Calculated ❑ Stack Test 10. Exhaust gas temperature(normal): 1,055 (°F) 11. Does process modify ambient air moisture content? ❑ Yes No If"Yes",exhaust gas moisture content: Normal percent Maximum_percent 12. Exhaust gas discharge direction: Up D Down ❑ Horizontal 13. Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack?❑Yes►2 No *****Complete the appropriate Air Permit Application Forms(s)2000-300,301.302.303, 304. ***** 305, 306,or 307 for each Unit exhausting through this stack, (*rating Nunn Application STACK IDENTIFICATION FORM 2000-200 ('oluradn I)partinont ul Public I ealth and I?n~uonrnint key'06. Au Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE Facility Warne: Greeley Natural Gas Processing Plant 2. Facility identification code:CO 123-0099 3, Stack identification code: C122 3a. Construction Permit Number:95OPWE038 4. Exhausting linit(s).use Unit identification code from appropriate Form(s)2000-300, 301, 302,303, 304.305.306,307 ?000.300 2000-301 2000-302 C122 2000-303 2000-304 2000-305 2000-306 2000-307 S. Stack identified on the plot plan required on Form 2000-101 /1 No Change in Engine location 6, Indicate by checking: This stack has an actual exhaust point.The parameters are entered in Items 7-13. ❑ This stack serves to identify fugitive emissions. Skip items 7-13. Go to next form, ❑ When stick height Good Engineering Practice(GEP)exceeds 65 meters(Colorado Air Quality Reg 3.A.VIII.1))data entry is required for Item 7. 7. Discharge height above ground level: 27 (feet) 8. Inside dimensions at outlet(check one and complete): Circular 1.0 (feet) ❑Rectangular length(feet) width(feet) 9. Exhaust flow rate: Normal 5.377 (ACFM) Maximum (ACFM) Velocity 114 (FPS) ❑Calculated ❑Stack Test 10. Exhaust gas temperature(normal): 1,055 (°F) 11. Does process modify ambient air moisture content? E1 Yes ►i No If"Yes",exhaust gas moisture content: Normal®percent Maximum percent 12. Exhaust gas discharge direction: ►.w4 Up ❑Down O Horizontal 13. Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack?❑Yes I No **"**Complete the appropriate Air Permit Application Forms(s)2000-300,301,302,303,304, ***** 305, 306,or 307 for each Unit exhausting through this stack, t tteruing Permit Application STACK IDENTI FICATION FORM 2000-200 Colorado Department ol Public health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code:CO 123-0099 3. Stack identification code: P135 3a.Construction Permit Number:95OPWE038 4. Exhausting Unit(s), use Unit identification code from appropriate Form(s)2000-300, 301,302,303,304,305, 306,307 2000-300 2000-301 2000-302 2000-303 2000-304 2000-305 2000-306 P135 2000-307 5. Stack identified on the plot plan required on Form 2000-101 E� No Change in Equipment Location 6. Indicate by checking: A. This stack has an actual exhaust point,The parameters are entered in Items 7-13. ❑ This stack serves to identify fugitive emissions. Skip items 7-13, Go to next form. ❑ When stack height Good Engineering Practice tGEP)exceeds 65 meters(Colorado Air Quality Ref;3.ANIIL1))data entry is required for Item 7. 7. Discharge height above ground level: (feet) 8. Inside dimensions at outlet(check one and complete): fi Circular (feet) ❑ Rectangular length(feet) width(feet) 9. Exhaust flow rate: Normal (ACFM) Maximum (ACFM) Velocity (FPS) ❑Calculated ❑ Stack Test 10. Exhaust gas temperature(normal): (°F) 11. Does process modify ambient air moisture content? ❑ Yes No if"Yes",exhaust gas moisture content: Normal percent Maximum percent j 12. Exhaust gas discharge direction: ®Up ❑ Down ❑ Horizontal 13. Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack?❑ Yes ►Zt No *****Complete the appropriate Air Permit Application Forms(s)2000-300,301,302, 303, 304, ***** 305, 306,or 307 for each Unit exhausting through this stack. INTERNAL COMBUSTION ENGINE OPERATION operating I'rnnit Aplalicau„n FORM 2000-302 Colorado Dcpartnrnt of Public dearth and Environment ttry(1(-95 Air Pollution(nnirul Division SIDE INSTRUC I IONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code:CO 123-0099 3. Stack identification code: C116 4. Engine(Unit)code: Cl I6 4a,Date first placed in service: Before 1986 Date last modified: NA 5. Engine use: drive for refrigeration compressor 6. Engine Features: 2-Cycle 4-Cycle Z Spark-ignition Diesel ❑ Standard rich burn Standard lean burn 0 Air//fuel ratio controller Turbocharger Low-NOx design 0 Other(Describe): 7. Emission controls: ❑No Yes- Attach control device form No change in engine control device Non-Selective catalytic reduction hree-way- catalyst ❑ Selective catalytic reduction 0 Ammonia injected ❑ Oxidation catalyst ❑ Other: 8. Manufacturer:Waukesha 9. Model No: L-7042 GSI SIN: 368993 10. Max Fuel Design Rate: 9.3 mmBTU%hr I I. horsepower Max Design: 1,100 Site: 1,100 12. heat Rate: 8,490 Bill/HP-hr 13. Operating Temp: Min. Max. EF 14. Fuels: Primary Fuel Backup Fuel Fuel Type: Natural Gas Heating Value BTU'SCF 1,040 Sulfur Content (Wt.%) Neg. Ash Content (Wt.%) Neg. Moisture Content (%) Maximum Hourly Consumption (I t`.gal) 8,984 scf'hr Maximum Yearly Consumption(Ftt,gal) 78.7 MMscflyr NOTE: Data entry below is NOT OPTIONAL it'parametric monitoring is used for compliance demonstration 15, Operational Parameters Low High REMARKS Ignition Timing(degrees) Speed(RPM) Intake Air Temp.(EF) Air and Fuel Manifold Pressure Exhaust Temperature(EF) Exhaust Oxygen(%) Waste Gate Position Fuel Regulator Setting ***** Identify. the method of compliance demonstration by completing Form 2000-500, ***** DESCRIPTION OF METHODS USED FOR DETERMINING COMPLIANCE. Attach Form 2000-500 to this form. **** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** INTERNAL COMBUSTION ENGINE OPERATION Operating Perrin Application FORM 2000-302 (t.toi;i t 0cpamnrnt trf Public I Icalth and t nrircmu+cnl ILcr(]6-95 Air Pollution Control Division SEF;INSTRUCTIONS ON REVERSE SIDE I. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code:CO 123-0099 3. Stack identification code: CI I7 4. Engine(Unit)code: C117 4a.Date first placed in service: Before 1986 Date last modified:NA 5. Engine use: drive for inlet/residue natural gas compressor 6. Engine Features: 2-Cycle 4-Cycle F Spark-ignition Diesel ❑ Standard rich burn Standard lean burn [] Air`fuel ratio controller ® Turbocharger Low-NOx design 0 Other (Describe): 7. Emission controls: ❑ No ► Yes-Attach control device form No change in engine control device Non-Selective catalytic reduction Three-way catalyst 0 Selective catalytic reduction 0 Ammonia injected 0 Oxidation catalyst 0 Other: 8. Manufacturer:Waukesha 9. Model No: L-7042 CSI S'N: 337569 10. Max Fuel Design Rate: 9.3 mmB"I'U'hr 11. Horsepower Max Design: 1,100 Site: 1,100 12. I(cat Rate: 8,490 BTU.IMP-hr 13. Operating Temp. Min. Max. Lf' 14. Fuels: Primary Fuel Backup Fuel PP1 Fuel Type: Natural Gas Heating Value BTU SCF I,040 Sulfur Content (Wt.%) Neg. Ash Content (Wt.%) Neg. Moisture Content (%) Maximum Hourly Consumption (Ft',gal) 8,984 scfihr ,. Maximum Yearly Consumption(Fi',gal) 78.7 MMscfiyr NOTE. Data entry below is NOT OPTIONAL if parametric monitoring is used for compliance demonstration 15.Operational Parameters Low High REMARKS Ignition Timing(degrees) Speed(RPM) Intake Air Temp.(EF) Air and Fuel Manifold Pressure Exhaust Temperature(EF) Exhaust Oxygen(%) Waste Gate Position Fuel Regulator Setting ***** Identify,the method of compliance demonstration by completing Form 2000-500, ***** DESC'RIPT'ION OF METHODS USED FOR DETERMINING COMPLIANCE;. Attach Form 2000-500 to this form. ***** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** INTERNAL COMBUSTION ENGINE OPERATION (Ix:r rting l'ennu 1pplicauun FORM 2000-302 ("olorarkr I)ep:utmcu[of I'uhhc I Icalth and I n%mmntcnt Itcv nh-95 t'uI haw C'onDoi L)rvision SEE INSTRt.)CTIONS ON REVERSE SIDE I. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code:CO 123-0099 i. Stack identification code: Cl I8 4. Engine(Unit)code: C118 4a. Date first placed in service: Before April 1975 Date last modified: NA 5. Engine use: drive for inlet/residue natural gas compressor 6, Engine Features: 2-Cycle 4-Cycle R. Spark-ignition ® Diesel ❑ Standard rich burn Standard lean burn ❑ AiNfuel ratio controller i:* Turbocharger I ow-NOx design 0 Other(Describe): 7. Emission controls: ❑ No ® Yes-Attach control des ice form No change in engine control device Non-Selective catalytic reduction ► Three-way catalyst 0 Selective catalytic reduction 0 Ammonia injected 0 Oxidation catalyst 0 Other: 8. Manufacturer: Waukesha 9. Mtxlel No: 1.-7042(SI S`N: 286434 10, Max Fuel Design Rate: 9.3 minBTU/hr I I Ilorsepov.er Max Design: 1,100 Site: 1,100 12. Heat Rate: 8,490 BTU=TIP-hr 13. Operating Temp: Min. Max. El 14. Fuels: Primary Fuel Backup Fuel 01 Fuel Type: Natural Gas !leafing Value BTU/SCE 1,04O Sulfur Content (Wt.°,) Neg. Content (Wt.%) Neg. Moisture Content (%) Maximum Ilourly Consumption(Ft`,gal) 8,984 scf/hr Maximum Yearly Consumption(Ft`.gal) 78.7 N1Miscf/yr NOTE: Data entry below is NOT OPTIONAL if parametric monitoring is used for compliance demonstration 15.Operational Parameters Low High REMARKS Ignition Timing(degrees) Speed(RPM) Intake Air Temp.(EF) Air and Fuel Manifold Pressure Exhaust Temperature(EF) Exhaust Oxygen(%) Waste Gate Position Fuel Regulator Setting ***** Identify.the method of compliance demonstration by completing Form 2000-500, ***** DESCRIPTION OF METHODS USED FOR DETERMINING COMPLIANCE, Attach Form 2000-500 to this form. ***•* Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** INTERNAL COMI3ESTION ENGINE OPERATION Otkrrting Permit Application FORM 2000-302 Colorado Department of public!lath and t,nvlronumit Rev 116-95 An Pollution Control Division SEE:INSTRUCTIONS ON REVERSE SIDE. _ I. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code:CO 123-0099 3. Stack identification code:Cl20 4, Engine(Unit)code: C120 4ta_Date first placed in service: Before 6/12/2006 Date last modified:NA . Engine use: drive for inletiresidue/ethane natural gas compressor 6, Engine Features: 2-Cycle 4-Cycle Spark--ignition Diesel Q Standard rich burn ® Standard lean burn Airfuel ratio controller ® l urbocharger t# Low-NOx design 0 Other(Describe): 7, Emission controls: ❑No Yes-Attach control device firm No change in engine control device Non-Selective catalytic reduction Three-way catalyst 0 Selective catalytic reduction 0 Ammonia injected 0 Oxidation catalyst © Other: 8. Manufacturer: Waukesha 9. Model No: L-7042 GSI SIN: 388531 10. Max Fuel Design Rate: 9.3 mmBTU`hr 11. Ilorsepower Max Design: 1,100 Site: 1,100 12, Beat Rate: 8,490 BTU/IlP-hr 13. Operating Temp: Min. Max, [F 14, Fuels: Primary Fuel Backup Fuel PI Fuel Type: Natural Gas Ileatinu Value 1310 SC'F 1,040 Sulfur Content (WVt.%) Neg. Ash Content (V4 Lni) Neg. Moisture Content (u/i,) Maximum Hourly Consumption(Et`,ggal) 8,984 sefihr Maximum Yearly Consumption(Ft',gai) 78.7 MMsef/vr NOTE: Data entry below is NOT OPTIONAL if parametric monitoring is used for compliance demonstration 15.Operational Parameters Low High REMARKS Ignition Timing(degrees) Speed(RPM) Intake Air Temp.(EF) Air and Fuel Manifold Pressure Exhaust Temperature(EF) Exhaust Oxygen(%) Waste Gate Position Fuel Regulator Setting ***** Identify, the method of compliance demonstration by completing Form 2000-500,***** DESCRIPTION OF METHODS USED FOR DETERMINING COMPLIANCE Attach Form 2000-500 to this form. *** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit, ***** INTERNAL COMBUSTION ENGINE;OPERATION Operating Permit Applicatign, FORM t 2000-302 (ott d,t Department of Public I lcatth and ICnvnunntrnl Rev UA-95 :1n I'oltu ton('ontrol I)teown SEE INSTRUCTIONS ON REVERSE SIDE_ I. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code:CO 123-0099 3, Stack identification code: C122 4. Engine(Unit)code: C I22 4a. Date first placed in service: Before April 2006 Date last modified: NA 5. Engine use: drive for inlet/residue/ethane natural gas compressor 6. Engine Features: 2-Cycle 4-Cycle® Spark-ignition Diesel ❑ Standard rich burn ® Standard lean burn ❑ Air"ftel ratio controller ® Turbocharger l-ow-NOx design 0 Other(Describe): 7. Emission controls: ❑ No ® Yes- Attach control device form No change in engine control device Non-Selective catalytic reduction ® Three-way catalyst ❑ Selective catalytic reduction 0 Ammonia injected ❑ Oxidation catalyst ❑ Other: 8. Manufacturer: Waukesha 9. Model No: L-7042 GSI SN: 260928 10_ Max Fuel Design Rate: 9.3 mmE3Tl//hr 11. Horsepower Max Design: 1,100 Site: 1,100 12. Iteat Rate: 8,490 BTU Ili'-hr 13. Operating Temp: Min. Max. ET 14. Fuels: Primary Fuel Backup Fuel /II Fuel Type: Natural( as _- _--- Ileating Value B'TE1'SCF 1,040 Sulfur Content (Wt.°ig) Neg. Ash Content (W1."i,) Neg.Moisture...._ Content . Maximum Ilourly Consumption (Ft),gal) 8,984 scf/hr Maximum Yearly Consumption(Ft',gal) 78.7'11Mscf/yr V NOTE: Data entry below is NOT OPTIONAL- if parametric monitoring is used for compliance demonstration 15.Operational Parameters Low High REMARKS Ignition Timing(degrees) Speed(RPM) Intake Air Temp.(EF) Air and Fuel Manifold Pressure Exhaust Temperature(EF) Exhaust Oxygen(%) Waste Gate Position Fuel Regulator Setting ***** Identify,the method of compliance demonstration by completing Form 2000-500, ***** DESCRIPTION OF METHODS EISEI)FOR DETERMINING COMPLIANCE. Attach Form 2000-500 to this form. ***** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** Urk:rting Permit Application NIISCEI,I.ANE:OUS PROCESSES FOR11 2000-306 Colorado Department of Public I Iealth and Environment Re‘06.95 \n Pollulion Control Division SEE INSTRUCTIONS ON REVERSE SIDE I. Facility name:Greeley Natural Gas Processing Plant 2. Facility identification code: CO 123-0099 3. Stack identification code: PI35 4. Process(Unit)code: P135 5. Unit description:Pressurized Product Truck Loadout Rack 6. Indicate the control technology status. Uncontrolled x Controlled No change in control status If the process is controlled,enter the control device code(s) from the appropriate form(s): 2000-400 2000-401 7000.402 2000-403 2000-404 200(1-405 2000-406 2000-407 7. Actual annual process rates for 19 X. Date first placed in service: 1/01/1990 Date of last modification: NA 9. Normal operating schedule: 24 hrs./day 7 days/wk. 8,760 hours'yr. 10, Describe this process(please attach a now diagram of the process). Attached? Propane,butane, B-G Mix,Y-Grade, Isopentane, Natural Gas Liquids(NGL), condensate loaded from pressurized storage tanks to tank trucks. Emissions controlled via vapor balance system: the only emissions are from hose disconnects. I I. I.ist the types and amounts of raw materials used in this process: Material Storage material handling process Actual usage Units Maximum Units usage Condensate Load out from tank to truck 55,718 loads/yr 2 17, I_ist the types and amounts of finished products: Material Storage material handling Process Actual amount Units Maximum Units produced amount produced None 13. Process fuel usage: Type of fuel Maximum heat input to Actual usage Units Maximum Units process usage million ITUUhr. None 14. Describe any fugitive emissions associated with this process.such as outdoor storage piles, unpai.ed roads,open conveyors,etc.: NA ***** For this emissions unit, identify the method(ti)of compliance demonstration by completing Form 2000.500, ***** DESCRIPTION OF METIIODS USED FOR DETERMINING COMPLIANCE. Attach Form 2000-500 and its attachment(s)to this firm, ***** Please complete the Air Pollution Control Permit Application Forms 2000.600 and 2000-601 for this Unit. ***** ' All loading and unloading events conservatively calculated using condensate product which gives the highest potential emissions of VOC and HAPs. 2 1 load= 10,000 gallons (p iauug Pcunit.Application EMISSION UNIT HAZARDOUS AIR POLLUTANTS FORM 2000-600 (-+d,t tdn I hparttnent or I'uhhc f kalif)and Inv+ronment Rc%W95 An Puttuuan Conned I)svtsnm SEE INSTRUCTIONS ON REVERSE SIDE I. Facility name:Greeley Natural Gas Processing 2. Facility identification code:CO 123-0099 Plant _ 3. Stack identification code:C116 4. IInit identification code:O116 5. Unit material description: compressor engine 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor references. Attached[] emission calculations provided with 12/18/2019 minor modification application Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name Quantity Measurement Quantity Measurement Units Units 50000 Formaldehyde 320.77 lb/Tr 402.5 lb/yr NOTE: If there is a permit for this unit, the permit limits are the same as the potential to emit. (,po.aing Pcrmu Applrcnion EMISSION UNIT HAZARDOUS AIR POLLUTANTS FORMI 2000-600 Colorado Ihpanrnent of Public health and Ern, Rcv 06-95 Ait Pollution('ontrol I hvisum SEE INSTRUCTIONS ON REVERSE SIDE: _ . Facility name:Greeley Natural Gas Processing 2. Facility identification code:CO 123-0099 Plant 3. Stack identification code:O117 4. Unit identification code:CI 17 5. Unit material description:compressor engine - 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor references. Attached Q emission calculations provided with 12/18/2019 minor modification application Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name Quantity Measurement Quantity Measurement Units Units 50000 Formaldehyde 322.5 lb/yr 402.5 Ib/yr NOTE: If there is a permit for this unit, the permit limits are the same as the potential to emit. ()periwig haunt Application EMISSION UNIT HAZARDOUS AIR POLLUTANTS FORM 2000-600 (otorado Department of I'uhhc I lraltli and 6nrnonmem It.•%0b-95 Ali Pollution Control tAcniun S1:1`.INSTRUCTIONS ON REVERSE SIDE — I. Facility name:Greeley Natural Gas Processing 2. Facility identification code:CO 123-0099 Plant 3. Stack identification code:Cl 18 4. trait identification code:O118 5. Unit material description:compressor engine 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor references. Attached❑ emission calculations provided with 12/18/2019 minor modification application Pollutant CAS Common or Generic • Actual emissions Allowable OR Potential to emit Pollutant Name Quantity Measurement Quantity Measurement Units Units 50000 Formaldehyde 322.8 lb/yr 402.5 lb/yr NOTE: If there is a permit for this unit, the permit limits are the same as the potential to emit. (tp rating Permit Application EMISSION UNIT HAZARDOUS AIR POLLUTANTS UTAN 1`S FORMI 2000-400 Colorado Department ,tI'uhlic I leal(h and Environment Rev(1(i-95 Atr I'olluuon Control Division SEE INSTRUCTIONS ON REVERSE SIDE' • 1. Facility name:Greeley Natural Gas Processing 2. Facility identification code:CO I23-0099 Plant TM1. Stack identification code:O1211 4. 1 Jnit identification code:O120 5. Unit material description:compressor engine h. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor references. Attached❑emission calculations provided with 12/18/2019 minor modification application Pollutant CAS Common or Generic Actual emissions Allowable OR Putentaal to emit Pollutant Name Quantity Measurement Quantity Measurement Units Units 50000 Formaldehyde 315.5 lb/yr 4023 lb/yr NOTE: If there is a permit for this unit, the permit limits are the same as the potential to emit. t)tx:rtnns Peanut Application EMISSION UNIT HAZARDOUS AIR POLLUTANTS FORA 2000-600 ('oloradn I)epartmcni ol IPublic tlealth and Pnvuonm4nt Rev 06A≥ Au Pollution Conitot Division SEE INSTRUCTIONS ON REVERSE SIDE I. Facility name:Greeley Natural Gas Processing 2. Facility identification code:CO 123-0099 Plant 3. Stack identification code:(7122 4. Unit identification code:C122 5. Unit material description• compressor engine 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor references. Attached❑emission calculations provided with 12/18/2019 minor modification application .- Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name Quantity Measurement Quantity Measurement Units Units 50000 Formaldehyde 318.2 lb/yr 4023 lb/yr NOTE: If there is a permit for this unit,the permit limits are the same as the potential to emit. Operating rennit Application EMISSION UNIT HAZARDOUS AIR POLLUTANTS FORM 2000-600 Colorado Department of Public I Ieatth and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE I. Facility name:Greeley Natural Gas Processing l 2. Facility identification code: CO 123-0099 Plant 3. Stack identification code: P135 — — 4. Unit identification code: P135 5. Unit material description:pressurized product truck loadout rack 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor references. Attached lAI Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name Quantity Measurement Quantity Measurement Units Units 110-54-3 n-Hexane 12,826 lb/yr 71-43-2 Benzene 1,679 lb/yr 108-88-3 Toluene 1,047 lb/yr 540-84-1 2,2,4-Trimethylpvntane 300 lb/yr NOTE: If there is a permit for this unit, the permit limits are the same as the potential to emit. Operating Permit Application EMISSION UNIT CRITERIA AIR POLLUTANTS FORM 2000-601 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing 2. Facility identification code:CO 123-0099 Plant 3. Stack identification code: C116 4. Unit identification code:C116 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission I factor references. Attached ❑ emission calculations provided with 12/1812019 minor modification application Air pollutant Actual Potential to emit Maximum allowable Quantity U TPY Quantity U TPY Quantity U TPY Particulates(TSP) 1.94E-02 III 0.63 1.94E-02 2 0.79 PM-10 1.94E-02 2 l 1.94E-02 I ' Nitrogen oxides * I l Volatile organic 0.130 compounds Carbon monoxide l 0.649 2 26.55 Lead Sulfur dioxide Total reduced sulfur Reduced sulfur compounds Hydrogen sulfide Sulfuric Acid Mist Fluorides *NOx 2019 actual emissions calculated using previous(non-modified)compliance emission factor. Updated potential emissions were calculated using the new(modified)compliance emission factor. Units (U) should be entered as follows: 1=lb/hr 2=lb/mmBTU 3=grains/dscf 4=lb/gallon 5=ppmdv 6=gram/HP-hour 7=lb/mmscf 8=lb/HP-hour 9=other(specify) 10=other(specify) Operating Permit Application EMISSION UNIT CRITERIA AIR POLLUTANTS FORM 2000-601 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing 2. Facility identification code:CO 123-0099 Plant 3. Stack identification code: C117 4. Unit identification code: C117 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached ❑ emission calculations provided with 12/18/2019 minor modification application Air pollutant Actual Potential to emit Maximum allowable Quantity U TPY Quantity U TPY Quantity U TPY Particulates (TSP) 1.94E-02 2 0.64 1.94E-02 2 0.79 PM-10 1.94E-02 2 0.64 1.94E-02 r 2 0.79 Nitrogen oxides * 0.649 2 21.30 0.586 12 24.00 Volatile organic 0.130 2 4.26 0.130 2 5.31 compounds Carbon monoxide 0.649 2 21.30 0.649 2 26.55 Lead Sulfur dioxide Total reduced sulfur Reduced sulfur compounds Hydrogen sulfide Sulfuric Acid Mist Fluorides T,--�- ------ *NOx 2019 actual emissions calculated using previous (non-modified)compliance emission factor. Updated potential emissions were calculated using the new(modified)compliance emission factor. Units (U) should be entered as follows: 1 =Ib/hr 2=lb/mmBTU 3=grains/dscf 4=lb/gallon 5=ppmdv 6=gram/HP-hour 7=Ib/mmscf 8=lb/HP-hour 9=other(specify) 10=other(specify) Operating Permit Application EMISSION UNIT CRITERIA AIR POLLUTANTS FORM 2000-601 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing 2. Facility identification code: CO 123-0099 Plant 3. Stack identification code: C118 4. Unit identification code: C118 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission I factor references. Attached ❑ emission calculations provided with 12/18/2019 minor modification application Air pollutant Actual Potential to emit Maximum allowable Quantity U TPY Quantity U TPY Quantity U TPY Particulates(TSP) 1.94E-02 2 0.64 1.94E-02 2 0.79 PM-10 1.94E-02 2 0.64 1.94E-02 2 0.79 Nitrogen oxides * 0.649 2 21.32 0.586 2 24.00 Volatile organic 0.130 2 4.26 0.130 2 5.31 compounds Carbon monoxide 0.649 2 21.32 0.649 2 26.55 Lead ___.__... Sulfur dioxide Total reduced sulfur Reduced sulfur compounds Hydrogen sulfide Sulfuric Acid Mist Fluorides *NOx 2019 actual emissions calculated using previous(non-modified)compliance emission factor. Updated potential emissions were calculated using the new(modified)compliance emission factor. Units(U) should be entered as follows: 1 =lb/hr 2=lb/mm8TU 3=grains/dscf 4=lb/gallon 5=ppmdv 6=gram/HP-hour 7=Ib/mmscf 8=lb/HP-hour 9=other(specify) 10=other{specify) Operating Permit Application EMISSION UNIT CRITERIA AIR POLLUTANTS FORM 2000-601 Colorado Department of Public Health and Environment 09.94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing 2. Facility identification code: CO 123-0099 Plant 3. Stack identification code: C120 4. Unit identification code: C120 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached ❑ emission calculations pros ided with 12/18/2019 minor modification application Air pollutant Actual Potential to emit Maximum allowable Quantity U TPY Quantity I U TPY Quantity U 1 TPY i Particulates(TSP) 1.94E-02 2 0.62 1.94E-02 2 0.79 PM-10 1.94E-02 2 0.62 1.94E-02 2 0.79 Nitrogen oxides ' 0.649 2 20.84 0.586 2 24.00 Volatile organic 0.130 2 4.17 0.130 2 5.31 compounds I Carbon monoxide 0.649 2 20.84 0.649 1 2 26.55 Lead Sulfur dioxide I Total reduced sulfur Reduced sulfur compounds Hydrogen sulfide Sulfuric Acid Mist Fluorides *NOx 2019 actual emissions calculated using previous(non-modified) compliance emission factor. Updated potential emissions were calculated using the new(modified) compliance emission factor. Units (U) should be entered as follows: 1 =lb/hr 2=Ib/mmDTU 3=grains/dscf 4=lb/gallon 5=ppmdv 6=gram/HP-hour 7=Ib/mmscf 8=lb/HP-hour 9=other(specify) 10=other(specify) Operating Permit Application EMISSION UNIT CRITERIA AIR POLLUTANTS FORM 2000-601 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing 2. Facility identification code: CO 123-0099 Plant 3. Stack identification code:C122 4. Unit identification code: C122 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached ❑ emission calculations provided with 12/18/2019 minor modification application Air pollutant Actual Potential to emit Maximum allowable Quantity U TPY Quantity U TPY Quantity U TPY Particulates (TSP) 1.94E-02 2 0.63 1.94E-02 2 0.79 PM-10 1.94E-02 2 0.63 1,94E-02 2 0.79 Nitrogen oxides " 1 21.02 0.586 2 24.00 Volatile organic I I 2 4.20 0.130 2 5.31 compounds Carbon monoxide 0.649 2 21.02 0.649 2 2635 Lead Sulfur dioxide Total reduced sulfur Reduced sulfur compounds Hydrogen sulfide Sulfuric Acid Mist Fluorides EMI *NOx 2019 actual emissions calculated using previous(non-modified)compliance emission factor. Updated potential emissions were calculated using the new(modified)compliance emission factor. Units (U)should be entered as follows: 1 =lb/hr 2=lb/mmBTU 3=grains/dscf 4=lb/gallon 5=ppmdv 6=gram/HP-hour 7=lb/mmscf 8=lb/HP-hour 9=other(specify) 10=other(specify) Operating Permit Application EMISSION UNIT CRITERIA AIR POLLUTANTS FORM 2000-601 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing 2. Facility identification code:CO 123-0099 Plant 3. Stack identification code: P135 4. Unit identification code: P135 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached Air pollutant Actual Potential to emit Maximum allowable Quantity U TPY Quantity U TPY Quantity U TPY Particulates (TSP) PM-10 Nitrogen oxides Volatile organic 134 9 5.8 1.55 9 43.15 compounds Carbon monoxide Lead Sulfur dioxide Total reduced sulfur Reduced sulfur compounds Hydrogen sulfide Sulfuric Acid Mist Fluorides *NOx 2019 actual emissions calculated using previous(non-modified)compliance emission factor. Updated potential emissions were calculated using the new(modified)compliance emission factor. Units (U)should be entered as follows: 1=lb/hr 2=.lb/mmBIU 3=grains/dscf 4=lb/gallon 5=ppmdv 6=gram/HP-hour 7=Iblmmscf 8=lb/HP-hour 9=other(lb/load) 10=other(specify) Operaung Purina Application PI.ANT-WIDE IlAZARDOUS AIR POLLUTANTS FORM 2000-602 Colorado I kpar Ju ni of Public I lealdt and Fnvirnninriu Ito n4.45 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1, Facility name:Greeley Natural Gas Processing 2. Facility identification code:CO 123-0099 Plant 3. Complete the following emissions summary for all hazardous air emissions at this facility.Calculations attached. Attach a copy of all calculations to this form. Attached Q emission calculations provided with 12!18/2019 minor modification application Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name Quantity Units Quantity Units 50000 Formaldehyde 1.6 TP1' 75070 Acetaldehyde 0.5 TP1' 107028 / Acralein 0.4 1`1'1' 71432 Beurcne 1.3 TP1' 108883 Toluene 0.8 TPl' 100414 Ethylhenzeue 0.02 TPY 10330207 Xylem 0.1 'FP1' 110543 n-Hexane 7.5 TP1' 67561 Methanol 0.7 TPY NOTE: If there is a permit for this unit, the permit limits arc the same as the potential to emit. tpctaling Perron,•\t,pti,:atiun PLANT-W1UE CRITERIA AIR POLLUTANTS FORM 2000-603 l7Horutlo Deparuttent of Public Width:old Iiii miniunl 04.94 Art Pollution Control Division SET: INSTRUCTIONS ON REVERSE SIDE I. Facility name, Greeley Natural Gas 2 Facility identification code:CO 123-0099 Processing Plant 3. Complete the following emissions summary for the listed emissions at this facility, Air pollutant Actual Potential to emit Maximum allowable TPY TPY TPY Particulates(TSP) 7.9 PM-I0 7.9 Nitrogen oxides 204.7 Volatile organic compounds 127.7 Carbon monoxide 242.3 lead Sulfur dioxide 0.3 Total reduced sulfur Reduced sulfur compounds �^ Hydrogen sulfide Sulfuric acid mist fluorides t>penning Pcnnu Application APPLICABLE REQUIREMENTS AND FORM 2000-604 Colorado tkpartrocnt of Public I to tlth:ind I In uomnent STATUS OF EMISSION UNIT Rea(1h-95 Air pollution(ontrol I)o noon SEE INSTRUCTIONS ON REVERSE SIDE I. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 123-0099 3. Stack identification code. CI16 --�� 4. Unit identification code: CI 16 5. Pollutant 6.Colorado Air Quality 7. 8. Limitation 9.Compliance Regulations State Status or Only IN OUT Construction Permit Number NOx 24.0 TP1' X Note:This form only includes revised limits/requirements 10.Other requirements(e.g.,malfunction reporting.special operating conditions from an existing State Only Compliance permit such as material usage,hours of operation,etc.) Status IN OU'F *Unit has not yet operated for twelve months following modification. ****.USE FORM 2000-700'fO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACII APPLICABLE REQUIREMENT**** Unit 3 operating t'enrt Application APPLICABLE: REQUIREMENTS .AND FORM 2000-604 Colorado Department utl'uhlic I lcalth and Environment STATUS OF EMISSION (UNIT Rc.(x,-45 \u Pulluuon(ammo]Division SEE INSTR(ft 1 IONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 123-0099 3. Stack identification code: CI 17 4. Unit identification code: C117 5. Pollutant 6, Colorado Air Quality 7, [ S. Limitation 9.Compliance Regulations State Status or Only IN OUT Construction Permit Number NOx 24.0 TM' X Note: This form only includesf revised limits/requirements 10.Other requirements(e.g., malfunction reporting, special operating conditions from an existing State Only Compliance permit such as material usage,hours of operation,etc.) Status IN OUT *Unit has not yet operated for twelve months following modification. **** USE FORM 2000-700 TO EXPLAIN 11OW COMPLIANCE WAS DETERMINED FOR EACII APPLICABLE REQUIREMENT**** Unit 3 C)tx•rating Nunn \pphcauon APPLICABLE REQUIREMENTS ANt) FORM 2000-604 Colu ratio Dim:Mintntol Public Ilcalth:mil Inciionun•nt STATUS OF EMISSION UNIT Rev 06-45 ArPollution('ontrol Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 123-0099 3. Stack identification code: O118 4. Unit identification code: CI18 5. Pollutant ti. Colorado Air Quality 7. 8. Limitation 9.Compliance Regulations State Status or Only IN OUT Construction Permit Number NO IIIII 24.0 TP1' Note: This form only includes revised limits/requirementsMill III 10.Other requirements(e.g., malfunction reporting.special operating conditions from an existing State Only Compliance permit such as material usage,hours of operation,etc.) Status IN OUT *Unit has not yet operated fur twelve months following modification. **** USE FORM 2000-700 TO EXPLAIN DOW COMPLIANCE WAS DETERMMI tiF.I) FOR F:ACII APPLICABLE REQUIREMENT**** Unit 3 I I Cllkrutinp I4rmit Applitunon APPLICABLE REQUIREMENTS ANI) FORM 2000-604 Colorado thlctrtmeni. Public tlealh and t-nvironntent STATUS OF EMISSION UNIT Rev UO.)5 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE I. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code. CO 123-0099 3. Stack identification code: C'120 4. Unit identification code: C120 S. Pollutant 6,Colorado Air Quality 7. 8, Limitation 9. Compliance Regulations State Status or Only IN OUT Construction Permit Number NOs 24.0 TP1' X Note: This form only includes revised limits/requirements 10. Other requirements fe.g., malfunction reporting,special operating conditions front an existing State Only Compliance permit such as material usage, hours of operation,etc.) Status IN OUT j _ l *Unit has not yet operated for tielve months follosiing modification. **** USE FORM 2000-700TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** Unit 3 Operating Permit Application :APPLICABLE REQUIREMENTS AND FORM 2000-604 Colorado t)parunent of Public ilealth and I us mmmcni STATUS OF EMISSION UNIT Rev 06--45 An Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE I. Facility name: Greeley Natural(:as Processing Plant 2. Facility identification code: CO 123-0099 3. Stack identification code: C122 _ _..., 4. Unit identification code: C122 5. Pollutant ti. Colorado Air Quality 7. R. Limitation 9.Compliance Regulations State Status or Only IN OUT Construction Permit Number NOr 24.0 TPV X Note:This form only includes revised limits/requirements l0.Other requirements(e,g, malfunction reporting,special operating conditions from an existing State Only Compliance permit such as material usage.hours of operation.etc.) Status IN OIJ"I' *Unit has not yet operated for twelve months following modification. **** USE FORM 2000-700 TO EXPLAIN 11OW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** Unit 3 t 1pvrumg I' nnYt-lpphadion APPLICABLE: REQUIREMENTS ANI) FORM 2000-604 t'uluradoIklkutmrnlitl'uhlrcIteatlh and tinrr.nunrnl STATUS OF EMISSION UNIT Kev06.95 it Pollution Comm]Dv.isron SIT INSTRUCTIONS ON RFVERSE SIDE I. Facility name: Greeley Natural Gas Processing Plant 2, Facility identification code: CO 123-0099 3. Stack identification code: P135 4. llnil identification code: PI35 _ T 5. Pollutant h. Colorado Air Quality 7 8. I.imitation 9 Compliance Regulations State Status or Only IN OUT Construction Permit Number Note:This form only includes revised limits/requirements 10. Other requirements(e.g.. malfunction reporting,special operating conditions from an existing State Only Compliance permit such as material usage, hours of operation,etc.) Status IN OUT Product Throughput Limit: 55,718 loads'yr Condensate used as worst-case scenario X Annual extended liquids analysis: 13-G mix, V-grade,NW.,condensate X *( nit has not yet operated for twel\:e months following modification. **** USE FORM 2000-700 TO EXPLAIN FLOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQLnIRENIENT**** Unit 3 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural 2. Facility identification code:CO 123-0099 Gas Processing Plant 3. Stack identification code: C116 4, Unit identification code: C116 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. ►�� We will continue to operate and maintain this Unit in compliance with all applicable requirements. ►�� Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units opt presently fully in compliance,complete the following. O This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Deadline Actions 1. 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural 2. Facility identification code:CO 123-0099 Gas Processing Plant 3. Stack identification code: C117 4. Unit identification code: C117 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. ❑ This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Deadline Actions 1. I 3 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural 2. Facility identification code: CO 123-0099 Gas Processing Plant 3. Stack identification code: C118 4. Unit identification code: C118 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. • We will continue to operate and maintain this Unit in compliance with all applicable requirements. ® Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. • This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule(If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Deadline Actions 1. 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter • Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural 2. Facility identification code: CO 123-0099 Gas Processing Plant 3. Stack identification code: C120 4. Unit identification code: C120 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. We will continue to operate and maintain this Unit in compliance with all applicable requirements. ® Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. ❑ This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Deadline Actions 1. 2. 3. Progress reports will be submitted: Start date:__ _ and every six (6) months thereafter Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural 2. Facility identification code:CO 123-0099 Gas Processing Plant 3. Stack identification code: C122 4. Unit identification code: C122 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. ►#� We will continue to operate and maintain this Unit in compliance with all applicable requirements. ® Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. ❑ This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Deadline Actions 2. • 3. Progress reports will be submitted: Start date: and every six (6) months thereafter Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural 2. Facility identification code:CO 123-0099 Gas Processing Plant 3. Stack identification code: P135 4. Unit identification code: P135 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. • We will continue to operate and maintain this Unit in compliance with all applicable requirements. • Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance,complete the following. ❑ This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule(If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Deadline Actions 1. 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter Operating Permit Application SUPPLEMENTAL INFORMATION FORM 2000-700 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE Facility name: Greeley Natural Gas Processing Plant I , Facility identification code:CO 123-0099 3. This form supplements Form 2000- 604 for Emission Unit(e.g. I3001.P001,etc.) O116 Additional Information,Diagram • Item Number Requirement Compliance Methods 17CP calculates rolling 12-month totals,updated NOx Emissions 1_imil: 24.0 tpy monthly. Records and calculations in Greeley 12- month rolling totals calculations workbook. Operating Permit Application SUPPLEMENTAL INFORMATION FORM 2000-700 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code:CO 123-0099 3. This form supplements Form 2000- 604 for Emission Unit (e.g. 8001,P001, etc.) CI 17 Additional Information, Diagram Item Number Requirement Compliance Methods DCl'calculates rolling 12-month totals,updated NOx Emissions Limit: 24.0 tpy monthly. Records and calculations in Greeley 12- month rolling totals calculations workbook. Operating Permit Application SUPPLEMENTAL INFORMATION FORM 2000-700 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE Facility name: Greeley Natural Gas Processing Plant 1 2, Facility identification code:CO 123-0099 3. This form supplements Form 2000- 604 for Emission Unit(e.g. 8001. P001,etc.) C118 Additional Information.Diagram I Item Number Requirement Compliance Methods DCI'calculates rolling 12-month totals,updated NO\Emissions Limit:24.0 tpy monthly. Records and calculations in Greeley 12- month rolling totals calculations workbook. _ Operating Permit Application SUPPLEMENTAL INFORMATION FORM 2000-700 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE I. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code:CO 123-0099 3. fhis form supplements Form 2000 - 604 for l:miSsion Unit (e.g, BO01, POOL etc.) O120 Additional Information, Diagram Item Number Requirement Compliance Methods DCP calculates rolling 12-month totals,updated NOx Emissions Limit: 24,0 tpy II monthly. Records and calculations in Greeley 12- month rolling totals calculations workbook. Operating Permit Application SUPPLEMENTAL INFORMATION FORM 2000-700 Colorado Department of Public Health and Environment ©9.94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE I. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 123-0099 3. This form supplements Form 2000 604 for Emission Unit (e.g. BOUT,POUT.etc.) 0122 Additional Information,Diagram Item Number Requirement Compliance Methods DCP calculates rolling 12-month totals,updated ' NU Emissions limit: 24.0 tpy monthly. Records and calculations in Greeley 12- month rolling totals calculations workbook. • Operating Permit Application SUPPLEMENTAL INFORMATION FORM 2000-700 Colorado Department of Public Health and Environment 09.94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE I. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 123-0099 3. This form supplements Form 2000- 604 for Emission Unit (e.g. 8001.POOL etc.) P 135 Additional Information, Diagram Item Number Requirement Compliance Methods DCP calculates rolling 12-month totals,updated Product Throughput Limit: 55,718 loads yr Condensate used as veorst-cec.s monthly. Records and calculations in Greeley. I L scenario month rolling totals calculations workbook. Records,calculations,and annual extended liquid Annual extended liquids analysis: B-0 mix, Y grade NG1„condensate analyses kept in DCP compliance files f 1 ! I Operating Permit Application TART LATI(]N OF 1'I R1ll-I'APPLICA'CION FORMS FORA 2000-800 colarada I)eparvnent oilical(h 1)0-'I4 Au Pollution Control Division I'ncilit ' Name Greelct• Natural Gas 1'rocessin yPlant Facility Identification Code: CO 123-0099 ADMINIS1RAIION "I his application contains the billowing limbs: ►�+ Fanu 2000-Iol,facility Identrliiation ►tea Form 2000-101,Facility Plot Plan Forms 2(1110-IO2,-Ii)2A,and-1020,Source and Slie.Descriptions II FAIISSIUNS SOURCF fowl Number 1)1 S(`R11'-1'It IN or his Form his application contains the following toms. Form 211n162011,Slack Identification 6 Iona limn for each lacilits boiler,nnntinr ❑ I'om,2100-300,!toiler nr Furnace Uperation ❑ I min 2000-30 I,Storage l inks l� Fumt 21HN1-3022..Internal Combustion Inginc 5 I inn 201AI-31)3.Incineration ❑ form 20(ul-3014,Piloting Operation; ❑�--� font,21)111)-305,I'ainhll1 and) taiing Operations Lions I ono_2111)0-3(16.tltscellancou.Processes I O loon 2110(1-307,Glycol Dehydration Unit III. :\II)POI LW 1IiINCONTI-00 TOWI Number SY'SLIS1 ofI his Inon Ins application contains the following Iimms ❑ is pl g I amt 21N Mi-411(1,1)sccllanrotn ❑ I non 2000.401,Condensers ❑ ram,2ti110-4)12. \d.ort+ers ❑ ,trot 21111(1-403.(y,talyh.Of I her sal U'idauon ❑ Fnon 211110 4)14.It climes ticuling(h:nnhcrs C] I',win 20110,4115.I:leclntsttl re Precipitators ❑ Parr 2(1011,406,Wei Collection Systems ❑ fort 21„10-407,Itaghouse'.Fahnc I ltrn IV- (-mill I\N(i Nutmlx.r 1)1 '.r1UNIRA'I ION fowl ul`I his Form I his application contains the billowing limns _ tone lief each lnellli%toile printing operation_ D Form 1111(1 5(111,(,Inplianc (-eniliealinn-AIitmtonng and eli.I: Repoittilg ❑ form 2000-501,Continuous Emission Stomtnnng ❑ I'omi 21)410-51)22,Periodic I mission Mornlrtnng I:sing Portable Monitors © I imn 21N1)1-50,3,(`antral Sy stein I'arunelers or Operation Parameters of a I'roccsa ❑ Fonn 20(1(1-5114,Aionitonng Atain(enance Procedures O ,onn 21)(1)1-505,Stark Testing O Form 2(1()41.51)6,Fuel Sampling and Analysis ❑ Form 211011_507,Recordkeepmg ❑ I 'nu 2000.508,Other Methods V, I\IISSIu\SI \t\LAR\ AND C`t_)\ttt J N.( I (I R 1 II lC'\I Ii)V total Number of Ibis Dunn I his application..mail'the f:dlowmP Inmts quantifying onis.quns.certifying.amplrance I"iron 21)00-000,I inrssnon I nu I laz.rdous Air 'olluwnrs 6 w nh applicable requirements,and developing a compliance plan • Conn 2(5)0-(,l)I,I in iamn I.nit l`ritcna:\ir Pollutants 6 • Fonn 2000.602,I a,iirt' I larardou;=fir Pollutant-s I ry} I onn 201)0-(,03,I ac,lit+I Mena \n Potluhrnts l .4 I an 2nuu-t,t4t,Applicable Requirement..and Status or 6 V'nmion( tilt Q Inn 2rr!)0-605.I'cnnit Shield Protection Identification ❑ form 20(I0-6f0t.I iris ton t'nn Compliance Plan- Commttments and Schedule [] Korn+204 0-60?,Plain-Wide Applicable Requirements Q form t1Ulh6t))4.I'lam 1\lde Compliance I'Ian- Conmtinnents and Schedule I T VI. SIGNATURE OF RESPONSIBLE.OFFICIAL. - FEDERAL/STATE CONDITIONS A, STA FI EM ENT OF COMPLETENESS I ha\e reviewed this application in its entirety and,based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this application are true,accurate and complete. B. CERTIFICATION OF FACILITY COSIPLIANC E S I,A"I US • FEDERAL S1 ATE CONDITIONS(check one box only) I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. ❑ I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements.except for the allowing emissions unit(s): (list all non-complying units) WARNING: Any person who knowingly,as defined in§ 18-1-501(6),C.R.S.,makes any false material statement, representation,or certification in,or omits material information from this application is guilty of a misdemeanor and may be punished in accordance with the provisions of§ 25-7 122.1,C.R.S. Printed or Typed Name Title Tauna Rignall General Manager, North Area Operations Signature Date Signed r t N r76.1 r.?Ixraurrg l'cnwt \ppitcawn CERTIFICATION FOR STATE-ONLI CONDITIONS FORA 2000-8110 olocutcr I lcpartment of I Ie rlUi tt'i-U4 An Pullin on('onu.a I)i�tsion Facility Name: Greeley Natural Gas Processing Plant Facility Identification Code:CO I23-0099 VI. SIGNA FART OF RESPONSIBI.I. OFFICIAL- STATE:ONLY CONDITIONS A. STATEMENT OF COMPLETENESS rl NESS I have reviewed this application in its entirety and,based on information and belief formed after reasonable inquiry. I certify that the statements and information contained in this application are true,accurate and complete. B, C'ERTIFICAI ION OF FAC'ILIIY COMPLIANCE STATLIS FOR SI ATE-ONLY CONDITIONS(check one box only I certify that the facility described in this air pollution permit application is fully in compliance tt ith all applicable requirements. ❑ I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements.except for the following emissions unit(s): (list all non-complying units) WARNING: An person who knowingly,as defined in§ 18-1-501(6).C.R.S.,makes any false material statement,representation,or certification in,or omits material information from this application is guilty of a misdemeanor and may be punished in accordance with the provisions of§25-7 122.1,C.R.S. Printed or Typed Name I itle Tauna Rignall General Manager, North Area Operations Signature - Date Signed SEND ALL MATERIALS TO: COLORADO DEPARTMENT OF lIFAI.TII Al'CD-SS-13I -LW CHERRY RRY CREEK DRIVE:SOIIii DENVER,CO 50246-1530 Attachment C: Plot Plan • Greeley Natural Gas Processrm2, Plant 1 • [VTL. 0,I1048,01r1 .,t k .e 1 r LI ` r u ' r , r r ' 6031 11111 Y1 rC ` ` 1%\'11 Isi>-ni)'Nr1 l{r3 III) i ` P MICI1P7 wino-,slit [ i - -..- - �` r:. - - _ _- 1 r Y. _-r../":„„,,,..e,„,..,- �.cw.wnr' _ , f,- \ - ---/...'t t/.t..,-.. �._�1_ �� -1_ - • - \ •I yr j i ti • ' l ft ri' r II — l r —e-. o -• `�� 1 r . . 11, motif - n1'-' 7� ,� i i .r-f .l: _ _ ~ I - - - -- __ • • , _ / +'tom i ..-1.1 f, -'r - I r J I P I rl -7,..,-..,I - _ � T - - .,z, _ I i. yr a+ -- - I 1" Attachment D : December 2019 A ! ' 1': N Forms Greeley Natural Gas Processing Plant Spark Ignition Engine APEN ' CDPHEForm APCD-201. CO Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for spark ignition(e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source(e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-2OO)is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at: www.cnlorado.gov/cdpheiapcd. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE038 AIRS ID Number: 1 23 /0099/ 103 blar,N u,r_>s APCD 3s mit and ARS:DI Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Greeley Natural Gas Processing Plant Site Location: Site Location SW 1/4 Section 25, T5N, R66W County: Weld NAICS or SIC Code: 1311 Mailing Address: (lydivae Zip Code, 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 Portable Source z Home Base: E-Mail Address : rsnankaran@dcpmidstream.com Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. z Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided, 429594 © COLORADO Fars? AP C11 20 1park Ig ion k.ng ne APEN Re iron 3%'Zttly 1 I A �. M., Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 103 Section 2 - Requested Action O NEW permit OR newly-reported emission source(check one beloi [] STATIONARY source 0 PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP02' (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of$1,875 must be submitted along with the APEN filing fee. -OR- Q MODIFICATION to existing permit ((beck each box below char applies) Add point to existing ❑ Change fuel or equipment ❑ Change company name' 0 permit ❑✓ Change permit limit ❑ Transfer of ownerships 0 Other(describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) -AeninoNAL PERMIT ACTIONS ❑ APEN submittal for permit-exempt/grandfathered source • Notification of Alternate Operating Scenario(AOS)permanent replacements Additional Info Et Notes: Lower NOx permit limit based on portable analyzer test data 3 Only one engine may be reported per APEN for GP02 coverage, Coverage under GP02 is voluntary. 4 For company name change,a completed Company Name Change Certification Form (Form APC0-106)must be submitted. 5 For transfer of ownership,a completed Transfer of Ownership Certification Form (Farm APCO 104)must be submitted. This does not apply to General Permit GP02,as it does not contain a provision for AOS permanent replacements. I I Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG•1, Engine 3, etc.)? Yes If yes, provide the Company Equipment Identification No. C116 / P122 �A — General description of equipment and purpose: Refrigeration For existing sources, operation began on: 1/16/1986 For new or reconstructed sources, the projected startup date is: Will this equipment be operated in any NAAQS nonattainment area? (http:i/www.coloradq.goviCdpher!attainrcient) El Yes No Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec-Feb: 25% Mar-May: 25% June-Aug: 25% Sept-Nov: 25% F,,,,„(mk 3E n? D 201 Spar , r, ;'s E;r nrErl y ,,, ,i 3:`29. ' 2 Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 103 Section 4 - Engine Information Engine Function: ❑Primary and/or Peaking Power O Emergency(max. 500 hrs/year) 0 Compression O Pump Jack O Water Pump ❑Other: What is the maximum number of hours this engine will be used for emergency back-up power? 0 hours/year Engine Make: Waukesha Engine Model: L7042 GSI Serial Number': 368993 What is the maximum designed horsepower rating? 1,100 hp What is the maximum manufacturer's site-rating? 1,100 hp kW What is the engine Brake Specific Fuel Comumption at 100%Load? 8,490 BTU/hp-hr Engine Features: Cycle Type: ❑2-Stroke 04-Stroke Combustion: O Lean Burn Q Rich Burn Aspiration: ❑Natural Q Turbocharged is this engine equipped with an Air/Fuel ratio controller(AFRC)? Q Yes O No If yes, what type of AFRC is in use? 0 Oz Sensor(mV) ❑NOx Sensor(ppm) O Other: Is this engine equipped with a Low-NOx design? O Yes ❑No Engine Dates: What is the manufactured date of this engine? < 1986 What date was this engine ordered? < 1986 What is the date this engine was first located to Colorado? < 1986 What is the date this engine was first placed in service/operation? < 1986 What is the date this engine commenced construction? < 1986 What is the date this engine was last reconstructed or modified? NA Is this APEN reporting an AOS replacement engine? O Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested. © COLORADO FOrii AP.D 201 Spire isnir." r E:� `ne:APFN R,,-,s 3,7019 3 11O. Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 103 Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 4,468,151 / 522,877 Discharge Height' , Flow Rate -';Velocity Above Ground Level Stack iD No. ('f) (ACFM) ;(ft/sec) (feet) P122 14.6 1,100 5,377 114 Indicate the direction of the Stack outlet: (check one) ✓[ J Upward O Downward O Upward with obstructing raincap o Horizontal O Other(describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter(inches): 12 Square/Rectangle Interior stack diameter (inches): Interior stack depth(inches): Other(describe): Section 6 - Fuel Data and Throughput Information Ftie!Use Rate G 100%Load Actual Annual Fuel Use .. ,Requested Annual Permit Limits ':=(SCF/hour) (MMSCF/year) #. (MMSCF/year) 8,984 58.75 78.70 From what year is the actual annual amount' 2018 Indicate the type of fuel usedg: 0 Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) Ej Field Natural Gas Heating value: BTU/scf o Propane (assumed fuel heating value of 2,300 BTUlscf) Q Landfill Gas Heating Value: BTU/scf 0 Other (describe): Residue Gas Heating Value(give units): 1,110 Btu/scf 8 Requested values will become permit limitations. Requested limitis)should consider future process growth. e If fuel heating value is different than the listed assumed value.provide this information in the"Other"field. COLORADO 1.1)rrn AP(D-201 Spin. Erg,nt'AP ti Pe,, =0 3:-20 19 4 Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 1 03 1 . . , - .A-cI , - ,'1 ipiSection 7- Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form.The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? Q Yes O No If yes, describe the control equipment AND state the overall control efficiency(%reduction): Overall Requested Control Pollutant Primary Control Equipment Description Efficiency (%reduction in emissions) TSP(PM) PM10 PM 2.5 SO4 NOx NSCR 83% VOC CO NSCa —72 Other: NSCR 76%±kxnaldehyde) 50°b pow,HAPS) Use the following tables to report criteria and non-criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2018 Criteria Pollutant Emissions inventory Requested Emission Factor Actual Annual Emissions10 Emission Limit(s)8rmit Pollutant Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis Units (AP-42, Emissions Emissions Emissions Emissions Mfg.etc) (tons/year) (tons/year) (tons/year) (tons/year) TSP(PM) 1.94E-02 Ib.'MMej AP-42 0 63 0 63 0.79 0 79 PM10 1.94E-02 ICJMM9% AP-42 0 63 0 63 0 79 0.79 PM 2.5 194E-02 I61M34919 AP-42 063 063 079 079 SOx --. 588E-04 Ib/MM6. AP-42 002 002 0.02 602 NOx 13 0 £01P-) Mfg 11004 21 19 13809 24 00 VOC 0 5 g Np-he M1q 4 24 4 24 5 31 5 31 CO 9.0 411P-N Mfg 76 18 21 19 95 60 26 55- Does the emissions source have any uncontrolled actual emissions of non criteria pollutants(e.g. HAP hazardous air pollutant)equal to or greater than 250 Q Yes O No lbs/year? If yes, please use the following table to report the non-criteria pollutant (HAP)emissions from source: Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions1° Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions Number Basis Mfg.etc) (poundslyear) (pounds/year)__^ Formaldehyde — 50000 2 05E-02 MORMe1u AP-42 1 336 54 320.77 _ Acetaldehyde _ 75070 Acrolein 107028 Benzene 71432 Other: 8 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 10 Annual emissions fees wilt be based on actual controlled emissions reported. If source has not yet started operating,leave blank. vqr COLORADO T,- Form APCD2ita Spark Igmhcln [n �1 ��n,e APEtd � R?ti1,. 3'2019 5 I l, ., Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 103 [terra Mann untcss APCD h permit "and AIR$ID] Section 8 -Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, i further certify that this source is and will be operated in full compliance with each condition of General Permit GPO2. O1\fts (19 Signature of Legally Authorized Person(not a vendor or consultant) Date Marie Cameron Senior Environmental Engineer Name(please print) Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance El Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made(significant emissions increase, increase production, new equipment,change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements, Send this form along with$191.13 and the General Permit For more information or assistance call: registration fee of$1,875, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 or(303)692.3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692-3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www.colorado.gov/cdphe/apcd ®may cotORADO 17.=, Form APCD 201 Spark Ignition Engine ADEN R�.visiGr� 3/2019 6 I ��Cff „R;; �°�.'-E�^ Spark Ignition Engine APEN coPHE p 1 g COForm APCD-201 �* • Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for spark ignition (e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e.g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-2OO) is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at: www.cotorado.gov/cdphe/apcd. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 104 Rea, t.r .n ,,.,s APCD'i+ti j'=,sc , y a.,rs ,'d a permrt c and AIRS ID) Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Greeley Natural Gas Processing Plant Site Location Site Location: SW 1/4 Section 25, T5N, R66W County: Weld NAICS or SIC Code: 1311 Mailing Address: (Intrude Zrp code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 Portable Source E-Mail Address: Home Base: rshankaran@dcprnidstream.com ' Use the full,legal company name registered with the Colorado Secretary of State,This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. Permits,exemption letters,and any processing invoices will be issued by the APCD via email to the address provided. 429595 VW C Form APCD 201 Spark I 'nti=an cn�r 'A r R@,r ,roil 3 2019 1 I COLORADO ,. .,._..n, Permit Number: 95OPWE038 AIRS iD Number: 1 23 /0099/ 1 04 r ,.. , , 1 Section 2 - Requested Action O NEW permit OR newly-reported emission source (check one below) • STATIONARY source ❑ PORTABLE source • Request coverage under a Construction Permit ❑ Request coverage under General Permit GP02' (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of$1,875 must be submitted along with the APEN filing fee. -OR- Q MODIFICATION to existing permit(check each box below thot applies) ❑ Change fuel or equipment ❑ Change company name' O Add point to existing permit El Change permit limit ❑ Transfer of ownerships O Other(describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS ❑ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario(AOS)permanent replacement6 Additional Info a Notes: Lower NOx permit limit based on portable analyzer test data 3 Only one engine may be reported per APEN for GPO2 coverage. Coverage under GPO?is voluntary. a For company name change,a completed Company Name Change Certification Form(Form APCO-106)must be submitted. 5 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-1041 must be submitted. 6 This does not apply to General Permit GPOZ,as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3. etc.)? Yes If yes, provide the Company Equipment Identification No. C117 / P123 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 12/11/2002 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? htt iw.v_w,colorado.gov/cd heattainment QYes �No Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec-Feb: 25% Mar-May: 25% June-Aug: 25% Sept-Nov: 25% CeLO *bo F�rm APC_C 201 Sp Irk I<Tnr_ron En�lr�e,lpEri 4��,;,Ft, 3.''21)19 2 I ® rt.. Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 104 Section 4 - Engine Information Engine Function: ❑Primary and/or Peaking Power O Emergency(max. 500 hrs/year) Q Compression ❑Pump Jack O Water Pump O Other: What is the maximum number of hours this engine will be used for emergency back-up power? 0 hours/year Engine Make: Waukesha Engine Model: L7042 GSI Serial Number': 337569 What is the maximum designed horsepower rating? 1,100 hp What is the maximum manufacturer's site-rating? 1,100 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8,490 BTU/hp-hr Engine Features: Cycle Type: O 2-Stroke ❑t 4-Stroke Combustion: O Lean Burn 0 Rich Burn Aspiration: O Natural Q Turbocharged Is this engine equipped with an Air/Fuel ratio controller(AFRC)? 0 Yes ❑No If yes, what type of AFRC is in use? ❑O2 Sensor(mV) ❑NO7 Sensor(ppm) O Other: Is this engine equipped with a Low-NO, design? ❑Yes ❑No Engine Dates: What is the manufactured date of this engine? 10/05/1979 What date was this engine ordered? < 10/1979 What is the date this engine was first located to Colorado? < 1986 What is the date this engine was first placed in service/operation? < 1986 What is the date this engine commenced construction? < 10/1979 What is the date this engine was last reconstructed or modified? NA Is this APEN reporting an AOS replacement engine? O Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested, p coLoaa©o Ft)rIn APCD 201 Spail Ignition En vie APEII Pevisio+) 3 2019 3 I �� "T Permit Number: 95OPWE038 AIRS ID Number: 1 23 /0099/ 1 04 r.,, . 1, Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 4,468,151 / 522,877 Operator Discharge Height Temp. Flow Rate Velocity Above Ground Level Stack ID No, ('F) (ACFM) (ft/sec) (feet) P123 26 1,055 5,377 114 Indicate the direction of the Stack outlet: )check one) ❑✓ Upward ❑Downward ❑Upward with obstructing raincap O Horizontal ❑Other(describe): Indicate the stack opening and size: /Check one) ✓❑Circular Interior stack diameter(inches): 12 ❑Square/Rectangle Interior stack diameter(inches): Interior stack depth (inches): ❑Other(describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100%Load Actual Annual Fuel Use Requested Annual Permit Limit$ (SCF/hour) a (MMSCF/year) `MMSCF/year) 8,984 59.06 78.70 From what year is the actual annual amount? 2018 Indicate the type of fuel used: ❑Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) o Field Natural Gas Heating value: BTU/scf ❑Propane (assumed fuel heating value of 2,30013TU/scf) ❑Landfill Gas Heating Value: BTU/scf D Other(describe): Residue Gas Heating Value (give units): 1,110 Btu/scf 8 Requested values will become permit limitations. Requested limits)should consider future process growth. S If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. coioRivv Form APCIJ 2O1Sp.:arf 1 ;7i�tt2= °� i, 1Eit Rer ��,^ 3!2[)19 4 I HH �„ Permit Number: 95OPWE038 AIRS ID Number: 1 23 /0099/ 1 04 N.,,,_[,, _ �., ., , . .;,,..,l 6 V Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑No If yes, describe the control equipment AND state the overall control efficiency(%reduction): Overall Requested Control Pollutant Primary Control Equipment Description Efficiency (%reduction in emissions) TSP (PM) ---- PM 10 PM25 SO NOx NSCf? 830 VOC CO NSCR 72% Other: NSCR 76-'5(formaldehyde) 50'.(Other HAPs) Use the following tables to report criteria and non-criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2018 Criteria Pollutant Emissions Inventory Requested Annual Permit Emission Factor Actual Annual Emissions10 Emission Limit(s)8 Pollutant Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis Units (AP-42, Emissions Emissions Emissions Emissions Mfg.etc) (tons/year) (tons/year) (tons/year) (tons/year) TSP (PM) 1 94E-02 Ib/MMBiu AP-42 0.64 0.64 0.79 0 79 '- Philp 1 940-07 1b/MMBiu AP-02 064 0.54 0.79 0 79 PM2,5 1.94E-02 Ib)MMB1u AP-42 064 0.64 079 079 SOx 5.86E-04 INMMBlu AP-42 0.02 0.02 .002 002 NOx 130 yhy-hr Mfg 11062 2130 138.09 2400 VOC 0.5 9/hp-hr Mfg 4.15 ,... _ 4.25 5.31 5.31 CO --� 5.0 9A7P-hr Mfg. 76.59 21,30 9560 26.55 Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 0 Yes 0 No lbs/year? If yes, please use the following table to report the non criteria pollutant(HAP)emissions from source: Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions10 Abstract Chemical Name Source Uncontrolled Controlled Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions Number Basis Mfg.etc) (pounds/year) (pounds/year) Formaldehyde 50000 2 05E-02 IbiYM8lu AP-42 1 343.57 322 46 Acetaldehyde 75070 Acrolein 107028 Benzene 71432 Other: _ ti Requested values will become permit limitations. Requested limit(sl should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank, lir coLsonsoo Form APCD 201 Spark ignition En, .,APEIJ R,?visfo/1 3�2019 5 ._. �,_..�f. Permit Number: 95OPWE038 AIRS ID Number: 1 23 /0099/ 104 (laa b`,ii un!.•.,s APCC ha;a! Oall iS:t ncd,a r„=i+ii ::and AIRS ID Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP02. ‘17/,e- 141/1 ci Signature of Legally Authorized Person(not a vendor or consultant) Date Marie Cameron Senior Environmental Engineer Name(please print) Title Check the appropriate box to request a copy of the: Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made(significant emissions increase, increase production, new equipment,change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with$191.13 and the General Permit For more information or assistance call: registration fee of$1,875, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692.3175 or(303)692.3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692.3150 Denver,CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www.colorado.gov/cdphe/apcd COLORADO Form APC©-2O1 Spark Ignitbm Engine APEN • Revi>iim 3/2019 6 I �� wn; a^�-, �aPl�f Spark Ignition Engine APEN ta Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for spark ignition(e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e.g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source(e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200)is available if the specialty APEN options do not meet your reporting Deeds. A list of all available APEN forms can be found on the Air Pollution Control Division(APCD)website at: www.colorado.gov/cdphe/aped. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel ty(Te, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 105 r 1e sr APCD has already assr fled a permit aEel AIRS lDI Section 1 -Administrative Information Company Name': DCP Operating Company, LP Site Name: Greeley Natural Gas Processing Plant Site Location Site Location: SW 1/4 Section 25, T5N, R66W County: Weld NAICS or SIC Code: 1311 Mailing Address: (Include Zip Cade) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 Portable Source Home Base: E-Mail Address;Home 'Use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes wilt require additional paperwork. z Permits,exemption letters.and any processing invoices will be issued by the APCD via e-mail to the address provided. 42959E COlOR1,00 Form APCG•2C11 Spar", Ignilirm Enure s',PEF' Rev 3on 3/X'19 1 .. ..., Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 105 Section 2 - Requested Action ❑ NEW permit OR newly-reported emission source(check one below) ❑ STATIONARY source O PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023(Natural Gas Only) If General Permit coverage is requested,the General Permit registration fee of$1,875 must be submitted along with the APEN filing fee. -OR- ✓❑ MODIFICATION to existing permit (check each box below that appt;es) Add point to existing O Change fuel or equipment O Change company name" O permit Q Change permit Limit O Transfer of ownership') O Other(describe below) -OR- ❑ APEN submittal for update only(Blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ❑ APEN submittal for permit-exempt/grandfathered source O Notification of Alternate Operating Scenario(AOS)permanent replacement6 Additional Info& Notes: Lower NOx permit limit based on portable analyzer test data 'Only one engine may be reported per APEN for GPO?coverage.Coverage under GP02 is voluntary, 4 For company name change,a completed Company Name Change Certification Form (Form APCD 106)must be submitted. 5 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. b This does not apply to General Permit GPOZ,as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-i, Engine 3, etc.)? Yes If yes, provide the Company Equipment Identification No. C118/P124 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 2/19/2003 For new or reconstructed sources, the projected start-up date is: Wilt this equipment be operated in any NAAQS nonattainment area? ID httI', //www.co(orado.gov/cd he/attainment Yes U No ( —' p ) Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec-Feb: 25% Mar-May: 25% June-Aug: 25% Sept-Nov: 25% 2 I L?1 ccwn.aa F;r m A ,, 2;�i Spark 1?, i_, . _ :1P�11 Rer.3.,r-t 3 2.019 �,. „ Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 105 Section 4 Engine Information Engine Function: ❑Primary and/or Peaking Power ❑Emergency(max. 500 hrs/year) 0 Compression ❑Pump Jack ❑Water Pump ❑Other: What is the maximum number of hours this engine will be used for emergency backup power? hours/year Engine Make: Waukesha Engine Model: L7042 GSI Serial Number': 286434 What is the maximum designed horsepower rating? 1,100 hp What is the maximum manufacturer's site-rating? 1,100 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8,490 BTU/hp-hr Engine Features: Cycle Type: ❑2-Stroke 0 4Stroke Combustion: O Lean Burn 0 Rich Burn Aspiration: O Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes ❑No If yes, what type of AFRC is in use? 0 O2 Sensor (mV) ❑N05 Sensor (ppm) ❑Other: Is this engine equipped with a Low•NOx design? ❑Yes 0 No Engine Dates: What is the manufactured date of this engine? 4/09/1975 What date was this engine ordered? <4/1975 What is the date this engine was first located to Colorado? <4/1975 What is the date this engine was first placed in service/operation? < 4/1975 What is the date this engine commenced construction? <4/1975 What is the date this engine was last reconstructed or modified? NA Is this APEN reporting an AOS replacement engine? ❑Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested. ^ CEO LOR�DO Form APCf) ?0' SDd'., l t €� cry�, AAPENR'-.;•c, 3:2019 3 I a3M;A �r�, Permit Number: 95QPWE038 AIRS ID Number: 123 /0099/ 105 Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 4,468,151 / 522,877 iNso arge`Height Gpera or Temp; Flog Rats Veltty. Above Ground level Stack JD No. - ('F) + (ACFM) lftlsoc) .. (feet) P124 26 1,055 5,377 114 Indicate the direction of the Stack outlet: (check one) 0 Upward O Downward O Upward with obstructing raincap Horizontal O Other(describe): Indicate the stack opening and size: (check one) Q Circular Interior stack diameter(inches): 12 El Square/Rectangle Interior stack diameter(inches): Interior stack depth(inches): Other(describe): Section 6 Fuel Data and Throughput Information Fuel Use Rate @ 9Ot Load ,- etuat Annual Fuel Use, Requested Annual Permit Limit$ (SCF Thour) (MMSCF/year) CMM.SCF1� ' 8,984 59.12 78.70 From what year is the actual annual amount: 2018 Indicate the type of fuel used': E Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) O Field Natural Gas Heating value: BTU/scf O Propane (assumed fuel heating value of 2,300 BTUtscf) Landfill Gas Heating Value: BTU/scf ✓�Other(describe): Residue Gas Heating Value(give units): 1,110 Btuiscf B Requested values will become permit limitations. Requested iimitlsk should consider future process growth. 9 if fuel heating value is different than the listed assumed value,provide this information in the"Other'field. ley j I CO OgAPO 3 _ F4,q 2Cc�n��w;i ��<t'a lay ie�=�t ��,�,,: A ��- Permit Number: 95OPWE038 AIRS ID Number: 1 23 /0099/ 1 05 Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? Q Yes ❑No If yes, describe the control equipment AND state the overall control efficiency(%reduction): Overall Requested Control Pollutant Primary Control Equipment Description Efficiency (%reduction in emissions) TSP(PM) PM10 PM 2.5 NOX__.___._.__. NSCR 83' VOC CO ._.......- NSCR 72'4, --' Other: NSCR 76`7.1 lorrnaldohytlel 5091,1Other NAPsj Use the following tables to report criteria and non-criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2018 Criteria Pollutant Emissions Inventory Requested Annual Permit Emission Factor Actual Annual Emissions10 Emission Limit(s)8 Pollutant Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Basis Units (AP-42, Emissions Emissions Emissions Emissions Mfg.etc) (tons/year) (tons/year) (tons/year) (tons/year) TSP(PM) 1.94E-02 Ib/MM8tu AP-42 064 064 079 079 PM,o 1 94E-02 Ib/MMBlu AP-42 064 064 -__ 079 079 PM 2.5 1 94E-02 Ib/MMBtu AP-42 064 0.64 0 79 0 79 5O9 558E-04 Ib+MMBtu AP-4 002 002 00? 002 NO0 130 g/hp-hi Mfg 11073 2)32 13809 2400 VOC 0.5 gTC h, Mfg 4 26 4 26 5 31 5.31 ,_._.. -CO 90 91hP-hr Mfg 7665 2132 95.60 2655 Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP - hazardous air pollutant)equal to or greater than 250 0 Yes O No lbs/year? If yes, please use the following table to report the non-criteria pollutant (HAP)emissions from source: Non-Criteria Reportable Pollutant Emissions inventory Chemical Emission Factor Actual Annual Emissionsi0 Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions Number Basis Mfg.etc) (pounds/year) (pounds/year) Formaldehyde 50000 2 05E-02 I5/MMBtu AP-42 1.344 84 322 75 Acetaldehyde 75070 . Acrolein 107028 Benzene 71432 Other: B Requested values will become permit limitations. Requested limits)should consider future process growth. to Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. ccl,oAoo Form APi_[Hi)1 Spark. Ig1 1,I Eivite APE Ii Revision 3'2019 5 �' � Permit Number: 95OPWE038 AIRS ID Number: 123 /00991 105 [Leave b1anF unless APCD i as alley ly a.si,,, <t rnit AIPS 10 Section 8 -Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP02. 7.free Signature of Legally Authorized Person(not a vendor or consultant) Date Marie Cameron Senior Environmental Engineer Name(please print) Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance El Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made(significant emissions increase,increase production, new equipment,change in fuel type,etc.).See Regulation No. 3,Part A, II.C. for revised APEN requirements. � I Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of$1,875, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692.3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692.3150 Denver,CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www.cotorado.gov/cdphe/aped AV' COLORADO Form APCD 20( Spark Ignition Engine APEN - Revision 3/2019 6 I [V' ».m;.s," , Spark Ignition Engine APEN CDPHE CO Form APCD-201 • Air Pollutant Emission Notice(APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and wilt require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for spark ignition (e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e.g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source(e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.), In addition, the General APEN(Form APCD-200)is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division(APCD) website at: www.colorado.gov cdphe/aped. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment,change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 107 iLcave bLtl,k APCD has already a,sre,e i a permit r:a„ti AIR,tD Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Greeley Natural Gas Processing Plant Site Location Site Location: SW 1/4 Section 25, T5N, R66W County: Weld NAICS or SIC Code: 1311 Mailing Address: (Include lip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran „ __....__ Phone Number: 303-605-2039 Portable Source Home Base: E-Mail Address2: rshankaran@dcpmidstream.com ' Use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via email to the address provided. 429597 //A COLORADO Form A'PCI 201 Spa 1.,3 lion F me A?t.1'� Po is,on 3:2019 1 I i' t k... t_....a., Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 107 Section 2 Requested Action O NEW permit OR newly-reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source O Request coverage under a Construction Permit ❑ Request coverage under General Permit GP02 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of$1,875 must be submitted along with the APEN filing fee. -OR- Q MODIFICATION to existing permit (check earn box below that applies) O Change fuel or equipment ❑ Change company name-0 O Add point to existing permit 0 Change permit limit O Transfer of ownerships O Other(describe below) -OR- D APEN submittal for update only(Blank APENs will not be accepted) •ADDITIONAL PERMIT ACTIONS - El APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario(AOS)permanent replacement' Additional Info Et Notes: Lower NOx permit limit based on portable analyzer test data 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change,a completed Company Name Change Certification Form (Form APC©•106)must be submitted. 5 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCO-104)must be submitted. 6 This does not apply to General Permit GP02.as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3. etc.)? Yes If yes, provide the Company Equipment Identification No. C120 / P126 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 1/14/1986 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http;i/www.colorado. ov/cd he/attainment) Ej Yes O No Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec-Feb: 25% Mar-May: 25% June-Aug: 25% Sept-Nov: 25% COLADO r irm AP`r 2'i% 'p irk I nlfl�,�n ri?[ne APEIJ Rev1'>;Za 3'20Ici 2 �® OR Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 1 07 Section 4 - Engine Information Engine Function: 0 Primary and/or Peaking Power 0 Emergency(max. 500 hrs/year) 0 Compression Pump Jack ❑Water Pump 0 Other: _ What is the maximum number of hours this engine will be used for emergency back-up power? 0 hours/year Engine Make: Waukesha Engine Model: L7042 GSI Serial Number': 388531 What is the maximum designed horsepower rating? 1,100 hp What is the maximum manufacturer's site-rating? 1,100 hp kW What is the engine Brake Specific Fuel Consumption at 100%Load? 8,490 BTU/hp-hr Engine Features: Cycle Type: 0 2-Stroke D 4-Stroke Combustion: O Lean Burn J Rich Burn Aspiration: ❑Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller(AFRC)? Q Yes ❑No If yes, what type of AFRC is in use? 0 02 Sensor(mV) DNOx Sensor(ppm) ❑Other: Is this engine equipped with a Low-NO,c design? El Yes D No Engine Dates: What is the manufactured date of this engine? 4/12/1985 What date was this engine ordered? <4/1985 What is the date this engine was first located to Colorado? <6/12/2006 What is the date this engine was first placed in service/operation? <6/12/2006 What is the date this engine commenced construction? <6/12/2006 What is the date this engine was last reconstructed or modified? NA Is this APEN reporting an AOS replacement engine? []Yes Q No If yes, provide the make, model, an/serial number of the old engine below: Engine Make: Engine Model: Serial Number. 'The serial number must be submitted if coverage under GP02 is requested. COLORADO Form APCD 201 Spark. Ikn,tuon Fnu:le APErl R'-i,ron 3/2019 3 I 0104� Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 1 07 Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 4,468,151 / 522,877 Operator Discharge Height Temp. Flow Rate Velocity Above Ground Level Stack ID No. a F) (AMU (ft/ses) (feet) P126 28 1,055 5,377 114 Indicate the direction of the Stack outlet: (check one) p Upward ❑Downward ❑Upward with obstructing raincap Horizontal O Other(describe): Indicate the stack opening and size: lcneck ono Q Circular Interior stack diameter(inches): 12 Ej Square/Rectangle Interior stack diameter (inches): Interior stack depth (inches): Other(describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate®1009Cl oad Actual Annual Fuel Use Requested Annual Permit Limit& (SCE/hour) (MMSCF/year) - (MMSCF%year) r 8,984 5718 78.70 From what year is the actual annual amount? 2018 Indicate the type of fuel used': Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) O Field Natural Gas Heating value: BTU/scf Ej Propane (assumed fuel heating value of 2,300 BTU/scf) Landfill Gas Heating Value: BTU/scf 0 Other(describe): Residue Gas Heating Value(give units): 1,110 Btu/scf 9 Requested values will become permit limitations. Requested limit is)should consider future process growth. 9 If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. Q i� _i I COlORA0O F1�~? 2,)f��) f.'1 �`. �'::�tl il�i�i Engine r1PC.iw ft'L'-�1>':;Ei ;/iJ l'� Permit Number: 95OPWE038 AIRS ID Number: 1 23 /0099/ 107 ,- .,,cr_ ,tit : , . Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? 0 Yes O No If yes, describe the control equipment AID state the overall control efficiency(% reduction): Overall Requested Control Pollutant Primary Control Equipment Description Efficiency (%reduction in emissions) TSP(PM) PM10 PM2.5 5O9 NOx NSCR 63% VOC -- — CO NSCP 12% Other: NSCR ._—J -- J 76%(formaldehyde) 50%1Otrwr r1AP]I Use the following tables to report criteria and non criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2018 Criteria Pollutant Emissions Inventory Requested Annual Permit Emission Factor Actual Annual Emissions10 Emission Limit(s)8 Pollutant Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis Units (AP-42, Emissions Emissions Emissions Emissions Mfg.etc) (tons/year) (tons/year) (tons/year) (tons/yeor) TSP(PM) 1.949.02 ib/MY Btu AP-42 0.62 0.62 0 79 0 7 PM 10 194E-02 lb/M1.48tu AP-42 062 0.62 0.79 0.79 PM 2.5 1 94E-02 IaMMBIu AP 42 0 62 0 62 0 79 0 79 SOx 5.88E-04 INMMBtu AP-42 002 0.02 002 002 NOx 130 glhphr Mfg 10424 2084 17809 24,00 VOC 0.5 cop-hr Mfg 4 16 4 16 5 31 5 31 �� CO 9.0 gtp+u Mfg . 7494 2084 9560 2655 Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP hazardous air pollutant)equal to or greater than 250 0 Yes O No lbs/year? If yes, please use the following table to report the non-criteria pollutant (HAP)emissions from source: Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions10 Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) Uncontrolled Units Basis (AP-42, Emissions Emissions Number _ Mfg.etc) (pounds/year) (pounds/year) Formaldehyde 50000 205E-02 Io1MMBlu AP42 1 314 68 315.52 Acetaldehyde 75070 Acrolein 107028 Benzene 71432 i Other: 8 Requested values will become permit limitations. Requested limit is)should consider future process growth. tS Annual emissions fees will be based on actin')controlled emissions reported. If source has not yet started operating.leave blank. , C01.08•00Fit ni APi D-i?I plr`'.'. L.,, th)h. f._ g e r\:'trf Poi„sIon 3='2014 5 I . C �., Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 107 AE'%CG Ire lR�-?:1 I, �:ei;ai'�1 l permit 7 and AIRS Ili Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP02. lam- IVirnajO2- I A// g/, �1 Signature of Legally Authorized Person(not a vendor or consultant) Date Marie Cameron Senior Environmental Engineer Name(please print) Title Check the appropriate box to request a copy of the: O Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with$191.13 and the General Permit For more information or assistance call: registration fee of$1,875,if applicable,to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692.3175 or(303)692.3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692.3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www.colorado.Rov/cdohe/aped ARM 6 coLoR.00 Form APCD 201 Spark IgnitionEn�Ine APENF .i,1;;i 33/2019 • ;4- r ` CDPNE Spark Ignition Engine APEN Form APCD-201 CO ! Air Pollutant Emission Notice (APEN) and Application for Construction Permit AU sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or tacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for spark ignition(e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e... diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific ADEN for your source(e.g.compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN(Form APCD-200) is available if the specialty APEN options do not meet your reporting reeds. A list of all available APEN forms can be found on the Air Pollution Control Division(APCD)website at: www.colorado.gov/cdphe-apcd. This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment,change in fuel type,etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE038 AIRS ID Number: 1 23 /0099/ 110 [Leave bi.10 itlpSs APCD h a,a!rea1, c a pnrrni n.uri AIPS#D] Section 1 - Administrative Information Company Name': DCP Operating Company, LP _ Site Name: Greeley Natural Gas Processing Plant Site Location Site Location: SW 1/4 Section 25, T5N, R66W County: Weld NAICS or SIC Code: 1311 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 Portable Source E-Mail Address?: Home Base: rshankaran@dcpmidstream.com ' Use the full,legal company name registered with the Colorado Secretary of State.This is the company name that wilt appear on all documents issued by the APCD. Any chaages will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. 429598 Form AP(.[) 2Qi Spark lgniti„n Engine A{ N Revision 3/2019 1 I AY �ai�w.00 Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 1 1 0 Section 2 - Requested Action ❑ NEW permit OR newly-reported emission source check one below) ❑ STATIONARY source ❑ PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023(Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of$1,875 must be submitted along with the APEN filing fee. -OR- 0 MODIFICATION to existing permit (check Pt,k bu,below that oppi+es) ❑ Add point to existing Change fuel or equipment ❑ Change company name° ❑ permit ❑� Change permit limit ❑ Transfer of ownerships O Other(describe below) -OR- ❑ APEN submittal for update only(Blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS - ▪ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario(AOS)permanent replacement" Additional Info& Notes: Lower NOx permit limit based on portable analyzer test data 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GPO2 is voluntary, °For company name change, a completed Company Name Change Certification Form (Form APCD 106)must be submitted. S For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted, This does not apply to General Permit GPO?,as it does not contain a provision for AOS permanent replacements. Section 3 General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? Yes If yes, provide the Company Equipment Identification No. C122 / P129 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 4/14/2006 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? htt t www.colorado.govicdphe/attainrnent ❑Yes ❑No Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec-Feb: 25% Mar-May: 25% June-Aug: 25% Sept-Nov: 25% COLORADO AV F;,,iT .�,='C.:1 ?'1 tiplt}�. I�; i,;G� Engine AP- ��•_� ;i 1,2J19 2 I �' Permit Number: 950PVVE038 AIRS ID Number: 123 /0099/ 110 Section 4 - Engine Information Engine Function: ❑Primary and/or Peaking Power ❑Emergency(max. 500 hrs/year) Compression O Pump Jack O Water Pump O Other: What is the maximum number of hours this engine will be used for emergency back-up power? 0 hours/year Engine Make: Waukesha Engine Model: L7042 GSI Serial Number?: 260928 What is the maximum designed horsepower rating? 1,100 hp What is the maximum manufacturer's site-rating? 1,100 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8,490 BTU/hp-hr Engine Features: Cycle Type: O 2-Stroke 0 4-Stroke Combustion: O Lean Burn Q Rich Burn Aspiration: ❑Natural Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑Yes ❑No If yes, what type of AFRC is in use? 102 Sensor (mV) ❑N05 Sensor(ppm) O Other: Is this engine equipped with a Low-NOr design? ❑Yes ❑No Engine Dates: What is the manufactured date of this engine? < 4/2006 What date was this engine ordered? <4/2006 What is the date this engine was first located to Colorado? <4/2006 What is the date this engine was first placed in service/operation? <4/2006 What is the date this engine commenced construction? <4/2006 What is the date this engine was last reconstructed or modified? NA Is this APEN reporting an AOS replacement engine? O Yes Q No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted 0 coverage under GP02 is requested. �� COlOR4pO Form FOP:D 201 Spar' I�ntilix E Trio APENRey: >� �� 3,'2019 3 I m _._, Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 110 Section 5 - Stack Information j Geographical Coordinates (Latitude/Longitude or UTM) 4,468,151 / 522,877 Discharge Height Operator Temp. Flow Rate Velocity .Above Ground Level Stack ID No.('F1 ACFM)' � 'ftfsec) : (feet) i . P129 27 1,055 5,377 114 Indicate the direction of the Stack outlet: (clrec&one) Upward Q Downward Q Upward with obstructing raincap Horizontal O Other(describe): Indicate the stack opening and size: (check ones Circular Interior stack diameter(inches): 12 ❑Square/Rectangle Interior stack diameter(inches): Interior stack depth(inches): Q Other(describe): Section 6 - Fuel Data and Throughput Information Fuel Use`Rate @ 1w00%Load Actual Annual Fuel Use a, Requested Annual Permit Limits .,(SCF/i1 rj (MMSCF/Year) . 8,984 58.28 78.70 From what year is the actual annual amount? 2018 Indicate the type of fuel used: ®Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) O Field Natural Gas Heating value: BTU/scf ®Propane. (assumed fuel heating value of 2,300 BTU/scf) O Landfill Gas Heating Value: BTU/scf D Other(describe): Residue Gas Heating Value(give units): 1,110 Btu/scf 8 Requested values will become permit limitations. Requested limitlsi should consider future process growth. 9 If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. coi3ON ADO Firth ¢1£x.1 211 Sp irk: i ri=tuft F rsgine APFt1 Re,i. ,_, 1•2019 4 1 1 Permit Number: 95OPWE038 AIRS ID Number: 1 23 /0099/ 110 I ... , Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? Q Yes O No If yes, describe the control equipment AND state the overall control efficiency(%,reduction): Overall Requested Control Pollutant Primary Control Equipment Description Efficiency Of reduction in emissions) TSP(PM) . PM10 PM 2.5 SOx NOx NSCR 83'., VOC CO NSCR 72% Other: NSCR 76'- ,formaJdehyle) 50=r;.tOrNer HAPS,N Use the following tables to report criteria and non-criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data 2018 Criteria Pollutant Emissions Inventory Requested Annual Permit Emission Factor Actual Annual Emissions"' Emission Limit(s)8 Pollutant Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Basis Units (AP-42, Emissions Emissions Emissions Emissions Mfg.etc) (tons/year) (tons/year) (tons/year) (tons/year) TSP(PM) 1.94E-02 Ip7MMBL AP-41 0 63 0 63 0 79 C 79 PM10 1,94E-02 lb/Wm, AP-42 0 63 0.63 0 79 079 PM 2,5 194E-02 IUrMMB,u AP-42 063 0.63 0 79 C 79 SOx 5.88E-04 IbMMMBlu AP-42 0.02 0.02 002 0.07 NOx 13.0 9lhFnr Mfg 1091;. �. 2102 13809 ---- 24.00 VOC .0 5 DTP-hr Mfg 4 20 4 20 5.31 5 31 CO 9 0 941041 Mfg 75 57 21 02 9560 20.55 Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g, HAP hazardous air pollutant)equal to or greater than 250 0 Yes O No lbs/year? If yes, please use the following table to report the non-criteria pollutant (HAP)emissions from source: Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions10 Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) Uncontrolled Units Basis (AP-42, Emissions Emissions Number Mfg.etc) (pounds/year) (pounds/year) _— Formaldehyde 50000 2 05E-02 IDIMMBI, AP-42 1 325-91 319 22 Acetaldehyde 75070 — Acrolein 107028 Benzene 71432 !_ Other: _^ _ 8 Requested values will become permit limitations. Requested limit(sl should consider future process growth. w Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. �y COLORADO Firm AP..D ;t01 Spark i n;;uxt En;1ri� AP€ F..� ;f'1�- 3.'20 5 I A "'' - Permit Number: 95OPWE038 AIRS ID Number: 1 23 /0099/ 110 h1 INV ss APCD o permit =arid AIR')ID Section 8 -Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP02. / 1 LA 8 G Signature of Legally Authorized Person(not a vendor or consultant) Date Marie Cameron Senior Environmental Engineer Name(please print) Title Check the appropriate box to request a copy of the: ❑Draft permit prior to issuance ❑Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made(significant emissions increase, increase production, new equipment,change in fuel type,etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with$191.13 and the General Permit For more information or assistance call: registration fee of$1,875,if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692.3175 or(303)692.3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692.3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www.colorado_gov/cdphe/apcd pqiv CCLOIIADO Form APCD 201 Spark Ignition Engine APEII R, vi;itm 3/2019 6 I 4334w. w`n "'^'` ACHydrocarbon Liquid Loading APEN '� Form APCD-208 CDPHE Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for hydrocarbon liquid loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, glycol dehydration unit, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200)is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division(APCD)website. This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE038 AIRS ID Number: 123 / 0099 /115 Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Greeley Natural Gas Processing Plant Site Location Site Location: SW 1/4, Sec 25,T5N, R66W County: Weld . 3489 49th Street, Evans CO NAICS or sic Code: 1321 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 E•Mail Address2: RShankaran@DCPMidstream corn ' Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD. Any charges will require additional paperwork. 2 Permits,exemption letters,and'any processing invoices will be issued by the APCD via e-mail to the address provided. 429599 p, COLORADO MP Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/115 Section 2 - Requested Action ❑ NEW permit OR newly-reported emission source O Request coverage under construction permit ❑ Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of$312.50 must be submitted along with the APEN filing fee. -OR- ❑Q MODIFICATION to existing permit ((heck each box below that applies) ❑ Change fuel or equipment O Change company name3 ❑ Change permit limit O Transfer of ownership ❑Q Other(describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS - • Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info& Notes: Update calculation methodology - retain existing VOC emission limit, slightly increased corresponding throughput limit + unit change from MMgal/yr to loads/yr For company name change, a completed Company Name Change Certification Form (Form APCD-106)must be submitted. For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted, Section 3 - General Information General description of equipment and purpose: pressurized product truck loadout rack Company equipment Identification No. (optional?: P135 For existing sources, operation began on: 1/01/1990 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? 0 Yes ❑ No Is this equipment located at a stationary source that is considered a Major Source of(HAP) ❑ Yes 0 No emissions? Does this source load gasoline into transport vehicles? O Yes p No Is this source located at an oil and gas exploration and production site? ❑ Yes (] No If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual ❑ Yes O No average? Does this source splash fill less than 6,750 bbl of condensate per year? O Yes O No Does this source submerge fill less than 16,308 bbl of condensate per year? O Yes O No co LOIA pO Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 115 Section 4 - Process Equipment Information Product Loaded: ❑ Condensate ❑ Crude Oil If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded5: bbl/year Actual Volume Loaded: bbl/year This product is loaded from tanks at this facility into: (e.g. "rail tank cars"or "tank trucks") If site specific emission factor is used to calculate emissions,complete the following: Average temperature of Saturation Factor: bulk liquid loading: Molecular weight of True Vapor Pressure: Psia ®60 'F lb/lb-mol displaced vapors: If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: 13,426,175 bbl/year Actual Volume Loaded: 2,309,341 bbl/year Product Density: See Below Ib/₹N Load Line Volume: 0.0327 ft3/truckload Vapor Recovery Line Volume: 0.0436 ft'/truckload 5 Requested values will become permit limitatiens or will be evaluated for exempt status,as applicable, and should consider future process growth. Requested values are required on all APENs,including APEN updates. ' Hl'(n.t.l�'�r I III U1l' I al! �,°c.!r°,tJ; t's 11='tl M G\{,s.'i (,ratk,N.tittrAI t „,rohnc I tytrdti I Nttl v,;cN)I�te,l�`tr Butm, ��. lh.'it- t��r�I 'LI.=-I" I III:II 't=n1.n . ,ay-l�,It Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40,36422/-104.73045 O Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Discharge Height Above Temp. Flow Rate Velocity Stack ID No. Ground Level(Feet) (-F) (ACFM) (ft/sec) P135 Indicate the direction of the stack outlet: (check one) 0 Upward ❑ Downward 0 Upward with obstructing raincap ❑ Horizontal ❑Other (describe): Indicate the stack opening and size: (cheer one) 0 Circular Interior stack diameter (inches): ❑Square/rectangle Interior stack width (inches): Interior stack depth (inches): O Other (describe): apb , COLORADO 3 ..o. Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/115 Section 6 - Control Device Information O Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. • Loading occurs using a vapor balance system: Requested Control Efficiency: 100 Used for control of: Rating: MMBtu/hr Combustion Type: Make/Model: _ ❑ Device: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: Minimum Temperature: F Waste Gas Heat Content: Btu/scf Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating: MMBtu/hr Pollutants Controlled: ❑ Other: Description: Requested Control Efficiency: Section 7 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? O Yes Q No If yes,describe the control equipment AND state the collection and control efficiencies(report the overall, or combined, values if multiple emission control methods were identified in Section 6): Collection Efficiency Control Efficiency Pollutant Control Equipment Description (%of total emissions captured (%reduction of captured b control .ui.ment emissions PM SOx NOx CO VOC HAPs Other: ❑ Using State Emission Factors (Required for GP07) VOC Benzene n•Hexane O Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL ❑ Crude 0.104 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data:' 2018 Use the following table to report the criteria pollutant emissions from source: Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Pollutant Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Units (x'42, Emissions Emissions6 Emissions Emissions Basis Mfg.,etc.) (tons/year) (tons year) (tons/year) (tons/year) PM 1' avalt nr ih <:rf SO, NO,, i'r,(a 1r i l CO li;1ta(1c; I- I VOC I See Below' Ib,Mad Eng.Est. 5.8 5.8 43 15 43 15 • NIA • -- I ; 5 Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider future process growth. Requested values are required on all APENs,including APEN updates. Nc,!. - l 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide projected emissions, = 0 0 ZIT Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/115 Section 8 - Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteria Yes D No pollutants(e.g. HAP - hazardous air pollutant)equal to or greater than 250 lbs/year? If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: Chemical Emission Factor Actual Annual Emissions Abstract Source Uncontrolled Controlled Chemical Name Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions6 Number Basis Mfg.,etc.) (lbs/year) (lbs/year) ) Benzene 71432 I 3.01E-02 RAW Erg.Est 1,699 1.699 Toluene 108883 188E-02 Woad Erg.Esl 1,060 1.960 Ethyibenzene 100414 4.65E-04 mooed Eng Est 27 27 Xylene 1330207 2.47E-03 Woad Eng Est 139 139 n-Hexane 110543 230E-01 ronoed Enq.Eel 12,961 12.881 2,2,4-Trimethylpentane 540841 539E-03 rodoetl Eng.Etc 304 304 Other:Methanol 67561 194E-05 bAaed Erg.Est 1 1 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide projected emissions. Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. if this is a registration far coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP07. 7‘Y.-e,e Ann-e)71Z--'/ /?/# Signature of Legally Authorized Person(not a vendor or consultant) Date Marie Cameron Senior Environmental Engineer Name(print) Title Check the appropriate box to request a copy of the: ❑Draft permit prior to issuance ❑Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type,etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with$191.13 and the General Permit For more information or assistance call: registration fee of$312.50, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 Air Pollution Control Division OR APCD-SS-B1 (303)692-3148 4300 Cherry Creek Drive South Denver,CO 80246-1530 APCD Main Phone Number (303)692.3150 Make check payable to: Colorado Department of Public Health and Environment t:OLOEAOO rn;lf` _ !.'`:3 Ili 1 rr.•' trt. 11 /,FLft Lrvlylr'iit Iii..>.UI 5 Hydrocarbon Liquid Loading APEN 11 Form APCD-208 x3 :t �` CDPHE Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittcl will require payment for a new filing fee. This APEN is to be used for hydrocarbon liquid loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source(e.g. amine sweetening unit, glycol dehydration unit, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200)is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE038 AIRS ID Number: 123 / 0099 /115 [Leave ave bian .untess APCD has already assigned a perr.it#and AIRS ID[ Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Greeley Natural Gas Processing Plant Site Location:• Site Location SW 1/4, Sec 25, T5N, R66W County: Weld 3489 49th Street, Evans CO NAICS or SIC Code: 1321 Mailing Address: (include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 E-Mail Address2: RShankaran@DCPMidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that wilt appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. 423526 i COLORADO For-n-1 APCD 29 Hydrocarbon Liquid Loading APEN Revision 12/20t9 1 I Health 6n�.. `eani Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/115 tt and AIRS I51 Section 2 - Requested Action O NEW permit OR newly-reported emission source O Request coverage under construction permit ❑ Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of$312.50 must be submitted along with the APEN filing fee. -OR- Q MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment ❑ Change company name3 ❑ Change permit limit ❑ Transfer of ownership' I] Other(describe below) -OR- i ❑ APEN submittal for update only(Note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info Et Notes: Update calculation methodology - retain existing VOC emission limit, slightly increased corresponding throughput limit + unit change from MMgal/yr to loads/yr 3 For company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted. 4 For transfer of ownership,a completed Transfer of Ownership Certification Form(Form APCD-104)must be submitted. Section 3 - General Information General description of equipment and purpose: pressurized product truck loadout rack Company equipment Identification No. (optional): P135 For existing sources, operation began on: 1/01/1990 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? Q Yes ❑ No Is this equipment located at a stationary source that is considered a Major Source of(HAP) ❑ Yes Q No emissions? Does this source load gasoline into transport vehicles? O Yes 0 No Is this source located at an oil and gas exploration and production site? O Yes ❑ No If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual O Yes O No average? ' Does this source splash fill less than 6,750 bbl of condensate per year? O Yes O No Does this source submerge fIl less than 16,308 bbl of condensate per year? O Yes ❑ No (COLORADO Form H'l.J-2U i"I�'drt c? Lu i Liquid Loading APEN c'd'S7->.7 12/2019 2 1 Ir ima Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/115 �, 4 it ,. <.✓ _c3i, ,s j:_• If Section 4 - Process Equipment Information Product Loaded: O Condensate O Crude Oil D Other: propane Butane B.G me.Y.&,de Izo,enrene N,1 liquids condensate If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded5: bbl/year Actual Volume Loaded: bbl/year This product is loaded from tanks at this facility into: (e.g. "rail tank cars"or "tank trucks") If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: Average temperature of F bulk liquid loading: Molecular weight of True Vapor Pressure: Psia @ 60 F lb/lb-mol displaced vapors: If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: 13,266,191 Requested Volume Loaded5: 13,426,175 bbl/year Actual Volume Loaded: 2,309,341 bbl/year EJC per 6/8/2020 Product Density: See Below lb/ft' email — Load Line Volume: 0.0327 ft3/truckload Vapor Recovery Line Volume: 0.0436 ft'/truckload 5 Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider future process growth. Requested values are required on all APENs,including APEN updates. 55,718 i 'o)hl gailon'toad Propane=3178 Ih/ill fi-(,rMix,Y-Grade,Natural(a ©line I tciuids IN1GI.), 9'0U Inac{ ;ct Butane=36.26 lhlit' (:r�ndcrsatc=46.15 It- (t` lsopentane=38.97 lb/ft' Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.36422/-104.73045 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Discharge Height Above Temp. Flow Rate Velocity Stack ID No. Ground Level(Feet) (',F) (ACFM) (ftlsec) P135 Indicate the direction of the stack outlet: (check one) El Upward O Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) Circular Interior stack diameter(inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth(inches): ❑Other(describe): COLORADO t P r 2CS i G ''t Loadiinfg APEF4 - Revision 12/22019 .� I !> iu rti"t A. r -u t 1t c1 .i"i L" ''. Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/115 (Lea._ _t.Y`k APO) Y_ j_ i and A PS fo Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. ✓❑ Loading occurs using a vapor balance system: Requested Control Efficiency: 100 % Used for control of: Rating: MMBtu/hr Combustion Type: Make/Model: ❑ Device: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: Minimum Temperature: 'F Waste Gas Heat Content: Btu/scf Constant Pilot Light: O Yes ❑ No Pilot Burner Rating: MMBtu/hr Pollutants Controlled: ❑ Other: Description: Requested Control Efficiency: % Section 7 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑Yes Q No If yes, describe the control equipment AND state the collection and control efficiencies(report the overall,or combined, values if multiple emission control methods were identified in Section 6): Collection Efficiency Control Efficiency Pollutant Control Equipment Description (%of total emissions captured (%reduction of captured by control equipment) emissions) PM SOX NOx CO VOC HAPs Other: ❑ Using State Emission Factors(Required for GP07) VOC Benzene n-Hexane ❑ Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL ❑Crude 0.104 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? 2018 Use the following table to report the criteria pollutant emissions from source: Emission Factor Actual Annual Emissions Requested Annual Permit Pollutant Emission Limit(s)5 Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled AP-42 Basis Units ( Emissions Emissions6 Emissions Emissions Mfg.,etc.) (tons/year) (tons/year) (tons/year) (tons/year) PM .111 HULL,in lb'bad SOx NOx Propane= (.11 CO Butane= 1 2 1 VOC See Below.t IbAoad Eng.Est. 5.8 5.8 43.15 43.15 B G Mix_ 1.52 F-Grade:= 1.53 5 Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider lsopcntane= 1.,y future process growth. Requested values are required on all APENs,including APEN updates. NG1.= 1.52 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide Condens;rle= 1 ;;projected emissions. a I COLORADO Form APCD 208 Hydrocarbon Liquid load n ADEN Revision 12%2019 °°•"""""•°`"` Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/115 u=_- SAPCD _ .. -, Section 8 - Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteria (]✓ Yes O No pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 lbs/year? If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: Chemical Emission Factor Actual Annual Emissions Chemical Name Abstract Uncontrolled Source Uncontrolled Controlled Service(CAS) Basis Units (AP-42, Emissions Emissionsb Number Mfg.,etc.) abs/year) (lbs/year) Benzene 71432 3.01E-02 lb/load Eng.Est. 1,699 1699 Toluene 108883 1.88E-02 tbnoad Eng.Est. 1,060 1.060 Ethylbenzene 100414 4.65E-04 Iblload Eng.Est. 27 27 Xylene 1330207 2.47E-03 lb/load Eng.Est 139 139 n-Hexane 110543 2.30E-01 lbnoad Eng.Est. 12,981 12,981 2,2,4-Trimethylpentane 540841 5.39E-03 lb/load Eng.Est. 304 304 Other:Methanol 67561 1.84E-05 lb/load Eng.Est. 1 1 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide projected emissions. Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP07. 7a , e l mte17V Signature of Legally Authorized Person(not a vendor or consultant) Date Marie Cameron Senior Environmental Engineer Name(print) Title Check the appropriate box to request a copy of the: ❑Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of$312.50, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 Air Pollution Control Division OR APCD-SS-B1 (303)692-3148 4300 Cherry Creek Drive South Denver,CO 80246-1530 APCD Main Phone Number (303)692-3150 Make check payable to: Colorado Department of Public Health and Environment COLORA00 For r 1 r,? L t-u :,;_. -. it L1�;,.1.51 Loading APEN Revis c 12'2.. 19 5 1 � ≥ ms .•A .. 6/9/2020 State.co.us Executive Branch Mail-Greeley Operating Permit for Source Review STATE OF Chavez-CDPHE, Elie<elie.chavez@state.co.us> COLORADO Greeley Operating Permit for Source Review Shankaran, Roshini <RShankaran@dcpmidstream.com> Mon, Jun 8, 2020 at 2:21 PM To: "Chavez-CDPHE, Elie" <elie.chavez@state.co.us> Hi Elie, Please see the bulleted insig list below with updates. Sorry this is so confusing, I'm depending on others to site verify and this is the best I can gather. I hope this helps, but definitely please let me know if you have any other questions. I also reviewed the updated conditions and they all look good to me. The APEN is also good to go. Thanks, Roshini Roshini Shankaran Environmental Engineer—Weld County DCP Midstream 370 17th Street, Suite 2500 Denver, CO 80202 Office: 303-605-2039 Cell: 720-391-7005 Creri Midstream From:Chavez-CDPHE, Elie [mailto:elie.chavez@state.co.us] Sent:Thursday,June 4, 2020 9:08 AM To:Shankaran, Roshini<RShankaran@dcpmidstream.com> Subject: Re: Greeley Operating Permit for Source Review Shoot, I have one more question (I knew I should have waited til I got through the engine condition). The insignificant list I had listed the following engines: https://mail.google.com/mail/u/0?ui=2&ik=85031 f40e8&view=lg&permmsgid=msg-f:1668963595226055024 1/11 6/9/2020 State.co.us Executive Branch Mail-Greeley Operating Permit for Source Review • One(1) Briggs&Stratton Emergency Genset 14 hp • One (1) Kohler Command Pro 10 Sweeper Brush Engine • One(1) Methanol Trailer Including: o One(1) Kohler Command Pro 8.5 Engine (this is attached to the methanol trailer but out of service) o One (1) Honda GX240 Engine • One(1) Hotsy Trailer Including: 2. One(1) Kohler Command Pro 8.6 Engine •—Onc (1) Honda CX210 Engine • One Briggs & Stratton (model 303447-1295-E1)—11/01/2001 Just to confirm, both trailers are still out there (so there are still 2 Hondas and 2 Kohler Command Pro 8.5s), but instead of the Kohler Command Pro 10, there's a Briggs&Stratton. Do I have that right? Elie Chavez Permit Engineer Title V Operating Permit Unit Stationary Sources Program Air Pollution Control Division COLORADO ' 44411 Air Pollution Control Division COPHC Department of Public Health 6 Environment P 303.692.6332 4300 Cherry Creek Drive South, Denver, CO 80246-1530 elie.chavez@state.co.us I www.colorado.gov/cdphe/apcd Are you curious about ground-level ozone in Colorado?Visit our ozone webpage to learn more. On Wed,Jun 3, 2020 at 4:21 PM Chavez-CDPHE, Elie<elie chavez@state.co.us>wrote: Hi Roshini, Thanks for the followup! I do want to run a couple of permit conditions by you to make sure you're comfortable with them before I turn this thing over to public notice.Also, I've got an APEN redline I'd like you to ok for the pressurized loadout point(AIRS 115), so I can get that in our system (see attached). For the permit conditions: Pressurized Loadout Sampling: https://mail.google.com/mail/u/0?ui=2&ik=85031 f40e8&view=lg&permmsgid=msg-f:1668963595226055024 2/11 6/9/2020 State.co.us Executive Branch Mail-Greeley Operating Permit for Source Review An initial extended liquids analysis of each of the B-G mix, Y-grade, NGL and condensate shall be obtained within five (5)years of permit issuance according to appropriate ASTM methods, or equivalent, if approved in advance by the Division.Thereafter, extended liquids analyses of each of the B-G mix, Y-grade, NGL and condensate shall be performed every five (5) years from the previous sample date for each species. The extended liquids analysis shall identify the relevant VOC and HAP constituents of the species loaded/unloaded, including any BTEX components. The composition indicated on each analysis may be used as a representative composition for all loading/unloading of that species completed over the next five years from the date on which the sample was taken. Records of the extended liquids analyses shall be maintained and made available to the Division upon request. This sounds good! Purge/Waste Gas Flowrate: The combined purge and waste gas throughput to the plant flare shall be continuously monitored and recorded monthly using the existing flare header flowmeter.All purge and waste gas streams routed to the plant flare shall be introduced upstream of this meter. During periods of flare operation, the lower detection limit of the flare header flowmeter shall be assumed at all times that the metered value cannot be obtained due to a flowrate below the detection limit. Records of the flare header flowmeter readings shall be maintained and made available to the Division upon request. This sounds good. Waste Gas Extended Analysis (and you are correct-you won't need a residue gas sample anymore) An extended gas analysis of the combined purge/waste gas routed to the flare shall be performed annually according to appropriate ASTM methods, or equivalent, if approved in advance by the Division (Colorado Construction Permit 15WE0939, as modified under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part C, Section I.A.7 and Part C, Section III.B.7). The extended analysis shall identify the relevant VOC and HAP constituents of the combined purge/waste gas stream routed to the flare. The purge/waste gas analysis shall be representative of the actual purge/waste gases flared. Results of the extended gas analysis shall be maintained and made available to the Division upon request. The composition and heat content values from combined purge/waste gas obtained from the most recent extended analysis shall be used to monitor compliance with the annual VOC, NOx and CO emission limitations, as required by Conditions 8.1 and 8.2. The combined purge/waste gas composition utilized to monitor compliance with the emissions limitations shall be representative of actual operations during each month. Engineering judgement shall be exercised when determining the appropriate purge/waste gas composition. Sounds good! Let me know if these conditions look good to you/make sense and if the APEN is ok and I'll proceed with public notice! Thanks so much, Elie Chavez Permit Engineer Title V Operating Permit Unit Stationary Sources Program Air Pollution Control Division rn:r- COLORADO Air• Pollution Control Division C0PH Department of Public Health&Environment P 303.692.6332 4300 Cherry Creek Drive South, Denver, CO 80246-1530 elie.chavez@state.co.us I www.colorado.gov/cdphe/aped https://mail.google.com/mail/u/0?ui=2&ik=85031 f40e8&view=lg&permmsgid=msg-f:1668963595226055024 3/11 Street,Midstream 370 F, DC 17th Street, Suite 2500 �/�+j� Denver, Colorado 80202 iII.7l riiQa .. Direct: 303-605-1745 April 30, 2013 /ZC1T = Fax: 303-893-8902 MAY- 1 Air Pollution Control Division Ai'C1% Colorado Department of Public Health and Environment Stab narti APCD-SS-B1 Su.,:wes- 4300 Cherry Creek Drive South Denver, CO 80246-1530 Re: DCP Midstream, LP Greeley Natural Gas Processing Plant Title V Operating Permit No. 95OPWE038 Renewal Application To Whom It May Concern: DCP Midstream, LP (DCP) hereby submits the following renewal application to the above referenced Operating Permit (OP) for the Greeley Natural Gas Processing Plant (Greeley Plant) pursuant to Colorado Air Quality Control Commission (CAQCC) Regulation No. 3, Part C, § lll.B.6. This renewal application includes administrative and minor updates and corrections only. The requested modifications within this renewal application are presented in the applicable Air Pollution Control Division (APCD) Title V forms (attached). In addition, DCP requests the following changes be made to the Greeley Natural Gas Processing Plant OP: • DCP is specifically requesting the deletion of all entries for and references to engine Unit P120, Waukesha F-3521 GSI, serial number 327086. This unit has ceased operation and has been permanently disconnected from service. • DCP is specifically requesting the deletion of all entries for and references to Unit P136, the Triethylene Glycol Dehydrator. This unit has ceased operation and has been permanently disconnected from sery ice. • DCP requests an administrative change to the serial number of unit P127 (C-123). The serial number listed in the current Title V Operating Permit is 268013. The correct serial number is 269013, as listed on the unit itself and was provided in the current APEN. This unit has not been altered or replaced since installation. DCP believes this to have been a typographical error. • To facilitate compliance tracking and equipment references in accordance with onsite plant operations, DCP requests an administrative change to the plant identifiers for all engines. At this time the OP engine plant identifier names are referred to as `P' followed by three numbers. DCP would like to change the plant identifier names, and all entries and references, to a 'C' followed by a three number designation. Please refer to the following table: Current OP Requested OP Engine Identifier Identifier Manufacturer and Model Serial No. P121 C-124 Waukesha F-11 G 5294177 P122 C-116 Waukesha L7042 GSI 261947 P123 C-117 Waukesha L7042 GSI 898468 P124 C-118 Waukesha L7042 GSI 286434 P125 C-119 Waukesha L7042 GSI 327603 P126 C-120 Waukesha L7042 GSI 337569 P127 C-123 Waukesha L7042 GU V 269013 P128 _ C-152 Waukesha L7042 GSI 388531 P129 C-122 Waukesha L7042 GSI 368993 • • To provide applicable regulatory clarity, DCP requests that Section I, Condition 2.3.4 be revised read as follows(underlined text and table are added): 2.3.4 Area Source for HAPs A permanent replacement engine located at either an area source or major source is subject to 40 CFR Part 63, Subpart ZZZZ. An analysis of the 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 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. Existing engines are subject to the requirements in 40 CFR Part 63, Subpart 777Z as follows: OP Identifier Requirements Conduct the following maintenance every 1440 hours or annually: C 124 • Change oil/filter • Inspect spark plugs • Inspect hoses&belts • Reduce CO emissions by 75%or to a maximum of 270 ppmvd at 15%O2 C-116,C-117, • Equip engine with non-selective reduction catalyst C-118, C-119, • Conduct initial performance test using a portable analyzer within 180 days of startup C-120, C-123, • Shut down engine if the catalyst inlet temperature exceeds 1250°F C-152, C-122 • Conduct annual compliance demonstration • Submit semi-annual compliance report • As part of the renewal, DCP re-evaluated all of the sources on the OP insignificant activities (IA) list for regulatory applicability. DCP has documented the updated IA list on APCD Form 2000-102B (attached). This facility is designated a minor source for Greenhouse Gas (GHG) emissions. The potential-to-emit carbon dioxide equivalent(CO2e)emissions are 63,982 tons per year(tpy), which is less than the major source threshold of 100,000 tons per year and 100 tpy(mass basis). One Air Pollutant Emission Notice (APEN and Addendum) renewal for unit P128 (C-152), Waukesha 7042 GSI, serial number 388531 and the associated filing fee check are included with this application. Please find attached the following appendices: Appendix Documents A APEN Renewal and Filing Fee Check B Title V Operating Permit Application Forms C Facility Plot Plan D Current APENs Should you have any questions or require additional information, please do not hesitate to call me at 303-605- 1745 or c(.,'I. I. Sincerely, DCP Midstream, LP ana Stephens Senior Environmental Engineer ray • Appendix B Title V Operating Permit Application Forms Operating Permit Application FACILITY IDENTIFICATION FORM 2000-100 Colorado Department of Public I ealth and Pm ironment Kic nn-05 Air Pollution Control Di\ision SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name and Name Greeley'Natural Gas Processing Plant mailing address Street or Route P.O. Box 5493 City. State,Zip Code Denver,CO 80217 2. Facility location Street Address 3009 West 446 Avenue (No P.O. Box) City,County,Zip Code Greeley,Weld County,CO 3. Parent corporation Name DCP Midstream,LP Street or Route 370 176 Street,Suite 2500 City, State,Zip Code Denver,CO 80202 Country(if not U.S.) 4. Responsible Name Joseph Kuchinski. official Title Vice President,Operations North Telephone 970-378-6345 5. Permit contact person Name Dana Stephens Title Senior Environmental Engineer (If Different than 4) Telephone 303-605-1745 6. Facility SIC code: 1321 7. Facility identification code: CO 123-0099 S. Federal Tax I. D.Number:84-1041166 9. Primary activity of the operating establishment: Natural Gas Processing and Gathering 10. Type of operating permit New Modified ✓ Renewal 11. Is the facility located in a"nonattainment"area: V Yes No If"Yes",check the designated"non-attainment" pollutant(s): Carbon Monoxide ✓ Ozone PM 10 Other(specify) 12. List all(Federal and State)air pollution permits(including grandfathered units),plan approvals and exemptions issued to this Facility. List the number.date and what unit/process is covered by each permit. For a Modified Operating Permit,do not complete this item. Permit No. IRS No. Facilitl II) 55\[304 102 ('-I2_4 85W1i337-I 103 C-116 N5w'P 337-2 1014 C-117 s5wT 137-3 lit:; ('-115 1.-i 19 -a'\\! '_5-1 I 107 ( -I'n s 1tI :: I Ins (-123 S'WFI9? IIN oh\\T_sn III C-I22 III PI3U 9011-.5 -I-_ 113 P13' 9Iwh.514-I 114 I'133 NO\4 Fit 18-' 115 P135 t)peratire Permit:\pplicatiun FACILITY PLOT PLAN FORM 2000-101 (ld,,rado Department of Public Ilcahh and t'niromncnt Re\lib-95 Air Pollution Contn,l Dit l eon Facility Name: Greeley Gas Processing Plant Facility Identification Code:CO 123-0099 The operating permit must be prepared and submitted on forms supplied by the Division. Use of this form is required for all operating permit applications. The Division will not consider or act upon your application unless each form used has been entirely completed. Completion of the information in the shaded area of this form is optional. Use"NA" where necessary to identify an information request that does not apply and is not in the optional shaded area. In order for a comprehensive air quality analysis to he accomplished,a facility plot plan MUST be included with the permit application. Drawings provided must fit on generic paper sizes of 8 1/2"X 11",5 1/2" X 14"or I I" X 15",as appropriate to display the information being provided. Include the facility name and facility identification code on all sheets. For facilities with large areas,sketches of individual buildings,on separate drawings, may he needed to allow easy identification of stacks or vents. Insignificant activities do not need to be shown. Refer to Facility Plot Plan in Appendix C(attached). L A plant layout(plan view) including all buildings occupied by or located on the site of the facility and any outdoor process layout. 2.The maximum height of each building(excluding stack height). 3.The location and coded designation of each stack. Please ensure these designations correspond to the appropriate stacks listed on the other permit forms in this application. The drawings need not he to scale if pertinent dimensions are annotated,including positional distances of structures,outdoor processes and free standing stacks to each other and the property boundaries. 4. The location of property boundary lines. 5. Identify direction "North"on all submittals. Are there any outdoor storage piles on the facility site with air pollution emissions that need to he reported? Yes ✓ No If"Yes",what is the material in the storage pile(s)? Are there any unpaved roads or unpaved parking lots on the facility site? ✓ Yes No List the name(s)of any neighboring state(s)within a 50 mile radius of your facility: Wyoming ulcerating Pennii.\pplieatiun SOURCE ,AND SITE DESCRIPTIONS FORM 2000-102 (.ok,rade t)clmrtruent of Public I Iealth and to inmmcni Re%')b-Ui \ir Pollution connol ision acility Name: Greeley Gas Processing Plant Facility Identification Code:CO 123-0099 The operating permit must he prepared and submitted on forms supplied by the Division. Use of this form is required for all operating permit applications. The Division will not consider or act upor your application unless each form used has been entirely completed. Completion of the information in the shaded area of this form is optiotnl. Use"NA" where necessary to identify an information request that does not apply and is not in the optional shaded area. I.Briefly describe the existing Unit(s)to he permitted. Attach copies of Form 2000-700 as needed to provide the information. Process flowsheets or line diagrams showing major features and locations of air pollution control equipment can be most effective in showing the location and relationships of the units. Providing mass tlowratesihalances at critical points on the diagrams is very helpful when developing an understanding of the processes involved. The Greeley Gas Processing Plant is a natural gas processing plant and compressor station designed to extract natural gas liquids from field produced natural gas and recompress the processed gas prior to transmission to the sales pipeline. Field gas is first piped to a separator where liquids formed during transport to the plant are separated from the gas stream. The gas stream discharged from the separator is processed through a glycol contact tower, where moisture contained in the gas stream is absorbed by ethylene glycol. The moisture laden glycol discharged from the contactor is regenerated in a rehoiler. The absorbed water volatilizes and is discharged into the atmosphere. The glycol solution is then recirculated to the contactor. After the moisture in the gas has been removed by the contactor. the gas stream is piped to the processing plant where it is chilled by a refrigeration system coupled with the Joule-Thompson process to create a natural gas liquid(NGL) product and a residue gas stream. A fractionation assembly separates the NGL product into ethane, propane, butane, isopentane and natural gas streams that are stored in separate tanks and transported offsite by truck. The residue gas is recompressed by ten(9)natural gas-tired internal combustion engines powering compressors and then routed to the sales pipeline. The facility operation also requires two natural gas-fired heaters,a truck loadout rack for condensate,an NGL truck loadout rack and numerous storage tanks. .Site Location and Description(Include instructions needed to drive to remote sites not identified by street addresses) The plant is located in Weld County at the south edge ofGreeley.Colorado near Highway 85. The Greeley Plant is in the SW : of Section 25,Township 5 North, Range hO West at the address of 3009 West 44'°Avenue. Driving Directions— From Greeley.go south on Highway 85 to Highway 34. Proceed west on Highway 34 to 3.5t"Avenue and turn leti. Follow 3511'Avenue to the"T" in the road. The plant is immediately on the left side about 300 feet down the road. 3. Safety Equipment Identify safety equipment required for performing an inspection of the facility: Protection Other,specify mm ✓ Hard Hat ✓ Safety shoes ✓ Hearing Protection ✓ Gloves Operating Permit Applieigion SOURCE DESCRIPTION-APENS FORM 2000-102A -olorado Department of Public f lealth and Environment Rev 06-95 r Pollution Control Division Facility Name: Greeley Gas Processing Plant Facility Identification Code:CO 123-0099 NOTE: Each new or updated Air Pollutant Emission Notice(APEN) submitted must be accompanied by payment of$100 per APEN. 1.For each emission unit enclose a copy of the most current complete Air Pollutant Emission Notice(APEN)on file with the Division. If the most current APEN was not completely and correctly filled out,a revised APEN is required. List an APEN number,date,and a brief description of the unit/process covered by the APEN. (No filing fees are needed for these copies) AIRS Stack Number(Plant ID) APEN Date Unit Description 102(C-124) 118110 Waukesha F-I I G 103(C-116) 6/1112 Waukesha L7042 GSI 104(C-117) 8/24111 Waukesha L7042 GSI 105(C-118) 7/22/11 Waukesha 1.7042 GSI 106(C-119) 2/22:'13 Waukesha L7042 GS( 107(C-120) 1129'10 Waukesha L7042 GSI 108(C-123) 812?/12 Waukesha L7042 GU 110(C-122) 2114111 Waukesha L7042 GSI I 1 1 (P130) 12/31/08 Ethylene Glycol Dehydrator 113(P132) 1113/12 15.0 MMBtu%hr Natural Gas Fired Heater 114(P133) 4/9109 Fractionation&NGL Gas Processing Plant 115(P135) l 1'30/09 Pressurized Truck Loadout 120(P139) 12'31/08 35.1 MMBtu/hr Natural Gas Fired Heater .No APEN exists for an emission unit. List the new APEN and the appropriate descriptive information here. Submit the APEN with a construction permit application. N/A 3. A revised APEN was prepared and enclosed for an emission unit. List the APEN and the appropriate descriptive information here. A revised APEN is needed where a significant increase in emissions has occurred,or is planned:or a major modification of the unit has occurred or is planned;or the existing information needs correction or completion. A construction permit application may need to be submitted. Revised APEN submitted as part of this application: ✓Yes No APEN Renewal Only New permit application enclosed: Yes ✓ No Unit already permitted. Permit modification application enclosed: Yes v No No permit modification requested. AIRS Stack Number(Plant ID) APEN Date _ Unit Description 109(C-152)P128 04/30/13 Waukesha L7042 GSI NOTE: Use additional copies of Form 2000-700 as needed to provide the above information. tperating Permit Applicatient SOURCE DESCRIPTION- INSIGNIFICANT ACTIVITIES FORA 2000-102B Colorado Department of Public Health and Einsironment Rev 0b-95 Air Pollution Control Division Facility Name: Greeley Cas Processing Plant Facility Identification Code:CO 123-0099 NOTE: the operating permit must he prepared and submitted on turns supplied by the Die ision. this is a supplemental ibrm for use only when necessary to provide complete information in the operating permit application.The Division will not consider or act upon your application unless each turn used has been entirely completed. Certain categories of sources and activities are considered to be insignificant contributors to air pollution and are listed below. A source solely comprised of one Or more of these activities is not required to obtain an operating permit pursuant to Regulation 3,unless the source's emissions trigger the major source threshold as defined in Part A,Section 1.B.58 of Regulation 3. For the facility,mark all insignificant existing or proposed air pollution emission units,operations,and activities listed below. (a) Noncommercial(in-house)experimental and analytical laboratory equipment which is bench scale in nature including quality control quality assurance laboratories, process support laboratories,environmental laboratories supporting a manufacturing or industrial facility,and research and development laboratories. (b)Research and development activities which are of a small pilot scale and which process less than 10.000 pounds of test material per year. (c)Small pilot scale research and development projects less than six months in duration with controlled actual emissions less than 500 pounds of any criteria pollutant or 10 pounds of any non-criteria reportable pollutant. Disturbance of surface areas for purposes of land development,which do not exceed 25 contiguous acres and which do not exceed six months in duration. (This does not include mining operations or disturbance of contaminated soil). ✓ Each individual piece of fuel burning equipment,other than smokehouse generators and internal combustion engines,which uses gaseous fuel,and which has a design rate less than or equal to 5 million Btu per hour.(See definition of fuel burning equipment,Common Provisions Regulation). Petroleum industry flares,not associated with refineries,combusting natural gas containing no H2S except in trace(less than 500 ppmw) amounts,approved by the Colorado Oil and Gas Conservation Commission and having uncontrolled emissions of any pollutant of less than five tons per year. ✓Chemical storage tanks or containers that hold less than 500 gallons,and which have a daily throughput less than 25 gallons. Landscaping and site housekeeping devices equal to or tess than 10 H.P.in size(lawnmowers,trimmers,snow blowers,etc.). Crude oil or condensate loading truck equipment at crude oil production sites where the loading rate does not exceed 10,000 gallons per day averaged over any 30 day period. ✓Chemical storage areas where chemicals are stored in closed containers,and where total storage capacity does not exceed 5000 gallons. This exemption applies solely to storage of such chemicals. This exemption does not apply to transfer of chemicals from,to,or between such containers. ✓Oil production wastewater(produced water tanks),containing less than 1%by volume crude oil.except for commercial facilities which accept oil production wastewater for processing. (Continues on other side) ✓Storage of butane,propane, or liquified petroleum gas in a vessel with a capacity of less than 60.000 gallons,provided the requirements of Regulation No. 7, Section IV are met, where applicable. ✓ Storage tanks of capacity;40.000 gallons of lubricating oils. Venting.of compressed natural gas. butane or propane gas cylinders, with a capacity of 1 gallon or less. Fuel storage and dispensing equipment in ozone attainment areas operated solely for company-owned vehicles where the daily fuel throughput is no more than 400 gallons per day,averaged over a 30 day period. ✓Crude oil or condensate storage tanks with a capacity of 40,000 gallons or less. V Storage tanks meeting all of the following criteria: (i) annual throughput is less than 400.000 gallons;and (ii) the liquid stored is one of the following: (A) diesel fuels I-D. 2-D,or 4-D; (B) fuel oils#I through 46; (C) gas turbine Niels I-GT through 4-GT; (D) an oil/water mixture with a vapor pressure lower than that of diesel fuel (Reid vapor pressure of.025 PSIA). ✓Each individual piece of fuel burning equipment which uses gaseous fuel, and which has a design rate less than or equal to 10 million Btu per hour,and which is used solely for heating buildings for personal comfort. Stationary Internal Combustion Engines which: (i) power portable drilling rigs;or (ii) are emergency power generators which operate no more than 250 hours per year:or (iii) have actual emissions less than live tons per year or rated horsepower of less than 50. Surface mining activities which mine 70,000 tons or fewer of product material per year. A fugitive dust control plan is required for such sources. Crushers,screens and other processing equipment activities are not included in this exemption. ✓ Air pollution emission units,operations or activities with emissions less than the appropriate de minimis reporting level. NOTE: Material Data Safety Sheets(MSDS)do not have to he submitted for any insignificant activities. USE FORM 2000-700 TO PROVIDE AN ITEMIZED LIST OF THE SOURCES OR ACTIVITIES BEING IDENTIFIED AS INSIGNIFICANT AC'T'IVITIES. DO NOT ITEMIZE INDIVIDUAL PIECES OF LANDSCAPING EQUIPMENT. THE LIST IS NEEDED TO ACCURATELY ACCOUNT FOR ALL ACTIVITIES AT THE FACILITY Operating Permit-\ppiicatiun SUPPLEMENTAL INFORMATION FORM 2000-700 Colorado Department r.1 Public Health and En\nonment il9-94 Air Pollution Control Div ision SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Creeley Cas Processing Plant 2. Facility identification code:CO 123-0099 3. This form supplements Form 2000- 102B for Emission Unit(e.g. B001. P001,etc.) Additional Information, Diagrams Insignificant Activities: Storage Tanks:(3)30,000 gal Pressurized V-grade Natural Gas Storage Tanks:(8)30,000 gal Pressurized Propane Storage Tank:(1)30.000 and(1)4.200 gal Methanol Storage Tanks:(7) 30.000 gal NGL Storage Tanks:(2)30,000 and(2)29,435 gal Pressurized Butane Storage Tank:(1)30.000 gal Pressurized Condensate Storage Tank: (I)29,835 gal Pressurized Isopentane Storage Tank:(1) 21,000 and(1)6,930 gal Engine Oil Storage Tank:(1) 16,800 gal Diesel Oil Storage Tanks:(2) 12,600,(1)3,360 and(1)2,940 gal Storm Water Storage Tanks:(2)3.360 gal Produced Water Storage Tanks:(2)3,360 gal Slop Oil Storage Tanks:(2)3,360 gal Used Oil Storage Tank:(1)2.000 gal Norkwool Storage Tank:(1)2.000 gal Ethylene Glycol Storage Tank:(I)500 hhl Triethylene Glycol Storage Tanks:(6)>500 hhl Misc. External Combustion Heaters: (5)< 1.0 mmBtu/hr Natural Gas Flare Pilot [missions Operating Permit Application PERMIT SHIELD PROTECTION FORM 2000-605 Colorado Department 0 Public Ilcalth and Environment IDENTIFICATION Rev 06-,45 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE L Facility name: Greeley Gas Processing Plant 2. Facility identification code:CO 123-0099 3.Specify Emission Source: 4.Do not use (9) Internal Combustion Engines:C-116-C-I20,C-122, C-123,C-124,C-152 5. Pollutant, 6.Colorado Air Quality 7. Equipment, Regulations State or Only Process Internal Combustion Engines: Reg I.III.A.1.b- Particulate emissions from fuel- C-116-C-120,C-122, C-123, burning equipment C-124,C-152 Internal Combustion Engines: Reg 1.VI.B.5.a-Sulfur dioxide emissions from C-116-C-120,C-122, C-123, fuel-burning equipment C-124,C-152 S.Other requirements(e.g., malfunction reporting,special operating conditions from an State Only existing permit such as material usage,operating hours,etc.) NOTE: REQUESTS FOR THE SHIELD MUST BE FOR A SPECIFIC REQUIREMENT IN THE REGULATIONS. USE FORM 2000-700 TO PROVIDE AN EXPLANATION OF'WHY THE SHIELD IS REQUESTED Operating Permit Application SUPPLEMENTAL INFORMATION FORM 2000400 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE I. Facility name:Greeley Gas Processing Plant 2. Facility identification code:CO 123-0099 3. This form supplements Form 2000-605 for Emission Units: C-I16,C-I20,C-I22, C-I23,C-124,C-I52 Additional Information. Diagrams Item Numher Internal Combustion Engines: C-I 16,C-I20,C-I22, C-123,C-124,C-152: Internal combustion engines are not considered fuel burning equipment for the applicable requirements of Reg. 1.I I I.A.I.h and Reg. The information on this form repeats what is already stated in Permit 95OPWE038. No changes requested. 9 Operating Permit Application PERMIT SHIELD PROTECTION FORM 2000-605 ('olorado Department of Public Ilealth and En%iromnent IDENTIFICATION Re%06_9i it Pollution Control Division FE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Greeley Gas Processing Plant 2. Facility identification code:CO 123-0099 3.Specify Emission Source: Facility Wide 4. Do not use 5.Pollutant, 6.Colorado Air Quality 7. Equipment, Regulations State or Only Process Reg.3 B.IV.D.3- Facility Wide PSD Review Requirements Facility Wide Reg.3 B.X.- Air Quality Modeling Facility Wide Reg.3 B.XI- Visibility Requirements Facility Wide Reg.4—Wood Burning Stoves Facility Wide Reg.6—Part A,NSPS Subpart OOOO Facility Wide Reg.7 V.C Facility WideReg.7 VIAL—Storage of Petroleum Distillates Facility Wide Reg.7 VI.B.2—Storage of Petroleum Distillates Facility Wide Reg.7 VII.C—Crude Oil Storage Facility Wide Reg.8 E,I Facility Wide Reg 8. E.Ill—Subpart HI" and 40 CFR Part 63,MACT Subpart VIII Facility Wide Reg. 10 Facility Wide 40 CFR Part 60,NSPS Subpart OOOO R.Other requirements(e.g., malfunction reporting,special operating conditions from an State Only existing permit such as material usage.operating hours,etc.) NOTE: REQUESTS FOR THE SHIELD MUST BE FOR A SPECIFIC REQUIREMENT IN THE REGULATIONS. USE FORM 2000-700 TO PROVIDE AN EXPLANATION OF WHY THE SHIELD IS REQUESTED 10 erating Permit Application SUPPLEMENTAL INFORMATION FORM 2000-700 olorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE Facility name: Greeley Gas Processing Plant 2. Facility identification code:CO 123-0099 3. This form supplements Form 2000- 605 for Emission knit(e.g. 13001. P001,etc.) Facility Wide Additional Information. Diagrams Item Number Permit Shield Protection Information: The regulations identified are either in the current Title V permit shield or are activities that are not applicable to this facility at this time. Reg.3 B.IV.D.3: Activities at this site have not yet required Prevention of Significant Deterioration(PSD) review or permitting. Reg.3 B.X.: Activities at this site have not resulted in the plant being classified as a major source for PSD. nor has there been any major modification. Reg.3 B. XI: The plant has not been identified as a.source that may impact the visibility in a Federal Class area. Reg.4:This plant does not include any wood burning stoves or wood burning appliances,or advertise or sell such devices. Reg.6 Part A,NSPS Subpart OOOO:These provisions apply to designated affected facilities that commenced construction,reconstruction or modification after August 23. 2011.This plant does not include such facilities. Reg.7 V.C:The plant is not a gasoline terminal, hulk gasoline plant or the type of gasoline dispensing plant subject to the provisions. Reg.7 VI.B.I:This plant does not include petroleum liquids storage tanks with greater than 40,000 gallons capacity. Reg.7 VI.B.2:This plant does not include petroleum liquids storage tanks with greater than 40.000 gallons capacity. Reg.7 VII.C: These provisions apply to the storage of crude oil in tanks with greater than 40.000 gallons capacity. Reg.8. E.I and EMI Subpart HH and 40 CFR Part 63,N1ACT Subpart HH:The affected source under the applicable is each triethylene glycol dehydration unit located at an area source.The triethylene dehydrator that was previously subject to Subpart HH has been physically disconnected from service and is no longer in operation. Reg. 10:Conformity of federal actions to SIPs and FIPs. 40 CFR Part 60,NSI'S Subpart OOOO:"1 hese provisions apply to facilities that commenced construction. reconstruction,or modification after August 23, 2011. This plant does not include such facilities. The information on this form repeats what is already stated in Permit'95OPWE038,with the exception of adding new permit shield citations,and the removal of the shield for'Reg.6 - Adoption of Federal NSPS Requirements'as the facility is subject to 40 CFR Part 60,Subpart KKK. Operating Permit Application TABULATION OF PERNIIT APPLICATION FOR\IS FORM 2000-800 Colorado Department of I Iealih 0U_-14 Air Pollution Control Di sun Facility Name: Greeley Gas Process:n=Plant Facility Identification Code:CO 123-0099 ADM INISIRAIION I his application contains the following forms: ✓ boon 2m m-100,Facility Identification ✓ Form_2000-101,Facility Plot Plan ✓ Forms 2000-102,-102_A,and-10213,Source and Site Descriptions II. FMMISSIONS SOURCE Food Number Dl SC RI I'I IC)N of This Form This application contains the taot�ing limns Form 2_000-22!(0,Stack Identification tome fiinn for each facility boiler,printine Form 2001)-300,[oiler or Furnace Operation Form 2000-301,Storage ranks Form 2_000-302,Internal Combustion Engine form 2001.303,Incineration Form 215)(1-304,Printing Operations Form 2000-305.Painting and Coating(tperallotts Form 2000-306.Miscellaneous Processes hum 2_000-307,Glycol Dehydration I init Ill. AIIt.POI LIE IION CONE(ROI. Fatal Number S't S 1 F of this Form Ibis application contains the tnlloncing forms Form 2000-400,Miscellaneous Pants 2001)-4)1.Condensers I'oon 2_00(1-40'_.Adsorhers Forst 2_000-403,Catalytic or thermal Oxidation Porn 2000-404,Cyclones Settling Chambers Form 2000-405,Flcclro statie Precipitators Form 2_000--406,Wet Collection Systems Form 2m0--407,13aghouses,Fabric Filters IV. C'OAII'I_I ANC F Iota!Number DFMt)NS I RA I ION of Nis Form I his application contains the ti lloto rig limns I 20(o-500.Compliance('ertitica0nn-Montioring and (one lug each facility hailer,printing operation, Reporting Form 2000-501,Continuous Emission Monitoring Form 2000-502,Periodic Emission Monitoring(`sing Portable Monitors Perm 20)10-503,Control System Parameters or Operation Parameters of a Process - Form 2_000-50-3,Monitoring Maintenance Procedures I-,mn'000-;05,Stack fcsuo: Faint 2,0o_ur?.I Smnhl:ng:nd Analysis i O1111?110(1-(1i?,Rccordkccpin_ Form'_000-Sus,Other Methods V. EMISSION SUMMARY AND Total Number COMPLIANCE.CERTIFICATION of This Form us application contains the following forms Form 2000-600, Emission Unit Hazardous Air Pollutants ntifying emissions,certifying compliance ith applicable requirements,and developing a compliance plan Form 2000-601, Emission Unit Criteria Air Pollutants Form 2000-602, Facility Hazardous Air Pollutants Form 2000-603. Facility.Criteria Air Pollutants Form 2000-604.Applicable Requirements and Status of Emission Unit ✓ Form 2000-605, Permit Shield Protection Identification 2 Form 2000-606. Emission Unit Compliance Plan- Commitments and Schedule Form 2000-607, Plant-Wide Applicable Requirements Form 2000-608.Plant-Wide Compliance Plan- Commitments and Schedule VI. SIGNATURE OF RESPONSIBLE OFFICIAL - FEDERAL/STATE CONDITIONS • A. STATEMENT OF COMPLETENESS I have reviewed this application in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this application are true, accurate and complete: CERTIFICATION OF FACILITY COMPLIANCE STATUS - FEDERAL/STATE CONDITIONS (check one box only) I I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. ❑ I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements, except for the following emissions unit(s): (list all non-complying units) WARNING:. Any person who knowingly, as defined in § 18-1-501(6), C.R.S., makes any false material statement, representation, or certification in, or omits material information from this application is guilty of a misdemeanor and may be punished in accordance with the provisions of§ 25-7 122.1, C.R.S. Printed or Typed Name Title Joseph Kuchinski Vice President, Operations North ir Die S �netl it It = !cz' �, 11� �'/�' � 3 Operating Permit Application CERTIFICATION FOR STATE-ONLY CONDITIONS FORM 2000-800 Co!'ra,lo Department of Health 09.94 '011utinn Control Division Facility Name: Greele)/ Gas Plant Facility Identification Code: CO 123-0099 VI. SIGNATURE OF RESPONSIBLE OFFICIAL - STATE ONLY CONDITIONS A. STATEMENT OF COMPLETENESS I have reviewed this application in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this application are true, accurate and complete. B. CERTIFICATION OF FACILITY COMPLIANCE STATUS FOR STATE-ONLY CONDITIONS (check one box only) ✓ I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. 11 I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements, except for the following emissions unit(s): (list all non-complying units) ',YARNING: Any person who knowingly, as defined in § 18-1-501(6), C.R.S., makes any false material statement, presentation, or certification in, or omits material information from this application is guilty of a misdemeanor and may be finished in accordance with the provisions of§ 25-7 122.1, C.R.S. Printed or Typed Name Title Joseph Kuchinski Vice President, Operations North Sigature Date Signed - ci SEND ALL MATERIALS TO: COLORADO DEPARTMENT OF HEALTH APCD-SS-B I 43(X)CHERRY CREEK DRIVE SOUTH DENVER, CO 80246-1530 Appendix C Facility Plot Plan w r :aap<: • • M E _ } , r w j _ M1 3 1 \ , �, ,_._,,�.. n . ., ..r.� ,!fi, ,� . il ( ¢ / J • ! ~a I ! • 1 1 fii J }r',--1 f k,'''-',,—,:.,_.— i -- `1 ` .....— }_. ..... ... »..oil. W/ .. _ .,TN OOEET(CII.7y) -- k1' Alligstrame , wE.I.0 tVl!N"I'1'. t'ULUliAUV ., t I,..of PLAN , 1 i h I.,: , . e ., ., a w ... ., ., .. iSSUC . r I 1 ISSIIt , w • ,..iality as Received AIR rOLLUTANT EMISSION NOTICE (APEN)& Application for'2onstruction Permit—Reciprocating Internal Combustion Engine Permit Nuiilber: 95OPWE038 'Leave blank unless APtI)has atreads assigned a permit s x.AIRS u)] Emission Source AIRS ID: 123 / 0099 / 109 FaciliI Equipment ID: C-152 (P-128) I Pros do Facihis I quipmcnt ID to idenuth boss this equipment is referrnced w'ithui your organization] Section 01 —Administrative Information Section 02—Requested Action(check applicable request boxes) ("ompan) Name' l)CP Midxiream,Lt' NAILS.or ❑ Request for NEW permit or newly reported emission source SIC Code': 1321 Source Name: Creeks Natural Gas Processing Plant ❑ Request for coverage under GENERAL PERMIT number GP02(Natural Gas Only) Source Location: S11 114 Section 25,'13N,R661%' County: Weld ❑ Request\IODIFI('ATION to existing permit(check each box below that applies) Elevation: 4,691 Feet ❑ Change fuel or equipment ❑ Change company name Portable Source ❑ Change permit limit ❑ Transfer of ownership ❑ Other I Some Base: ❑ Request PORTABLE source permit Mailing Address: 370 17"'Street,Suite 2500 ZIP Code: 80202 ® Request APEN update only(check the box below that applies) Denver,CO ❑ Revision to actual calendar year emissions for emission inventory Person To Update 5-Year API.N term without change to permit limits or previously reported Contact: Dana Stephens Phone Number: . 303-605-1745 emissions E-mail Address: dstephens a dcpmidstream.com Fax Number: ❑ Notification of AOS permanent replacement Addl. Info.& Section 03—General Information Notes: For existing sources,operation began on: 8 / 1 / 2002 For new or reconstructed sources,die projected startup date is: / Normal hours of source operation- 24 hours/day 7 daystwcek 52 weekshear General description of equipment purpose: General Compression Date the engine was ordered: Date engine construction commenced: Date the engine seas relocated into Colorado: Date of an) reconstruction/modification: Colorado Department of Public Health and Environment Air Pollution Control Division(At'('l) Will this equipment be operated in any NAAQS nunattainment area'? Don't Iht / sssssc.ait>h,a.it t,,t, u.t ninuint,tim.himl) ® 1'es ❑ No Elknow This notice is said for five(5)years. Submit a revised APEN prior to expiration of live-year term. or when a signilicant change is made Section 04—Engine Information (increase production.new equipment,change in fuel type,etc). Mail this form along with a check for S152.90 per APEN and Engine date of manufacture: Engine displacement: !icy! SI,500 for each general permit registration to: Manufacturer: 'Waukesha Model: L7042 GS1 Serial No.: 388531 Colorado Department of Public Health&Environment A P('D-SS-B I Engine function: ❑ Primal and;or peaking power ❑ l:mergenc) back-up power 4300 Cherry('reek Drive South 4114.,), ❑ Compression ❑ Pump jack ❑ Water pump ❑ Other: Denver,CO 80246-1530 ''''',"0,, For guidance on how to complete this APEN Iunn: 'r Manufacturer's maximum rated horsepower a sea level: 1,100 BII1' a. 900 RPM Air Pollution Control Division: (303)-642-3150 Manufacturer's maximum site rating: BHP a RPM kW Small Business Assistance Program(SBAP). (303)692-3148 or (30Engine Brake Specifie Fuel Consumption.a: I00"0 Load: 8,490 Btu/IIP-hr AI'FN forms:hnn Intr)::/www.cdphe.state.co.us;ap:downloadt0rins.litml G93-,17S i radtornshunl Cycle Type: ❑ _2-Stroke Q 4-Stroke Combustion. ❑ Lean Burn ® Rich Burn AppLcalion status:bttp://www.cdphe.state_co.usio;ss/sspept.htnil Ignition Source: ❑ Spark ❑ Compression Aspiration: ❑ Natural ❑ Turbocharged ❑ Check box to request copy of draft permit prior to issuance. What is the maximum number of hours this engine is used fur emergency back—up power:' I loursiycar ❑ Check box to request copy of draft permit prior to public notice FORM APCD-201 291386 Page I of 2 Greeley Forms-2i it 3 APLfN Renessal duc AL% <OLLUTANT EMISSION NOTICE (APEN) & Application for ,.onstruction Permit—Reciprocating Internal Combustion Engine ' Permit Number: 95OPWE038 Emission Source AIRS ID: 123 / 0099 / 109 Section 05—Stack Information(Attach a separate sheet with reles ant iniitrmation in the event of multiple stacks;provide datum&either Lat/Long or UT'M1) Stack >ta. Dis charge,eharge Ilorvontal Operator Datum Ul'M UI M Lasting or CITM Nonhing or Method of Collection for Location Stack Rase 1 Light Above .Lem F Plow Rate Velocity Moisture I:Icvauuu (,r)und Level p (� ) u. (NAD27, Zone Longitude Latitude Data(e g map,GPS. ID No. (ACFMI (f�'sec) ( a) NADS3, Oven (feet) (12 or 13) (meters or degrees) (meters or degrees) GoogleFarth) WGS84) C-152/P128 4,691 26.86 1055 5,377 114 Ambient WCS84 13 522,877 4,468,151 CPS Direction of stack outlet(check one): © Vertical ❑ Vertical with obstructing raincap ❑ Horizontal ❑ Down ❑ Other(Describe): Exhaust Opening Shape& Sire(check one): 0 Circular:Inner Diameter(inches)= 12 ❑ Other:Length(inches)= Width(inches)= Section 06—Fuel Cousuntptit,o Information 1=uc{Use flatsu IOU%,load Annual Fuel Consumption(gal/yr or MMSCF/yr) Sulfur Seasonal Fuel Use 1%of Annual Use) Fuel } . e Fuel Heating Value )p (SC L%hr-eal/hr) Actual Reported for Requested Permit Limit (Btu/Ib,Btu/gal.Btu/SCF) Content Dec-Feb Mar-May Jun-Aug Sep-Nov �� Calendar Year ( wt.) Natural Gas 9.34 NINIBtu/hr 78.66 t MScf/vr 1,040 Btu/Scf 0 25 25 25 25 Is this engine equipped tsith an Air,Fuel ratio controller'? ® Yes ❑ No Section 07—Emissions Inventory Information& Emission Control Information O Emission Factor Documentation attached Data year for actual calendar yr.emissions betoss Si fuel use above(e.g.20117): ' • Control Device Description Control Emission Factor Actual Calendar Year Emissionsr Requested Permitted Estimation Method Pollutant Efficiency Emissions or Primary Secondary (%Reduction) Uncontrolled Basis Units Uncontrolled Controlled Uncontrolled Controlled Emission Factor (Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Source TSP PM,,,, 1.94E-02 Ib/M\1Btu 0.79 0.79 AP-42 PM,; 1.94E-02 lb/NINIBtu 0.79 0.79 AP-42 SO, 5.88E-04 lb/MM Btu 0.024 0.024 AP-42 NOt NSCR 13.0 g/hp-hr 138.09 21.24 Manufacturer VOC 0.5 g/hp-hr 5.31 5.31 Manufacturer CO NSCR 9.0 g/hp-hr 95.6 26.55 Manufacturer Formaldehyde NSCR 76 2.05E-02 Ib/.1\1Btu 0.84 0.02 AP-42.Table 3.2-3 Acetaldehyde NSCR 50 2.79E-03 Ib/b1AMBtu 11.11 0.06 AP-42,Table 32-3 Acrolein NSCR 50 2.63E-03 Ib/NIMBtu 0.11 0.05 AP-42.Table 3.2-3 Benzene NSCR 50 1.58E-03 Ib/NIMBtu 0.06 0.03 AP-42.Table 3.2-3 _ _ Please use the APCDNon-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Annual emission lees a ill he based on actual emissions reported here. If left blank,annual emission tees will.be based on requested emissions Section 08—Applicant Certification-I hereby certify that all information contained herein and information submitted with this application is complete,true and correct.If this is a regis 'lion for coverage under general permit(iP02,I further certilj that this source is and will be operated in full compliance with each condition of general permit CiP02. ".--)C'''-'4:-- �J 1 •• rj. � `//30//3 Dana Stephens Sr. Environmental Engineer Signature of Person Legally'authorized to Supply Data Date Name of Legally Authorized I,erson(Please print) Title .r�l Page 2 oft Greeley Forms-2013 APEN Reno\at doe NON-CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) Permit Number: 95OPWE038 AIRS ID Number: 123/0099/109 Company Name: DCP Midstream, LP Plant Location: SW 1/4 Section 25, T5N, R66W County: Weld Zip Code: 80202 Person to Contact: Dana Stephens Phone Number: 303-605-1745 E-mail Address: dstephensdcpmidstream.com Fax Number: Chemical Reporting Control Equipment/ Emission Factor Emission Uncontrolled Actual Controlled Actual Abstract Service Chemical Name (CAS)Number BIN Reduction (%) (Include Units) Factor Source Emissions (lbs/year) Emissions(lbs/year) • 106-99-0 1, 3 Butadiene A NSCR/50% 6.63E-4 AP-42 54.24 27.12 Ib/MMBtu Reporting Scenario (1, 2 or 3): 1 Calendar Year for which Actual Data Applies: NA t-., ,t.��._., :, 14y L//-)oJ / 3 Signature of Person Legally'Authorized to Supply Data '/ Date Dana Stephens .<1 Sr. Environmental Engineer Name of Person Legally Authorized to Supply Data (Please print) Title of Person Legally Authorized to Supply Data Form Revision Date: December 4, 2006 A 'OLLUTANT EMISSION NOTICE(APEN)& Application Construction Permit—Reciprocating Internal Combustion Et Perm4Numbcr: 95OPWE038 [Leave blank unless APCD has already assigned a permit#&AIRS ID] Emission Source AIRS ID: 123 / 0099 1 102 Facility Equipment ID: P121 (C-124) [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01 —Administrative Information Section 02—Requested Action(check applicable request boxes) Company Name: DCP Midstream,LP NAICS,or O Request for NEW permit or newly reported emission source SIC Code: 1311 Source Name: Greeley Natural Gas Processing Plant 0 Request PORTABLE source permit Source Location: Section 25,TSN,R66W County: Weld ❑ Request MODIFICATION to existing permit(check each box below that applies) Elevation: 4,691 Feet ❑ Change fuel or equipment 0 Change company name Portable Source O Change permit limit O Transfer of ownership O Other Home Base: ❑ Request to limit HAPs with a Federally enforceable limit on PTE Mailing Address: 370 17ih St.,Suite 2500 ZIP Code: 80202 E Request APEN update only(check the box below that applies) Denver,CO O Revision to actual calendar year emissions for emission inventory Person To Update 5-Year APEN term without change to permit limits or previously reported Contact: Wesley Hill Phone Number: 303-605-1716 E emissions E-mail Address: wdhill i≥dcpmidstream.com Fax Number 303-605-1957 O Notification of AOS permanent replacement Addl. Section 03—General Information Info.& • Notes: For existing sources,operation began on: 5 1 20 / 1986 For new or reconstructed sources,the projected startup date is: / / Normal hours of source operation: 24 hours/day 7 days/week 52 weeks/year — General description of equipment purpose: Natural Gas Compression Date the engine was ordered: Before 5/86 Date engine construction commenced: Prior to 5/86 Date the engine was relocated mtu Colorado: 11/14/1992 Date of any reconstruction/modification: Colorado Department of Public Health and Environment Will this equipment be o operated in any NAAQS nonattainment area? Air Pollution Control Division(APCD1 P Q ❑ Don't (http://www.cdphe.state.co.usf .p/Duainmaintain.html) Z Yes No know This notice is valid for five(5)years. Submit a revised APEN prior to • Section 04—Eneine Information expiration of five-year term, or when a significant change is made (increase production,new equipment,change in fuel type,etc). Engine date of manufacture: 3/8/88 Engine displacement: 11 L/cyl Mail this form along with a check for$152.90 to: Manufacturer _Waukesha Model: Fl I G _ Serial No.: 5294177 Colorado Department of Public Health&Environment APCD-SS-B1 Engine function: O Primary and/or peaking power 0 Emergency back-up power 4300 Cherry Creek Drive South E Compression O Pump jack O Water pump O Other: Denver,CO 80246-1530 For guidance on how to complete this APEN form: Manufacturer's maximum rated horsepower @ sea level: 125 BHP @ 1,500 RPM Air Pollution Control Division: (303)692-3150 Manufacturer's maximum site rating: 125 BHP rib 1,500 RPM kW Small Business Assistance Program(SBAP): (303)692-3148 or (303)692-3175 Engine Brake Specific Fuel Consumption @ 100%Load: 7,920 Btu/HP-hr APEN forms:http://www.ctinhe.state.co.us/ap/downloadforms.html Cycle Type: O 2-Stroke E 4-Stroke Combustion: O Lean Burn ® Rich Burn Application status:http://www.edphe.state.co.us/ap/ss/ssoc)rt.html Ignition Source: ® Spark ❑ Compression Aspiration: E Natural O Turbocharged O Check box to request copy of draft permit prior to issuance. What is the maximum number of hours this engine is used for emergency back—up power'? Hours/year O Check box to request copy of draft permit prior to public notice_ FORMAPCD-201 291387 MAY - L'%-. Page I of 2 Greeley P121 APEN Renewal-FormAPCD-'_01-RlCEAPFN dog A___ POLLUTANT EMISSION NOTICE (APEN)& Applicatio Construction Permit—Reciprocating Internal Combustion E e Permit Number: 95OPWE038 Emission Source AIRS ID: 123 / 0099 / 102 Section 05—Stack Information(Attach a separate sheet with relevant information in the event of multiple stacks;provide datum&either Lat/Long or VIM) Operator Stack Base Stack Discharge Horizontal Datum UTM UTM Eastmg or UTM Northing or Method of Collection for Location Height Above Flow Rate Velocity Moisture Stack Elevation Temp.(F) (NAD27,NAD83, Zone Longitude Latitude Data(e.g.map,GPS, Ground Level (ACFM) (ft/sec) (%) 1D No. (feet) WGS84) (12 or 13) (meters or degrees) (meters or degrees) GoogleEarth) (feet) i S121 4691 14.6 1100 615 52 ambien WGS84 13 522,877 4,468,151 GPS Direction of stack outlet(check one): ® Vertical ❑ Vertical with obstructing raincap ❑ Horizontal O Down O Other(Describe): Exhaust Opening Shape&Size(check one): ® Circular:Inner Diameter(inches)= 6 O Other:Length(inches)= Width(inches) Section 06—Fuel Consumption Information • 100% Annual Fuel Consumption(gal/yr or MMSCF/yr) Sulfur Seasonal Fuel Use(%of Annual Use) Fuel Type Fuel Use Rate a load Fuel Heating Value yp (SCE/hr,gat'hr) Actual Reported for Requested Permit Limit (Btuilb,13tu/gal,Btu/SCF) Content Dec-Feb Mar-May Jun-Aug Sep-Nov Calendar Year (%wt.) Natural Gas 952.05 SCF/hr 8.34 MMscf/yr 1040 Btu/scf 25 25 25 25 is this engine equipped with an Air/Fuel ratio controller? ® Yes O No Section 07—Emissions Inventory Information&Emission Control Information ® Emission Factor Documentation attached Data year for actual calendar yr.emissions below&fuel use above(e.g.2007): ' Requested Permitted Estimation Method Control Device Description Control Emission Factor Actual Calendar Year Emissions' Emissions2 or Pollutant Efficiency Primary Secondary (%Reduction) Uncontrolled Basis Units Uncontrolled Controlled Uncontrolled Controlled • Emission Factor (Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Source TSP PM 10 I , PMZ s SOx NOx NSCR 3.0 Manuf.data VOC NSCR 0.6 Manuf.data CO NSCR 4.2 Manuf.data Formaldehyde NSCR 76% 0.0205 Ib/mmbtu 0.02 AP-42 Acetaldehyde NSCR 50% 0.00279 lb/mmbtu 0.006 AP-42 Acrolein NSCR 50% 0.00263 Ib/mmbtu 0.006 AP-42 Benzene NSCR 50% 0.00158 lb/mmbtu 0.003 AP-42 Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Annual emission tees will be based on actual emissions reported here. If left blank,annual emission fees will be based m requested emissions, 'If Requested Permitted Emissions is left blank,the APCD will calculate emissims based on the information supplied in sections 03-07. Section 08—Applicant Certification-I hereby certify that all information contained herein and information submitted with this application is complete,true and correct. A._. ,--1--‘),/t l��/l 0Wesley Hill Sr.Environmental Specialist Signature of Person Legally Authorized to Supply Data IDate Name of Legally Authorized P git(P print) Title Page 2 of 2 Greeley P121 APEN Renewal-Form APCD-201-RICEAPEN,dm AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit— Reciprocating Internal Combustion Engine Permit Number: 95OPWE038 (Leave blank unless APCD has already assigned a permit it&AIRS ID] Emission Source AIRS II): 123 / 0099 / 103 Facslity hquipm'nt ID. ( 1 to(P122) (Provide Facility Equipment ID to identify how this equipment is ncferenced within your organization.] Section 01 - Administrative Information Section 02—Requested Action(check applicable request boxes) Company Name: DCI'Nikki ream,LP NAICS,or ❑ Request for NEW permit or newly reported emission source 1311 Source Naiuc ( recle,) Natural(as Processing Plant SIC Code: ❑ Request fur coverage under GENERAL PERMIT number CP02(Natural Gas OM)) Source Location: S\1' 1/4 Section 25,TSN,1266\% County: AVeld O Request MODIFICATION to existing permit(check each box below that applies) Elevation: 4,691 hect ❑ Change fuel or equipment ❑ Change company name Portable Source ❑ Change limit b permit ❑ Transfer of ownership ❑ Other Home Base: ❑ Request PORTABLE source permit Mailing Address: 370 17th Street,Suite 2500 ZIP Code: 80202 © Request APEN update only(check the box below that applies) Denver,Co Revision to actual calendar❑ year emissions tar cmttssupn inventory I Person'Fri f77Update 5-Year APEN term without change to permit limits or previously reported Contact: llill Phone Number: 303-605-1716 __.. emissions E-mail Address: wdhilaa dcpmidstream.com L=ax Number: 303-605-1957 ❑ Notification of AOS permanent replacement Addl. Section 03—General Information Info.& Notes: For csistiog sources,operation began on: 1 16 1 1986 For new or reconstructed sources,the projected startup date is: — Normal hours of source operation: 24 7 days/week 52 weeks/year General description of equipment purpose: Refrigeration Date the engine was ordered: pre-1986 Date engine construction commenced: Date the engine was relocated into i.olorado: pre-1986 Date of any reconstruction%ntoditication: Colorado Department of Public health and Environment — Air Pollution Control Division(APCD1 Will this equipment be operated in any NAAQS nonattaimneot area' (limy w tie .cd2?!t_stt_ us Ah.ail;rimnainta n,l ui�O ❑ Yes ❑ No 0 Don't This notice is valid for five(5)years. Submit a revised APEN prior to know expiration of five-year term, or when a significant change is made Section(14— Kii ire lmforntatiun (increase production,new equipment,change in fuel type,etc). Engine date ofntanutueaure: 03/01/1974 Engine displacement: 115 L'cyl Mail this form along with a check for $152.90 per APEN and — $1,500 for each general permit registration to: 1lanufaeturer. ,,%aukesha Model:oel: L7042 GM Serial No.: 261947 Colorado Department of Public Health&Environment Engine fianctiia: APCD-SS-BI r ❑ Primtary and-or peaking power ❑ Emergency back-up power 4300 Cherry Creek Drive South Cong>icssion ❑ Pump jack ❑ Water pump ❑ Other: Denver,CO 80246-1530 For guidance on how to complete this APEN(cut: Manufacturer's rnaxiruutn ruled horsepower al sea level: 1,100 BHP 4, 900 RPM Air Pollution Control Division: (303)692-3150 Manufacturer's maximum,ite_rimm,: BHP fu' RPM kW Small Business Assistance Program(SOAP): (303)692-3148 or Engine Brake Spccitie Fuel Consumption cii: 1009'01.011d: 8,490 Btu/HP-hr - (303)692-3175 — APEN limns:http:awww.cdphe.state.cu.us apidownloadtiirrus.hmnl Cycle Type: ❑ 2-Sirokc ❑Q 4-Stroke Combustion: ❑ Lean Burn ® Rich Bum Application status:http:_wwv4 rdohe.statc,cuus,apiss sspcorhtmil ignition Source: ❑ Spark ❑ Compression Aspiration: ❑ Natural ® Turbocharged U Check box to request copy of draft permit prior to issuance. What is the maximum number of hour,this engine is used for emergency back—up power? ILours/ycar 0 Check box to request copy of draft permit prior to public notice. FORM APCD-201 :.. 291388 Page I of 3 Greeley APFN C I Iii,dcic AIR POLLUTANT EMISSION NOTICE (.ADEN)& Application for Construction Permit—Reciprocating Internal Combustion Engine Permit Number: 95OPWE038 Emission Source AIRS ID: 123 / 0099 / 103 Section 05—Stack In formation(Attach a separate sheet with relevant information in the event of multiple stacks;provide datum&either Lat/Long or UTM) Operator pe}tor Stack hieV Base ��ftr��tDrAt"Y�gr 1'rmp.(°F) Flow Raw Velocity Moisture r Horizontal NAD83, UTM UT Longitudef rigor UTM Latitude Northing or Method Data Collection for GPS Location Stack Base alOll g.t uoei t,c el (ACFM) (discs) (lo) ID NO. asst) �I feet) WGSxi) (12or13) (metcrsordegreiz) (meters GoogleEarth) SI22 Amble C'1 16 14.6 1100 615 522 -104.73055852 40.3636146826 CPS nt . Direction of stack outlet(check one): 0 Vertical ❑ Vertical with obstructing raincap O Horizontal O Down O Other(Describe): Exhaust Opening Shape 3 Sire(check one): 0 Circular:Inner Diameter(inches)_ 6 O Other:Length(inches)_ Width(inches)'= Section 06— Fuel Consumption Infornation Annual Fuel Consumption(gal/yr or MMSCF/yr) Sulfur Seasonal Fuel Use(%of Annual Use) Fuel Type Fuel Use Rate(w 100%load Actual Reported for Fuel Heating Value Content (SC Frier,galihr) Calendar Year Requested f ermit Limit (Btu/lb,Btu/gal,Btu/SCF) (�u ') Dec-Feb Mar-May Jun-Aug Sep-Nov Natural Gas 9.34 llMItt'1'U/hr 78.66 AINISCF/yr 1040 BTU/SCE 0 25 25 25 25 Is this engine equipped ssiti:an An'Fuel ratio controller? ® Yes O No Section 07— Emissions Inventory Information& Emission Control Information D. Emission Factor Documentation attached Data year fur actual calendar yr.emissions below&fuel use abuse(e.g.2907): I 2007 Control Device Description Control Emission Factor Actual Calendar Year Emissionst Requested Permitted Estimation Method Pollutant Efficiency Emissions or Pi-unarySeconduty (%Reduction) Uncontrolled Basis Units Uncontrolled Controlled Uncontrolled Controlled Emission Factor (Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Source .I_SP P11:.- SO, NO,v — NSCR 2.5 g/hp-hr — 138 26.55 Mani: VOC NSCR .5 g/hp-hr 531 5.31 Mardi CO NSCR 2.5 g/hp-hr 95.6 26.55 Mani. Fomtaldchcde NSCR 76 2.05E-02 lb/rnenBtu 0.84 0.02 AP-42 Acetaldehyde NSCR SU 2.79E-03 Ib/mmBtu 0.11 0.06 AP-42 Aerolein NSCR 50 2.63E-03 lb/mmBtu 0.11 0.05 AP-42 Bcnictte NSCR 50 1 1.58E-03 lb/tnnmBtu 0.06 I 0.03 AP-42 Please use the APCD Non-Criteria Reportable Air'Pollutant Addendum form to report pollutants not listed above. 'Annual emus n n lees ill be based on actual emissions reported here. If lett blank,annual emission fees will be based on requested emissions. Section 08—Applicant Certification - I hereby certify that all information contained herein and information submitted with this application is complete,true and correct. If this is a registration for coverage under general permit GI'02,I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. ) Signature of L //L ( W/// -`` Wesle •Hill -- — y } Senior E:nv.S�tecialist g Person Legally Authorized to Supply Data Date Name of Legally Authorized Person(11444.6,-print) Title Page 2 of 3 Greeley APFN(ith.doc NON-CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) Permit Number: 95OPWE038 AIRS ID Number: 123/0099/103 Company Name: DCP Midstream, LP Plant Location: SW '/4 Section 25, T5N, R66W County: Weld Zip Code: Person to Contact: Wesley Hill Phone Number: 303-605-1716 E-mail Address: wdhill(cr7dcpmidstream.com Fax Number: 303-605-1957 Chemical Reporting Control Equipment/ Emission Factor Emission Uncontrolled i Controlled Abstract Service 1 Chemical Name BIN Reduction(%) (Include Units) Factor Source Emissions(lbs/year) Emissions(Ibs/year). (CAS)Number 106-99-0 1,3 Butadiene A NSCR/ 50% Ib/m3mbtu AP-42 54.24 27.12 . — j 1 , l _ Reporting Scenario (1, 2 or 3): 1 Calendar Year for which Actual Data Applies: , .„' 7" 1 //'' . ` '1't a . { J Signature of Person Legally uthorized to Supply Data r Date Wesley Hill ____ __.._ _.__ .. ..____—._ Senior Environmental Specialist Name of Person Legally Authorized to Supply Data (Please print) Title of Person Legally Authorized to Supply Data Form Revision Date: December 4,2006 AIR LLUTANT EMISSION NOTICE(APEN)& Application fr onstruction Permit—Reciprocating Internal Combustion Eng Permit Ntlonber: 95OPWE038 [Leave blank unless APCD has already assigned a permit 4&AIRS 1D] Emission Source AIRS ID: 123 / 0099 / 104 Facility Equipment ID: P123(O117) — [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01—Administrative Information Section 02—Requested Action(check applicable request boxes) Company Name: DCP Midstream,LP NAICS,or ❑ Request for NEW permit or newly reported emission source SIC Code: 1311 Source Name: Greeley Natural Gas Processing Plant ❑ Request PORTABLE source permit Source Location: SW 1/4 Section 25,T5N,R66W County: Weld ❑ Request MODIFICATION to existing permit(check each box below that applies) Elevation: 4,691 Feet ❑ Change fuel or equipment ❑ Change company name Portable Source ❑ Change permit limit ❑ Transfer el ownership ❑ Other Home Base: ❑ Request to limit HAPs with a Federally enforceable limit on PTE Mailing Address: 370 I7`h St.,Suite 2500 ZIP Code: 80202 ❑ Request APEN update only(check the box below that applies) Denver,CO ❑ Revision to actual calendar year emissions for emission inventory Person To Update S-Year APEN term without change to permit limits or previously reported Contact: Wesley 11i11 Phone Number: 303-605-1716 ❑ emissions E-mail Address: wdhill@dcpntidstreanl.com Fax Number: 303-605-1957 ® Notification of AOS permanent replacement Addl. Section 03—General Information Notes: & Like-kind engine replacement Notes: For existing sources,operation began on: 12 / 11 1 2002 For new or reconstructed sources,the projected startup date is: / — / Normal hours of source operation: 24 hours/day 7 daystweek 52 weeks/year General description of equipment purpose: Natural Gas Compression f Date the engine was ordered' Before 12/02 Date engine construction commenced: 2002 Date the engine was relocated into Colorado: 2002 Date of any reconstruction/modification: — Colorado Department of Public Health and Environment Air Pollution Control Division{APC.D) Will this equipment be operated in an) NAAQS nonattaimnent area? ® Yes ❑ Na ❑ Don't (http:t/www.cdphe.state co.us(ftpiattatnmaintain.html) know This notice is valid for five(5)years. Submit a revised APEN prior to expiration of five-year term, or when a significant change is made Section 04—Engine Information (increase production,new equipment,change in fuel type,etc). Engine date of manufacture: prior to 715/05 Engine displacement; 115 L1cyi Mail this form along with a check for S152.90 to: Manufacturer: Waukesha Model: L7042 GS' Serial No.: 898468 Colorado Department of Public Health& Environment __-._ APCD SS-B1 4300 Cherry Creek Drive South Engine function: ❑ Primary and/or peaking power ❑ Emergency back-up power Denver,CO 80246-1530 © Compression ❑ Pump jack ❑ Water pump ❑ Other: —_.._. For guidance on how to complete this APEN form: Air Pollution Control Division: (303)692-3150 Manufacturer's maximum rated horsepower @ sea level: 1,100 BHP @ 900 RPM Small Business Assistance Program(SBAP): (303)692-3148 or Manufacturer's maximum site.rapt[ 1,100 BHP @ 900 RPM kW (3'03)692-3175 Engine Brake Specific Fuel Consumption @ 100%Load: 8,490 Btu/HP-hr APEN forms:Ititp://www.cdphe,state.co,us/ap/ciownloadforms.html Cycle Type: ❑ 2-Stroke ED 4-Stroke Combustion: ❑ Lean Burn ED Rich Burn Application status:littn://www.cdohe.state co.us/ap/ss1s.spept.html Ignition Source: ❑ Spark ❑ Compression Aspiration: ❑ Natural ® Turbocharged ❑ Check box to request copy of draft permit prior to issuance. What is the maximum number of hours this engine i$used for emergency back-up power? _ Hours/year LA Check box to request copy of draft permit prior to public notice. FORM APCD-201 291, 389 Page 1 of 2 Greeley P123(C-117)APEN-FormAPCD 201-RICEAPEN.dx. AIR t<k.LLUTANT EMISSION NOTICE(APEN) & Application fo nstruction Permit—Reciprocating Internal Combustion Engi Permit Number: 95OPWE038 Emission Source AIRS ID: 123 / 0099 / 104 Section 05—Stack Information(Attach a separate sheet with relevant information in the event of multiple stacks;provide datum&either lid/Long or U'TM) (�` �_.- Stack Disehat'ge Fasting OStack r Stack Base ! Height Above Flow Rate Velocity lvloisture Horizontal Datum ((TM U("1 Easdng or UTM Northing or Method of Collection for Location 1 St. o Elevation i ‘feet), Temp.{°F} r ) (NA WGS84)NADS3, Zone(1.or 13) 1 (metLongitude stor degrees) (meters or degrees)e DatGa(ogleEae.g. nh)PS, ID No, i (feet) Ground Level (ACFM) (fttsce { ) P123/C117_ 4,691 26 1055 5,377 114 WGS84 I 13 522,877 4,468,151 1 GPS_,,,..„,,..,,,,,,,___A Direction of stack outlet(check one): E Vertical ❑ Vertical with obstructing raincap ❑ Horizontal D Down O Other(Describe): Exhaust Opening Shape&Size(check one): E Circular:Inner Diameter(inches)= 12 O Other Length(inches)_ _ Width(inches)=- Section 06—Fuel Consumption Information Fuel Use Rate�c 100%load Annual Fuel Consumption�gallyr or MMSCFI}Tl Sulfur Seasonal Fuel Use(%of Annual Use) Fuel Type Actual Reported for Fuel Heating Value Content (SCl ihr,gal/hr) Requested Permit Limit (Btu/lb,Btu/gal,Btu/SCF) ° Dec-Feb Mar-May Jun-Aug Sep-Nov CaF----- _ lendar Year {,° fur Natural Gas 8,984 SCE/hr 78.7 M1l bisefivr 1040 Btu/scf Neg. 25 25 25 25 Is this engine equipped with an Air/Fuel ratio controller? E Yes ❑ No Section 07—Emissions Inventory Information&Emission Control Information ® ;r _ i Requested_ Emission Factor Documentation attached Data year for actual calendar yr.emissions below&fuel use above leg 2007): , - _ Permitted Estimation Method Control Device Description ' Control Emission Factor Actual Calendar Year Emissions Emissionsz or Pollutant Efficiency Uncontrolled Controlled Uncontrolled Controlled Emission Factor Primary Secondary (%Reduction) Uncontrolled Basis Units (Tons/Year) (Tons/Yca ear(TonslY (Tons/Year) Source TSP PM to 9.5E-3 113/mmbtu — 0.39 0.39 AP-42 PM2 s 9.5E-3 lb/mmbtu 0.39 0.39 AP-42 SOx 5.88E-4 Ibimmbtu — 0.02 0.02 AP-42 NOx NSCR 2.5 g/bhp-hr 138 26.6 Manuf.data VOC NSCR 0.5 g/bhp-hr 5.3 5.3 Manuf,data CO NSCR 2.5 g/bhp-hr 95.6 26.6 Manuf.data Formaldehyde NSCR 76% 2.05E-02 lb/mmbtu 0.84 0.20 AP-42 Acetaldehyde NSCR 50% 2.79E-03 lb/mmbtu 0.11 0.06 AP-42 Acrolein NSCR 50% 2.63E-03 lb/mmbtu 0.11 0.05 AP-42 Benzene NSCR 50% 1.58E-03 Ib/mmbtu 0.06 i 0.03 AP-42 Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. :_ _ — i 'Annual emission fees will be based on actual emissions reported here. if left blank,annual emission fees will be based on requested emissions 2 If Requested Permitted Emissions is left blank,the APCD will calculate emissions based on the information supplied in sections 03-07. Section 08—Applicant Certification-I hereby certify that all information contained herein and information submitted with this application is complete,true and correct. /�,s/'c r ( Wesley Hill 4Y Sr.Environmental Specialist Signature`oofPerso ' zgally Autho zed to Supply Data Da Name of Legally Authorized PersontPlerase print) Tide Page 2 of 2 Greeley P123(C-I 17)APEN-FonnAPCD-201-RICEAPEN.doc I NON-CRITERIA REPORTABLE AIR POL__TANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) . Permit Number: 95OPWE038 AIRS ID Number: 123/0099/104 Company Name: DCP Midstream, LP Plant Location: SW 1/4 Section 25, T5N, R66W County: Weld Zip Code: Person to Contact: Wesley Hill Phone Number: 303-605-1716 E-mail Address: wdhili(a�dcpmidstream.com Fax Number: 303-605-1957 Chemical Reporting Control Equipment/ I Emission Factor r Emission Uncontrolled Controlled Abstract Service Chemical Name BIN Reduction(%) (Include Units) Factor Source I Emissions(lbs/year) Emissions (lbs/year) (CAS)Number � 6.63E-4 106-99-0 i 1,3 Butadiene A NSCR/ 50°/a AP-42 54.24 27.12 ib/mmbtu il _ I _ i re__ ___ .1.____ _ __[.....,_ ......____„......,__,...._ ___________,IErC -.1=1,.ilIMIM. Reporting Scenario (1, 2 or 3): Calendar Year for which Actual Data Applies: I 7:—J1-' -'---7-7,//'/Z -'1 t Signature of Person Legally Authorized to Supply Data 4Y Date I Wesley Hill I i l Senior Environmental Specialist Name of Person Legally Authorized to Supply Data (Please print) Title of Person Legally Authorized to Supply Data Form Revision Date: December 4, 2006 AIR POLLUTANT EMISSION NOTICE (APEN) &Application for Construction Permit—Reciprocating Interim'Combustion Engin Permit N umber: 95OPWE038 [Leave blank unless APCD has already assigned a permit#&AIRS ID] Emission Source AIRS ID: 123 / 0099 I 105 Facilitky Equipment ID: P 124ff 118) [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.) Section 01—Administrative Information Section 02—Requested Action(check applicable request boxes) Company Name: DCP Midstream,LP NAICS,or • O Request for NEW permit or newly reported emission source SIC Code: 1311 Source Name: Greeley Natural Gas Processing Plant O Request PORTABLE source permit Source Location: SW 1/4 Section 25,TSN,R66W i County: Weld O Request MODIFICATION to existing permit(check each box below that applies) Elevation: 4,691 Feet O Change fuel or equipment ❑ Change company name Portable Source O Change permit limit ❑ Transfer of ownership ❑ Other Home Base: ❑ Request to limit HAPs with a Federally enforceable limit on PTE • Mailing Address: 370 17t St.,Suite 2500 ZIP Code: 80202 O Request APEN update only(check the box below that applies) Denver,CO ❑ Revision to actual calendar year emissions for emission inventory Person To Update 5-Year APEN term without change to permit limits or previously reported Contact: Wesley 11111 Phone Number: 303-605-1716 ❑ emissions E-mail Address: wdhill@depmidstream.com Fax Number: 303-605-1957 ® Notification of AOS permanent replacement Addl. Section 03—General Information Info.& Like-kind engine replacement Notes: For existing sources,operation began on: 2 / 19 / 2003 For new or reconsrnreted sources,the projected startup date is: Normal hours of source operation: 24 hours/day 7 days/week 52 weeks/year General description of equipment purpose: Natural Gas Compression Date the engine was ordered: Before 4/75 Date engine construction commenced: 1975 Date the engine was relocated into Colorado: 1975 Date of any reconstruction/modification: Colorado Department of Public Health and Environment Will this equipment be operated in any NAAQS nonattainment area? ® Yes ❑ No O Don't Air Pollution Control Division(APCD (httn://www.cdphe.state.co.us/an/attainmaintain.html) know This notice is valid for five(5)years. Submit a revised ADEN prior to Section 04—Engine Information expiration of five-year term, or when a significant change is made (increase production,new equipment,change in fuel type,etc). Engine date of manufacture: 4/9/75 _ Engine displacement: 115 L/cyl Mail this form along with a check for$152.90 to: Manufacturer: Waukesha Model: L7042 GSI Serial No.: 286434 Colorado Department of Public Health&Environment APCD-SS-Bl Engine function: ❑ Primary and/or peaking power ❑ Emergency back-up power 4300 Cherry Creek Drive South ►Z4 Com rcsion Pump jackWater pump Denver,CO 811246 1530 P ❑ O O Other: For guidance on how to complete this APEN form: Manufacturer's maximum rated horsepower @ sea level: 1,567 BHP @ 1,200 RPM Air Pollution Control Division: (303)692-3150 Small Business Assistance Program(SBAP): (303)692-3148 or Manufacturer's maximum site rating: 1,100 BHP @ 1,200 RPM kW (303)692-3175 Engine Brake Specific Fuel Consumption @ 100%Load: 8,490 Btu/HP-hr APEN forms:http:/lwww.cdphe.state.co.us/ap/downloadforms.html Cycle Type: O 2-Stroke ® 4-Stroke Combustion: O Lean Burn ® Rich Burn Application status:http://www,cdphe.state.co.ustap/ss/sspept.html Ignition Source: :4 Spark O Compression Aspiration: O Natural ® Turbocharged O Check box to request copy of draft permit prior to issuance. What is the maximum number of hours this engine is used for emergency back-up power? - I iours/year ® Check box to request copy of draft permit prior to public notice. FORM APCD-201 4)'-1 201,3 Page 1 of 2 2.91390 Greeley P124(C-118)APEN-FunnAPCD-201-RICEAPEN.doc AIR POLLUTANT EMISSION NOTICE(APEN)& Application for Construction Permit—Reciprocating Internal Combustion Engin Permit Number: 95OPWE038 Emission Source AIRS ID: 123 / 0099 / 105 Section 05—Stack Information(Attach a separate sheet with relevant information in the event of multiple stacks;provide datum&either Lat./Long or UTM) I Stack Discharge Operator Stack Base. i Horizontal Datum ' UTM LT vi L-;asting or U'fM Northing or Method of Collection for Location Fright Above Flow Rate Velocity Moisture ,r Stack Elevation Temp.(°F) ° I (NAD..7,NADU, zone Longitude Latitude Data(e.g.map,GPS, Ground L.evet (ACCM) i (ft/six) -:I , (!e) WGS84 (12. _ _ .13)., _(meters g ):,:_j_.(meters es) gt__� ) { ID Na. (feet) (feet) ) or or degrees) or degrees) Goa leEarclt P1241C118 4,691 26 1055 5,377 114 1,�--._ WCS84 MEMI 522,877 4,468,151 GPS Direction of stack outlet(check one): ® Vertical ❑ Vertical with obstructing raincap 0 Horizontal ❑ Down 0 Other(Describe): Exhaust Opening Shape&Size(check one): El Circular.Inner Diameter(inches).- 12 O Other:Length(inches)_: Width(inches)= Section 06—Fuel Consumption Information Annual Fuel Consumption(gal/yr or MMSCF/yr) Sulfur Seasonal Fuel Use(%of Annual Use) Fuel Use.Rate @ 100%load Fuel Heating Value Fuel Type `Actual Reported for Content (SCF/hr,galfltr) Permit Limit (Btu/lb,tb,Btu gal,Btu/SCF) o Dec-Feb Mar-May Jun-Aug Sep-Nov Requested• /o wt-) Natural Gas 8,984 SCF/hr 78.7 MMscf/yr 1040 Btu/scf Neg. 25 25 25 25 Is this engine equipped with an Air/Fuel ratio controller? ® Yes ❑ No Section 07—Emissions Inventory Information&Emission Control Information 0 Emission Factor Documentation attached Data year for actual calendar yr.emissions below&fuel use above(e.g.2007): Control Device Description Control Emission Factor Actual Calendar Year Emissions' Requested Permitted Estimation Method I Pollutant Efficiency Emissions2 or Primary Secondary {%Reduction) Uncontrolled Basis Units Uncontrolled Controlled Uncontrolled Controlled Emission Factor ...��_ .._. __._. (Tons/Year) (Tons/Yea ("I'onslYear) (Tons/Year) Source TSP PM Jo9.5E-3 lb/mmbtu 0.39 0.39 AP-42 PM2.5 9.5E-3 lb/mmbtu 0.39 0.39 AP-42 SOx 5.88E-4 lb/ntmbtu 0.02 0.02 AP-42 NOx NSCR 2.5 g/bhp-hr _ 138 26.6 Manuf,data VOC NSCR 0.5 g/bhp-hr 5.3 5.3 Manuf.data CO NSCR 2.5 g/blip-hr 95.6 26.6 Manuf data Formaldehyde NSCR 76% 2.05E-02 lb/mmbtu 0.84 0.20 AP-42 Acetaldehyde NSCR 50% 2.79E-03 lb/rnmbtu 0.11 0.06 AP-42 Acrolein NSCR 50% 2.63E-03 lb/mmbtu 0.11 0.05 AP-42 Benzene NSCR 50% 1.58E-03 lh/mmbtu 0.06 0.03 AP-42 Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. r Annual emission fees will be based on actual emissions reported here. If left blank,annual emission fees will be based on requested emissions 2 If Requested Permitted Emissions is left blank,the APCD will calculate emissions based on the infortnation supplied in sections 03-07. Section 08—Applicant Certification-I hereby certify that all information /contained herein and information submitted with this application is complete,true and correct. ,,e---<-,-1711- ••"" 7—2_j `" l(( Wesley Hill Sr.Environmental Specialist Signature of Person Leg ?y Authorized to Supply Data Date Name of Legally Authorized kryson(Please print) Title r , Page 2 of 2 Greeley P124(C-118)APEN-FormAPCD-201-RICE.APEN.doe NON-CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM • (See reverse side for guidance on completing this form) Permit Number: 95OPWE038 AIRS ID Number: 123/0099/105 _ Company Name: DCP Midstream, LP Plant Location: SW '/a Section 25, T5N, R66W County: Weld Zip Code: Person to Contact: Wesley Hill Phone Number: 303-605-1716 E-mail Address: wdhillC�dcpmidstream.com Fax Number: 303-605-1957 Chemical Reporting Control Equipment! Emission Factor Emission Uncontrolled Controlled Abstract Service Chemical Name BIN Reduction(%) (Include Units) Factor Source Emissions(Ibs/year) Emissions(lbs/year) (CAS) Number 6.63E-4 106-99-0 1,3 Butadiene A NSCR/50% lb/mmbtu AP-42 54.24 27.12 Reporting Scenario (1, 2 or 3): 11// Calendar Year for which Actual Data Applies: 2009 Signature of Person Legally Authorized to Supply Data Date Wesley Hill Senior Environmental Specialist Name of Person Legally Authorized to Supply Data (Please print) Title of Person Legally Authorized to Supply Data Form Revision Date: December 4,2006 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit— Reciprocating Internal Combustion Engine Permit Number: 95OPWE038 ►Leave blank unless APCD has already assigned a permit a&AIRS ID) Emission Source AIRS ID: 123 / 0099 / 106 Facility Equipment Ill: 1'125(C 1 19) [Provide Facility I quipment ID to identity how this equipment is referenced within your organization) Section 01 —Administrative information Section 02—Requested Action(check applicable request boxes) Company Name: U('N Midstream,LP NAICS,or 1311 O Request for NEW permit or newly reported emission source Midstream, P Source Name: Processing Greeley'Natural Gas Plant SIC Code: y b ❑ Request for coverage under GENERAL PERMIT number GP02(Natural Gas Only) Source Location: 3009 West 49th Street,Greeley,CO 80634 County: Weld O Request MODIFICATION to existing permit(check each box below that applies) SSW Section 25,•I'5N,R66W Elevation: 4,691 Feet ❑ Change fuel or equipment O Change company name Portable Source O permit limit Change g permit O Tratislr of ownership O Other flume Base O Request PORTABLE source permit Mailing Address: 370 17th Street,Suite 2500 ZIP Code: 80202 0 Request APEN update only(check the box below that applies) Denver,Co O Revision to actual calendar year emissions for emission inventory Persist Jo Update 5-Year APL\term without change to permit limits or previously reported Couwrt: DIUIa Stephens Phone Number: 303-605-1715 Ei emissions E-mail Address: DStephensur DCPMidstream.com Fax Number: 303-605-1957 O Notification of AOS permanent replacement Addl. Section 03—General information Info.& Notes: For existing sources,operation licttau on: 05 , 30 2001 For new or reconstructed sources,the projected startup date is: i / Normal hours of source operation. 24 hoursday 7 days/week 52 weeks/year General description 01 equipment purpose, Natural Gas Compression Date the engine tv;u ordered: Pre-2001 Date engine construction commenced: Pre-2001 Date the engine was relocated Min Colorado: Pre-2001 Date of any rcconstructton/moditication: Colorado Department of Public Health and Environment j — Air Pollution Control Division(APCDZ Will this equipment be operated in any NAAQS nonattainntent area? Don't ® Yes O No ❑ This notice is valid for five(5)years. Submit a revised APEN prior to know expiration of five-year term, or when a significant change is made Section 04—Engine Information (increase production,new equipment,change in fuel type,etc). L'cyp Mail this form along with a check for $152.90 per APEN and Engine date of tnanulaeturc: Pre-2001 Engine displacement: $1,500 for each general permit registration to: Manutactwcr: 't uukeshat Mask! L7042 CSI Serial No.: 327603 Colorado Department of Public Health& Environment APCD-SS-B 1 Engine function: O Primary and.or peaking lower O Emergency back-up power 4300 Cherry Creek Drive South 0 Compression O Pump jack O Water pump O Other: Denver,CO 80246-1530 For guidance on how to complete this APEN form: Manufacturer's maximum rated horsepower(u sea lcsel: 1,100 BHP(a; 1,200 RPM Air Pollution Control Division: (303)692-3150 Manufacturer's maximum site braising: 1,100 Bill'(ti, 1,200 RPM kW Small Business Assistance Program(SBAP): (303)692-3148 or , Engine Brake Specific Fuel Consumption(u 1(X)°v Load: 8,490 Btu//HP-la (303)692-3175 APEN forms: imp a.wa_c irte.,t,ttc eo u,ap d,s:bloadt err_s.iumi Cycle Type: E 4-Stroke Combustion: p _'-Bunke ❑ Lean Bum ® Rich Bunt Application status Imp:, ct a .fhli�,i 1(C_e;11.a_,p,. i,vkPt_initi1 Ignition Source: 0 Spark O ('onipression Aspiration: O Natural ® Turbocharged ❑ Check box to request copy of draft permit prior to issuance. Vt hat is the maximum number of hours this engine is used for emergency back--up power? I lours/year 1 O Cheek box to request copy admit permit prior to public notice. FORMAPCI)-201 291391 j 0O —1 Ipj Page 1 of 2 P125 AI'EN(12.20 21113.doe AIR POLLUTANT [IISSION NOTICE (APEN) & Application for Construction Permit— Reciprocatini Internal Combustion Engine • Permit Number: 95OPWE038 Emission Source AIRS ID: 123 / 0099 / 106 Section 05—Stack Inform:Itio,u(Attach a separate sheet with relevant information in the event of multiple stacks;provide datum&either tat/I ong or UTM) Operator Stack Base siae.t)ischarge ibctglu Atx,ac Plow Rate Velocity Moisture Horizontal Datum UTM UTM Fasting or UTM Northing or Method of Collection for Location Stack Lie%aton t amp.CI'') y (NAD27,NAD83, Zone Longitude Latitude Data(e.g.map,GPS. 1D No. (fief) (mound Level (ACFM) 01isec) (%) l'•g• P fleet) WGS84) (12 or 13) (meters or degrees) (metas or degrees) GoogleEarth) P125 C119 1 4,69! 26.19 1,055 5,377 114 Amb SVGS 84 13 -104.7304 40.3642 CPS Direction of stack outlet(cheek one): Q Vertical O Vertical with obstructing rtincap O Horiamtal O Down O Other(Describe); Exhaust Opening shin,.\Size(check one): ® Circular:Inner Diau)eter(inches) - 12 O Other:Length(inches) - Width(inches)- , Section 06— Fuel Consumption Information Fuel Use kale ru I(1(l,'0 load Annual Fuel Consumption(gal/yr or MMSCF/yr) Sulfur Seasonal Fuel Use('%of Annual Use) Fuel Type (SC'L.hr, tl0( Actual Reported for Fuel Heating Value Content g ) Calendar Year Requested Pennit Limit (Btu,lh,Btulgal,BtuJSCF) (/Q wt) Dec-Feb Mar-May Jun-Aug Sep-Nov Natural Gus 8,984 SCF/hr 78.7 MMSCF/yr 1,040 BTU/SCE 25% 25•/ 25% 25% Is this engine equipped with an \ir Fuel ratio controller! ® Yes O No Section 07—Emissions Inventor) Information& Emission Control Information O Emission Factor Documentation attached Data sear fur actual calendar yr.emissions below Si.fuel use above(e.g.2007): Control Den'cc Description Control Emission Factor Actual Calendar Year Emissions, Requested Permitted Estimation Method Pollutant Efficiency Emissions or Priucu} Secondary ( Re-Auction) Uncontrolled Basis Units Uncontrolled Controllexi Uncontrolled Controlled Emission Factor (Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Source TSI' PM:': 1.94E-02 Ib/tnmBtu 0.79 0.79 AP-42 PM;' 1.94E-02 lb/mnrl3tu — — , 2 _ 0.79 0.79 AI-4,. SOs 5.88E-04 IbhnmBtu 2 0.02 0.02 AI-4,. NOx AS('R 13 g/bhp-hr �— 138.09 _ 21.24 Manf Data — V(x 0.5 g/bhp-hr 5.31 5.31 Mani. Data CO NSCR 9.0 g,/bhp-hr 95.60 26.55 Mant: Data Lurnwldchydc \SCR 76% 2.05E-02 lb/mmltu 0.84 0.20 AP-42 Acetaldchydr NSC'I( _ 50% 2.79E-03 IbhuniBtu 0.11 0.06 AP-42 Acruleiu NS('ll 50% 2.63E-03 Ib/mmBtu 0.11 0.05 AP-42 Benzene NSCR 50% 1.58E-03 lb/mmBtu 0.06 0.03 AP-42 __ __ Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Annual cn,is,nat Ice,ail In:based on actual emissions repotted here. If elf blank.annual emission lees will be based on requested emissions. Section 08—Applicant Certification- 1 hereby certify that all information contained herein and information submitted with this application is complete,true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit 61'02. C'� ._ n�vy�o 02-22-2013 Dana Stephens Sr.Environmental Engineer Signature of Person LeMll_ A uelorized to Supply Data Date Name of Legally Authorized Persott0ease print) Title Page 2 of 2 P125 APt-N 02202013.doe • NON-CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) Permit Number: 95OPWE038 AIRS ID Number: 123 /0099 / 106 Company Name: DCP Midstream, LP Plant Location: SW Section 25, T5N, R66W County: Weld Zip Code: Person to Contact: Dana Stephens Phone Number: 303-605-1745 E-mail Address: DStephens@DCPMidstream.com — — — Fax Number: 303-605-1957 Chemical1 Abstract Service Chemical Name Reporting Control Equipment t Emission Factor Emission ! Uncontrolled Actual Controlled Actual (CAS) Number BIN Reduction(%) (Include Units) Factor Source Emissions(lbs/year) Emissions(lbs/year) 00106-99-0 1,3 Butadiene A 50 6.63E-04 EPA 54.24 27.12 -- - i — lb/mmBtu i — I • Reporting Scenario (1, 2 or 3): 1 Calendar Year for which Actual Data Applies: 2013 "� — Signature of Person Legally 9uthorized to Supply Data Date Dana Stephens MAY - I ,,- Sr. Environmental Engineer ame of Person Legally Authorized to Supply Data (Please print) — Title of Person Legally Authorized to Supply Data Form Revision Date. December 4, 2006 AIR POLLUTANT EMISSION NOTICE(APEN)&Application for Construction Permit—Reciprocating Internal Combustion Eng____ - Permit Number: 95OPWE038 [Leave blank unless APCD has already assigned a permit#&AIRS ID] Emission Source AIRS ID: 123 I 0099 / 107 Facility Equipment ID: P 126(C120) (Provide Facility Equipment 11)to identify how this equipment is referenced within your organization.] Section 01--Administrative Information Section 02—Requested Action(check applicable request boxes) Company Name: DC'P Midstream,LP NAICS,or ❑ Request for NEW permit or newly reported emission source 1311 SIC Code:Source Name: Greeley Natural Gas Processing Plant ❑ Request PORTABLE source permit Source Location: SW 1/4 Section 25,T5N,R66W County: Weld ❑ Request MODIFICATION to existing permit(check each box below that applies) Elevation: 4,691 Feet ❑ Change fuel or equipment O Change company name Portable Source O Change permit limit ❑ Transfer of ownership D Other Home Base: ❑ Request to limit HAPs with a Federally enforceable limit on PTE Mailing Address: 370 176 St.,Suite 2500 " ZIP Code: 80202 O Request APEN update only(check the box below that applies) Denver,CO ❑ Revision to actual calendar year emissions for emission inventory Person To ❑ Update 5-Year APEN term without change to permit limits or previously reported Contact. Wesley 1101 Phone Number: 303-605-1716 emissions E-mail Address: wdhill@dcpinidstream.com Fax Number: 303-605-1957 El Notification of AOS permanent replacement Addl. Section 03 information specific to AIRS ID 123/0099/107 not replacement Section 03—General Information info.& engine.Section 04 information specific to engine serial#337569. Notes: For existing sources,operation began on: 01 / 14 / 1986 For new or reconstructed sources,the projected startup date is: / / Normal hours of source operation: 24 hours/day 7 days/week 52 weeks/year General description of equipment purpose: Natural Gas Compression Date the engine was ordered: Before 1986 Date engine construction commenced: Before 1986 Date the engine was relocated into Colorado: Before 1986 Date of any reconstruction/modification: Colorado Department of Public Health and Environment Will this equipment be operated in any NAAQS nonattainment area? Don't Air Pollution Control Division(APCD] (http://vvww.ecinhe.state.co ,'a attaimnaintain.html) ® Yes ❑ No ❑ know This notice is valid for five(5)years. Submit a revised APEN prior to Section 04—Engine Information expiration of five-year term, or when a significant change is made (increase production,new equipment,change in fuel type,etc). Engine date of manufacture' 10/15/79 Engine displacement: 115 Licyl Mail this form along with a check for$152.90 to: Manufacturer: Waukesha Model: L7042 CS! Serial No.: 337569 Colorado Department of Public Health&Environment APCD-SS-B1 Engine function: O Primary and/or peaking power O Emergency back-up power 4300 Cherry Creek Drive South is ( om ncssion Denver,CO 80246-1530 { ❑ Pump jack ❑ Water pump ❑ Other: For guidance on how to complete this APEN form: Manufacturer's maximum rated horsepower @ sea level: 1,100 BHP @ 900 RPM Air Pollution Control Division: (303)692-3150 Manufacturer's maximum site rating: 1,100 BHP @ 900 • RPM kW Small Business Assistance Program(SBAP): (303}692-3148 or (303)692-3175 Engine Brake Specific Fuel Consumption @ 100%Load: 8,490 Btu/IIP-hr APEN forms:http://www.cdphe.state.co,us/apidownloadforms htmi Cycle Type: ❑ 2-Stroke 0 4-Stroke Combustion: ❑ Lean Burn ® Rich Bum Application status:http:/lwww.cdphe.state.co.us-tphsicspcpt,htm( Ignition Source: ® Spark O Compression Aspiration: ❑ Natural ® Turbocharged ❑ Check box to request copy of draft permit prior to issuance. What is the maximum number of hours this engine is used for emergency back—up power? Hours/year ❑ Check box to request copy of draft permit prior to public notice. FORM APCD-201 12p\t r Page 1 of 2 291392 Greeley P126 APEN Renewal-ForrnAPCL)-201-RICEAPEN doc / Q"{ - a O AIR POLLUTANT EMISSION NOTICE (APEN)&Application for Construction Permit—Reciprocating Internal Combustion Engi1f'C Permit Number: 95OPWE038 Emission Source AIRS ID: 123 / 0099 I 107 Section 05—Stack Information(Attach a separate sheet with relevant information in the event of multiple stacks;provide datum&either Lat/Long or UTM) r=— Operator Stuck Discharge Horizontal Datum UTM UTM Easting or UTM Northing or Method of Collection for Location p Stack Base Height Above Flow Rate Velocity Moisture Stack I Elevation Temp.('F) (NAD27,NAD83, Zone Longitude Latitude Data e .ma GPS, ID No. (feet) Ground Level (ACFM) (ftrsec) (%) g ( g A. m_ (feet) WGS84) (12 or 13) (meters or degrees) (meters or degrees) GoogleEarth) P-126 4691 28 1055 5,377 114 16 WGS84 13 522,877 4,468,151 GPS Direction of stack outlet(check one): 1 Vertical ❑ Vertical with obstructing raincap O Horizontal O Down O Other(Describe): Exhaust Opening Shape&Size(check one): El Circular: Inner Diameter(inches)= 12 O Other:Length(inches)= Width(inches)= Section 06—Fuel Consumption Information Fuel Type Fuel Use Rate CR 100%load Annual Fuel Consumption(gal/yr or MMSCF/yrl Fuel Heating Value Sulfur Seasonal Fuel Use(%of Annual Use) Yp' (SCF/hr,gal/hr) Actual Reported for Requested Permit Limit (Btu/lb,Btu/ al,Btu/SCF} Content Calendar Year 9 g (%wt.) Dec-Feb Mar-May Jun-Aug Sep-Nov Natural Gas 8,984 SCF/hr 78.7 MMscf/yr 1040 Btu/scf Neg. 25 25 25 25 Is this engine equipped with an Air/Fuel ratio controller? ® Yes O No Section 07—Emissions Inventory Information& Emission Control Information El Emission Factor Documentation attached Data year for actual calendar yr.emissions below&fuel use above(e.g.2007):1 Control Des ice Description Control Emission Factor Actual Calendar Year Emissions' Requested Permitted Estimation Method Pollutant Efficiency Emissions2 or Primary Secondary (%Reduction) Uncontrolled Basis Units Uncontrolled Controlled Uncontrolled Controlled Emission Factor (Tons/Year) (Tons/Year) Tons/Year) (Tons/Year) Source TSP PM le Mils SOS NOs NSCR 138 26.6 Manuf.data VOC NSCR 5.3 5.3 Manuf.data CO NSCR 95.6 26.6 Manuf.data Formaldehyde NSCR 76% 0.84 0.20 AP-42 Acetaldehyde NSCR 50% 0.11 0.06 AP-42 Acrolein NSCR 50% 0.11 0.05 AP-42 Benzene NSCR 50% 0.06 0.03 AP-42 Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. 'Annual emission fees will be based on actual emissions reported here. If left blank,annual emission fees will be based at requested emissions. 2 if Requested Permitted Emissions is lett blank,the APCD will calculate emissions based on the information supplied in sections 03-07. Section 08—Applli—nt C rtii cat' n- I hereby certify that all information con fined herein and information submitted with this application is complete,true and correct. J V ` / 0 Wesley,Hill Sr.Environmental Specialist Signa ure of Pens• Legally Authorized to Supply Data D to Name of Legally Authorized Person(Please print) Title 12013 Page 2 of 2 t Greeley.P126 ADEN Renewal-FormAPCD-201•RICEAPFN doc NON-CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM • (See reverse side for guidance on completing this form) Permit Number: 95OPWE038 AIRS ID Number: 123/0099/107 Company Name: DCP Midstream, LP Plant Location: SW 1/4 Section 25, T5N, R66W County: Weld Zip Code: Person to Contact: Wesley Hill Phone Number: 303-605-1716 E-mail Address: wdhill@dcpmidstream.com Fax Number: 303-605-1957 Chemical Reporting Control Equipment/ Emission Factor Emission Uncontrolled Controlled Abstract Service Chemical Name (CAS) Number BIN Reduction(°/0) (Include Units) Factor Source Emissions(lbs/year) Emissions(lbs/year) 106-99-0 1 3 Butadiene A NSCR /50% 6.63E-4 ! AP-42 54.24 27.12 Ib/mmbtu Reporting Scenario (1, 2 or 3): 1 Calendar Year for which Actual Data Applies: 2009 //2-g/ Signature of erson Legally Authorized to Supply Data Date Wesley Hill tAr - z 2013 Senior Environmental Specialist Name of Person Legally Authorized to Supply Data (Please print) Title of Person Legally Authorized to Supply Data Form Revision Date: December 4, 2006 AIR POLI.I"'.ANT E\IISSION NOTICE (APEN)& Application for Construction Permit- Reciprocating Internal Combustion Engine Permit Number: 95OPWE038 I!a blank unless,\PCI)has alicady assigned a(emit it&AIRS u) AIRS II): 123 / 0099 / 108 I Emission Source Facility figwpwent II). P127 (('-I23) I Pn,elJe Faeiiny F,tulpux•ut ID to IJenuly h,rw the equipment is r•k:unced+snhm your organization( Section 01 -- Adutinistratise Inlurinatiou Section 02 Requested Action(check applicable request boxes) Company Name U( P\Gdstrcaia LP NAILS,or ❑ Request for NEM permit or mewl) reported emission source Saurcc\auic Grecle'a Natural(:as Processing Plait S►(('ode: 1311 ❑ Request for coverage under GENERAL PEKAI l't number GPU2 1\arural Gas Only t Sourer t.....auuu• SN\ . _Secu bt on 25, hS\,KO ' County: Nerd ❑ Request M1IODIF"1(:�htON to existing permit(check each box brio" that applies) F Icsation 4,691 Feet ❑ Change fuel or equipment ❑ Change company name 1 unable lourec Horne Base Change permit limit ❑ 1 ransler of ownership O Other ❑ Request PORTABLE source permit Mailing Address 370 17th Street,Suite 2500 L11'Cl de• 80202 ® Request APES update only(check the box Mlow that applies) )unsr,CO ❑ Res 151O0 to actual calendar year cmissh,m for emission MY entury Per,. I o Coma,I Q l plate 5-Year APEN term without change to permit limits or previously reported Nlesiet Hili Phone Number 3Ui bU5 171b missions t!-mall \ddtess wdhdl u dr)midstreunt.cum - ---- 1 fay �undxr. 303-605-1957 ❑ Notification of AOS permanent replacement Section 03 - .eneral Information Info.& ( Notes: psi Lt}b,uure.r,.opsr.iu,at i><r .,u,ui 19!{6 For new orreeanstructed sources,the projected startup date i, Normal hour-,of soiree o eauti„n __.-.--_—_- 1 24 hour,day 7 days w eek 52 weeks,year General des.npm,n at equiplucnt p,ipo,e General( onipressiun ale Mc ettglne was til,lei c'd. Date eltgllte construction commenced. _ ---- - - '-- - - l)ate the engine uu,del„e,teel aim,( ,rlorauo ___ Date ai any reconstruction modification: Colorado Department of Public BEAM and Environment W ill this equipment he ,per.ted ni any N.\\l�S non.lttanunult area? — Air Pollution Control Division(A P('U) (I ii t; ytoit ,,,ILt sink us �1, ,u u.d1,.:uti oo moil) ❑ No Don't ❑ 11 ® this miller I5 culid for five 5 know ( )years Submit a revised J\PI N prior to Section 04-- 1^.utliue Informotiiitt expiration of t fi r-ye tent, or when a significant el ii_e is made (increase production,new equipment.change in fuel Is pc.etc) Pigott date ofut.uwt.+lture prior to 1978 Engine displacement: 115 L cyl g with a check for 5152.90 per APEN and \tarrufaewrcr Mail this form atom ss aikesha -lodcl 1.7042 Gt _—. 51,500 for eachgeneral Serial No.: 269013 permit registration to: Colorado Department of Public Health& Environment Lngutc tuition DPr'nnury anJ or peaking(x,vsri APCD-SS-111 ❑ Fnters,eney hack-up(waver 4300('herr} ("reek Drive South (_] l ,ni;pic„son ❑ I'ump)ack ❑ Water pump ❑ Other Denver,CO SU246-1530 S},uwtaeturrr niavnunn ruled holsr(>,oer a xa lead For guidance on how to complete tit is APIA limn. 896 1-1111,,u 1,0(10 RPM Air Pollution('antral Division' �- SlanUtaelurer's ulasuaunt',di tro;; -- (itiltb 2 iI5il 1311P a RPM k w Small Business Assistance Program(SibAl'I. (303 i('12 +I45 or I ngutc Brake Specific I eel lr,um loon .r itNi 1 toad: $4112 Btu.FIP-hr (31 t 3)092-3175 ( stile 1\Ik. ❑ ' sirs' j ,us.ij,loan --_ kc 0 4-Stroke Combustion' Applicationl staitus:httw�l�.,,Iwle,lpt nl�,(rll rn�,LUuI Ignition Source.. ❑ Lean Burn `� Rich Burn b CI spark ❑ Compression Aspiration ® ❑ 1 L,t, llr u, ,i+„ „to,fn L;nit Natural furtx/chargsxl What as the niasnnunl'mother of hour,Uus engine b used cur emergency hack up wucr" 0 Check box to request copy of draft permit prior to issuance. 1 flours,year ® Check I>.1x to request copy of draft(spot prior to puhhc nl,ticc. FORM APCU-?UI }age 1 td 2 291393 AIR POLL1TAN'I. E.\IISSION NOTICE (APEN)& Application for Construction Permit—Reciprocating Internal Combustion Engine Permit .Number: 95OPWE038 Emission Source AIRS ID: 123 / 0099 / 108 Section 05 - Stash Information(Attach.t separate sheet with relevant information in the event of multiple stacks;provide datum&either Lat-Long or tJ I M) `�t.wh t),xlw�e J (JPerat,a" Stan.tl«ge �' .._. ..-. _..__ Jtra. l:.le,ru,rt Ift,�ht Ah,,.c How Ftatc ( Vele,ttty Mu,stwt: Ilonwnwl Datum UTM Ur Eiaatmg or I U'IM honiung or Method of C•Ut1,1 Li it ii r IAM:anull l ID No. (,t,.u;wl�t.scl fcnrp t F, ' t".1 (NA D27, D83, Lunt Longitude Latitude Data(e.g.sup.C,PS. fleet) ' (ACFM) tl(socl (1_or13) (ntct urdcgrets) Intatcrsurdegrx�) (,uobleLtnit) II ('121 1,091 20.5 toss .1... 4380 5,574 16 I WGS$4 13 1 1- 522,877 4,.x,151 ( PS w Uirceuuu ot‘t.el outlet tebrel.WW1 Q \sotcal ❑ 4'crucal with obstructing rwncat I ❑ 1loritontal ❑ Down ❑ ()tiler t DeNeriheI: I-.shaua(.4)\-11111.;S1t.tiw.1 slit:(cheek one): Q Circular! Inner Diameter Iinches( 12 . ❑ Other Length tutchcs) Width(inches) Section Ut) - Furl Consumption Information of Annual Fuel Use Rale w 1009„load Annual Fuel C'unsumptiun(gaUyr or MMSC'F Seasonal y Fuel Use( Fuel lylk r) Sulfur Fuel It g Value °'u l;sel _ (St'I' hr,gaLhr) Actual Reported for b Conlon Calendar Year Rcquc,te41 Permit Limit (Btu/lb,Btutgal,B (�tuWSCF) Dot-Feb Mar-May Jun-Aug Sep-Nos i Natural Gas 7.0 SIN1B fC/hr wt.) 64.2 M%ISCF/yr 1040 ll'Fl,/SCF 0 25 25 25 25 Is this engine eyu )ped w,ni au .\)r I net rail„c,nnn,t)er:' ® ❑ l es No Section 07- Emissions inventors. Information& Emission Control Information O i:uttsaiuu Iactur Du,,uottNur.attun atrach`'d Data),ear fur actual calendar fi r.emissions below&fuel use Abu%e(e.g.20417): r Control 1,.) 1)<xnptton Control ....�___.. Pullutar,[ Emi+siun Factor Actual Catania(Year Emissions' Requested Permitted Estimation Method ! Ftiiciutey Enus;ions or Uncommlled Connolly" !'rin:ar) Stzundary (�•„Reductiurtl Uncontrolled Basis Uncontrollyi ('untrulhxi Emission Factor Units 1 S W ITons+Yeur) ('I•ons/Y.:art (TonstYeurI (•Ionsi\ear) Source I f'\f,, Ibs/MnlBtu _ 5.886- IbsIMMBtu 5.88E-04 0.02 Y\1 5.88E-04U0.02 AP 4' R — -_ 0.02 0.02 AP-42 I — -- — 0 02 0.02 AP-42 1, -- 7.71 E-05 Ibs/AI!11Btu —., 0.003 0 13 ,hr-hr — 1 112.48 173 Mani. ').(X. \SCIt 0.5 g/hp-hr CO 76 413 \S('It �- 4 i3 Mar& 9.0 g/hp-hr — f,)rnulacr>dc77.87 NS('It Ibs/MMBtu — I 0.2 Mani. .AectaldeMdc \SCtt ...—.._.. 0.0205 0.00279 , 0.7 Acn)Icrt, \SCk ;� Iba1MM1lBtu 0.1 0.05 \))_�� 0.00263 — — Bcrucnc SSCtt —_ IbslM11M1IBIu 42 i 50 -- — 0.1 0.04 AP- 0.00158 Ibs/M1IMBtu — —___.-- 0.1_v Please use the 1PCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. 0.03 AP-42 y` Annul cnuasnm lceN w dl nc fused on actual cntnsnns rained hoc It lett blank,,urnual evussrtm let-,will be based tut requested e'rn,sswns. Section 08 Applicant Certification - 1 hereb\ certify that all information contained herein acid information submitted with this application is complete,true arid correct. If this is a registration for covcr g,:ends t general permit(,P(1_2. I further cenify that this source is and will be operated in full compliance with each condition of general ,/,',_.,..:,.;',/ ; ,_ h p rnut C,I U_. � w'eslc•bill e GPO'. Signature of Person Legally :�utltunzcd to Supply U eta (3xik Senior Env.Specialist Name of Legally Authorized Person(Please print) i isle .,, 1 Pale? of? / AIR POLLUTANT EMISSION NOTICE(APEN)&Application for Construction Permit—Reciprocating Internal Combustion Engin. Permit Numi,er: 95OPWE038 [Leave blank unless APCD has already assigned a permit#&AIRS IDJ Emission Source AIRS ID: 123 / 0099 / 110 Facility Equipment ID: P129(C-122) [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.) Section 01—Administrative Information Section 02—Requested Action(check applicable request boxes) Company Name: DCP Midstream,LP NAICS,or ❑ Request for NEW permit or newly reported emission source SIC Code: 1311 Source Name: Greeley Natural Gas Processing Plant 0 Request PORTABLE source permit Source Location: Section 25,T5N,R66W County: Weld ❑ Request MODIFICATION to existing permit(check each box below that applies) Elevation: 4,691 Feet O Change fuel or equipment ❑ Change company name Portable Source ❑ Change permit limit ❑ Transfer of ownership 0 Other Home Base: 0 Request to limit HAPs with a Federally enforceable limit on PTE Mailing Address: 370 17`'Sr.,Suite 2500 ZIP Code: 80202 E Request APEN update only(check the box below that applies) Denver,CO O Revision to actual calendar year emissions for emission inventory Person To Wesley Hill Phone Number: 303-6(F5-1716 ® Update 5-Year APEN term without change to permit limits or previously reported Contact: emissions E-mail Address: wdhill@dcpmidstream.com Fax Number: 303-605-1957 ❑ Notification of AOS permanent replacement Addl. Section 03—General Information Info.& Notes: For existing sources,operation began on: 10 / I / 1987 For new or reconstructed sources,the projected startup date is: / / Normal hours of source operation: 24 hours/day 7 days/week 52 weeks/year General description of equipment purpose: Natural Gas Compression Date the engine was ordered: Before 1987 Date engine construction commenced: Prior to 1987 Date the engine was relocated into Colorado: 1987 Date of any reconstruction/modification: Colorado Department of Public Health and Environment Will this equipment be operated in any NAAQS nonattainment area? Don't Air Pollution Control Division(APCDI (http://www.cdohe.state.co.us/an/attainmaintain.html) ® Yes 0 No 0 know This notice is valid for five(5)years. Submit a revised APF,N prior to Section 04—Engine Information expiration of five-year term, or when a significant change is made (increase production,new equipment,change in fuel type,etc). Engine date of manufacture: 12/8/81 Engine displacement: 12 L/cyl Mail this form along with a check for$152.90 to: Manufacturer: Waukesha Model: L7042 GSI Serial No.: 368993 Colorado Department of Public Health&Environment APCD-SS-B1 Engine function: O Primary and/or peaking power 0 Emergency back-up power 4300 Cherry Creek Drive South E Compression ❑ Pump jack 0 Water pump O Other: Denver,CO 80246-1530 For guidance on how to complete this APEN form: Manufacturer's maximum rated horsepower @ sea level: 1,100 BHP w 1,000 RPM Air Pollution Control Division: (303)692-3150 Manufacturer's maximum site rating: 1311Pd! RPM kW Small Business Assistance Program(SBAP): (303)692-3148 or (303)692-3175 Engine Brake Specific Fuel Consumption @ 100%Load: 8,490 Btu/HP-hr APEN forms:http://www.cdtthe.state.co.us/ap/downloadforms.html Cycle Type: ❑ 2-Stroke E 4-Stroke Combustion: O Lean Burn E Rich Bum Application status:http://www.cdphe.state.co.us/ao/ss/sspcpt.html Ignition Source: E Spark 0 Compression Aspiration: ❑ Natural E Turbocharged 0 Check box to request copy of draft permit prior to issuance. What is the maximum number of hours this engine is used for emergency back—up power? I Iours/year ❑ Check box to request copy of draft permit prior to public notice. FORM APCD-201 2 913 9 4 -.1 4. ,j Page 1 of 2 Greeley P129(C-I22)APEN Renewal-FormAPCD-201-RICEAPEN.doc AIR POLLUTANT EMISSION NOTICE(APEN)& Application for Construction Permit—Reciprocating Internal Combustion Engin_ Permit Number: 95OPWE038 Emission Source AIRS ID: 123 / 0099 / 110 Section 05—Stack Information(Attach a separate sheet with relevant information in the event of multiple stacks;provide datum&either Lat/Long or UTM) 1 Stack Discharge Operator Stack Base Horizontal Datum UTM UTM Fasting or UTM Northing or Method of Collection for Location height Above Flow Rate Velocity Moisture ( g P Stack Elevation Temp.(°F)(NAD27,NAD83, Zone Longitude Latitude Data c ma GPS, Ground Level (ACFM) (ft/sec) (%) . ID No. (feet) (feet) WGS84) (12 or 13) (meters or degrees) (meters or degrees) GoogleEarth) S129 4691 26.86 1055 114 ambien WGS84 13 522,877 4,468,151 GPS Direction of stack outlet(cheek one): El Vertical ❑ Vertical with obstructing raincap ❑ Horizontal 0 Down 0 Other(Describe): Exhaust Opening Shape&Size(check one): ® Circular:Inner Diameter(inches)= 12 0 Other:Length(inches)= Width(inches)— Section 06—Fuel Consumption Information Annual Fuel Consumption(gaUyr or MMSCF/yr) Sulfur Seasonal Fuel Use(%of Annual Fuel Use Rate @ 100%loadUse) Fuel Type Fuel Heating Value (SCF/hr,gal/hr) Actual Reported for Requested Permit Limit (Btu/lb,Btu/ Btu/SCF) Content Calendar Year $�. (%wt) Dec-Feb Mar-May Jun-Aug Sep-Nov Natural Gas 8,984 SCF/hr 78.7 MMscf/yr 1,040 Btu/sef 25 25 25 25 Is this engine equipped with an Air/Fuel ratio controller? ® Yes 0 No Section 07—Emissions Inventory Information&Emission Control Information ® Emission Factor Documentation attached Data year for actual calendar yr.emissions below&fuel use above(e.g.2007): l Control Device Description Control Emission Factor Actual Calendar Year Emissions' Requested Permitted Estimation Method Pollutant - Efficiency Emissions2 or Primary Secondary (%Reduction) Uncontrolled Controlled Uncontrolled Controlled Emission Factor ) Uncontrolled Basis Units (Tons/Year) (1'ons/Year) (Tons/Year) (Tons/Year) Source TSP PM 10 NSCR 5.88E-04 ib/mmbtu 0.02 Manuf.data PM25 NSCR 5.88E-04 Ib/mmbtu 0.02 Manuf.data SOX NSCR 7.71E-05 Ib/mmbtu 0.003 Manuf,data NOx NSCR 10 g/bhp-hr 106.22 26.55 Manuf.data VOC NSCR 0.5 g/bhp-hr 531 5.31 Manuf.data CO NSCR 10 g/bhp-hr 106.22 26.55 Manuf data Formaldehyde NSCR 76% 2.05E-02 lb/mmbtu 0.84 0.2 AP-42 Acetaldehyde NSCR 50% 2.79E-03 lb/mmbtu 0.114 0.06 AP-42 Acrolein NSCR 50% 2.63E-03 lb/mmbtu 0.11 0.054 AP-42 Benzene NSCR 50% 1.58E-03 Ib/mmbtu 0.065 0.032 AP-42 Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. 'Annual emission fees will be based on actual emissions reported here. If left blank,annual emission fees will be based on requested emissions. + 2If Requested Permitted Emissions is left blank,the APCD will calculate emissions based on the information supplied in sections 03-07. Section 08—A plicant Certification-I hereby certify that all information contained herein and information submitted with this application is complete,true and correct. �-- 2/ / `i / if Wesley Hill Sr.Environmental Specialist Signature of Person Lega y Authorized to Supply Data Date Name of Legally Authorized.PMAAtt st21(Nt se print) Title Page 2 of 2 Greeley PI29(C-122)ADEN Renewal-FortnAPCD-201-RICE..APEN.doe NON-CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) Permit Number: 95OPWE038 AIRS ID Number: 123/0099/110 Company Name: DCP Midstream, LP Plant Location: SW 1/4 Section 25, T5N, R66W County: Weld Zip Code: Person to Contact: Wesley Hill Phone Number: 303-605-1716 E-mail Address: wdhill(a}dcpmidstream.com Fax Number: 303-605-1957 Chemical Reporting Control Equipment/ Emission Factor Emission Uncontrolled Controlled Abstract Service Chemical Name BIN Reduction (%) (Include Units) Factor Source Emissions(lbs/year) Emissions(lbs/year) (CAS)Number E-4 106-99-0 1,3 Butadiene •A NSCR/50% I6.63mbtu AP-42 54.24 27.12 � I I - . Reporting Scenario (1, 2 or 3): 1 Calendar Year for which Actual Data Applies: 2010 Si f P..../,,,,r4.7.- L ,. .. 2.,. ? ,„, , , 'Z1 4 f/l/ ---gnature o rson Legally Authorized to Supply Data c D to Wesley Hill _ Senior Environmental Specialist Name of Person Legally Authorized to Supply Data (Please print) Title of Person Legally Authorized to Supply Data Form Revision Date: December 4, 2006 i AIR POLLUTANT EMISSION NOTICE (APEN)& Application for Construction Permit—General Pei mber: 95OPWE038 (Lease blank unless APCD has already assigned a permit 4&AIRS ID) Emission Source AIRS ID: 123 / 0099 / 113 Facility Equipment ID'. P-132 (Provide Facility Equipment ID to identify how this equipment is referenced within your organization.) Section 01 —Administrative Information Section 02—Requested Action(check applicable request boxes) Company Name DCP Midstream,LP NAICS,or ❑ Request for NEW permit or newly reported emission source SIC Code: 1311 Source Name Greeley Natural Gas Processing Plant ❑ Request PORTABLE source permit Source Location. SW 1i4 of Section 25,TSN,R66W County: Weld ❑ Request MODIFICATION to existing permit(check each box below that applies) Elevation: 4,691 Feet ❑ Change fuel or equipment ❑ Change company name Portable Source Home Base ❑ Change permit limit ❑ Transfer of ownership [7] 0ther ❑ Request to limit IIAPs with a Federally enforceable limit on PTE Mailing Address: 370 17t'Street.Suite 2500,Denver,CO ZIP Code: 80202 ® Request APES update only(check the box below that applies) — _ — ❑ Revision to actual calendar year emissions for emission inventory Person To Contact: Wesley Hill Phone Number. 303-605-1716 ® Update 5-Year APES term without change to permit limits or previously reported emissions E-mail Address: wdhill(adcpmidstream.com Fax Number: 303-605-1957 — Additional Info.& Notes: Section 03-General Information For existing sources,operation began on: 1987 For new or reconstructed sources,the projected startup date is: / Normal Hours of Source Operation: 24 hours/day 7 days,week 52 wccksiycar General description of equipment.and purpose: Hot Oil Heater Will this equipment be operated in any N.AAQS nonamainment area? Don't (Imp: ww_w.cdphc,tatc eo.us-ar,iitainm nntain htnl) ® Yes ❑ Ne ❑ know Colorado Department of Public Health and Environment Air Pollution Control Division(APCD) Section 04—Processinf l\lanufacturine Equipment Information& Material Use This notice is valid for five(5)years. Submit a revised APES prior to Description oicyuipment': expiration of five-year term, or when a significant change is made (increase production,new equipment,change in fuel type.etc). Manufacturer: Model No.: Serial No.: Mall this form along with a check for S152.90 to: "" �""" — Colorado Department of Public Health&Environment Its co,au��,a Actual Level Annual Requested Permitted Level- Design Process kale 1 APCD-SS-BI (S([For Data Y can xwafy tin irs} C sptix ify t xrizx lIour) 4300 Cherry Creek Drive South Denver,CO 80246-1530 Raw t ;\IaRYaah. _ + For guidance on how to complete this APEN firm: i Air Pollution Control Division: (303)692-3150 Small Business Assistance Program(SBAP I: (303)692-3148 or Finished ( . . (303)692-3175 Ptxaducts: APES forms:http w,uvy cctpbC.st its.co us/ap tftiesnivadforms htiii! t)tta.r I'is css Application status httt'iwwtv..tipbe tatc_cc,us. si sspcLt.hmn! It additional space is required,please attach a separate list of equipment,materials and throughputs. ❑ Check box to request copy of draft permit prior to issuance. 'Requested values will become permit limitations Requested level should consider process growth over the next Five years ❑ Check box to request copy of draft permit prior to public notice FORM APCD-200 1 Page I oft FormAPCD-200-General.APEN-Ver9-lo-20Of.C,reeleyP-I3?doc.doc 291396 n6'.'' r - Aar AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit—General Permit Number: 95OPWE038 Emission Source AIRS ID: 123 / 0099 / 113 Section 05—Emission Release Information(Attach a separate sheet with relevant information in the event of multiple releases;provide datum&either Lat/Long or UTM) ()Itrras+x 14-`'.. L''''t.u:c Itcti�ht ! I 11 airmail!Durum I tam UTM FaAlms or If FN.,Northing cn I Stack i 1-ict..,n=rs ti .e trsigittl (clip Ft rw kale 1 �'.Gwuy 1 Atw.turc iAAL?j7.!`AE�Ii lone Lixrttittikk LugodC Mcttrat ui C Ik3trxt t a t.w anon IUIS.r ite:Kr t._,.ttfexlt 1 t`Ft IACFM) 1 tti t i .r i WGSIIi) tt2nrlJ) frutatixtx Watrg, map.GMCairrgleE'anhl &VIVO.i inscwc Of S-132 4,601 i 41.29 675 5.472 11 limb11C:SS4 I.1 522,!(77 4,46&151 (.PS Direction of outlet(check one)• ® Vertical O Vertical with obstructing raincap O Horizontal O Down O Other(Describe): Exhaust Opening Shape&Sine(check one): ® Circular: Inner Diameter(inches)= 36 ❑ Other:Length(inches)-- Width(inches!= Section 06—Combustion Equipment& Fuel Consumption Information Company equipment identification No.: P-132 Manufacturer: Born Model: Serial No.: 2278 Fad Inv,: rik. t „,f•,iw l{eke»._ Actual Lelcl Annual Requested Permitted Lcseh Fuel Heating Value ttndreutc_ Percent by Wet st Se:a,ycwsal Pixel l'w:I"r.of Annual 1.;sic) lir Bill hi! tFssr Data 1''ceri lSpecify Units) l3m1b.Btu,gal.Bur Suitur Ash Doti-Fe+ Mar-Mart lull-Auk Sep-Not. r Natural Gas I 15.0 126_15 11Mtscf 1040 B'tl7cc( !. Neg. Neg. 25 25 I 25 25 I t — r__ 1 t 'Requested values will becourc perms limitations. Requested level should consider process growth over the next live years. Section 07—Emissions Inventory Information& Emission Control Information Attach any emission calculations and emission factor documentation to this APEN ticrm. O Emission Factor Ducumentatiuu attached Data year for actual calendar yr.emissions below Si.throughput above(e.g.2007): i Actual Calendar Year Requested Penmtted Estintatiotr i.ottt:ul I?v s ie 1Ellessriptii n Overall Control kmiaaor+Factor « Emission timi ,` k:naissatuast Method Pollutant --- T-- ('olkettsrr Eihecscy t.itnontnslied Uncontrolled Ccmtntlled Urncmttcsl1W Ctsruntilesl Emission Factor f i at..r-s ! Stionsidry E:Iticicricy 1°x Reduction) Units Basis (Tons/Year) tTcutc'"YearI (fnns'Yuv) (Tons Year) Source i IS)' • I'M 1 1 11.7 1b M1tscf 0.87 ! AP-4. i--- ,„),I'\t 1 .1_ !.3.7 .......__ IbiMMIxt0,87 d! 11,0 It MiMlsel 0.04 �4P-4_ _-.___...�.-.. .._ ._ - .. _,......-. ... .. .....� ......_. ...y _._....... .. .... ., \4.), 140.0 IbiMMsd t 8.8 4 1 AP-42 `six �.__. 2.8 !b/Si Nisei' 0.18 i AP t_' I 35.0 lb/MMsct 1 2.21 I AP-4 2 1'Irase use the 5PC U Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. '''''Annual emission fees will he based on actual emissions reported here. If left blank,annual emission fees will be based on requested emissions. '11 Requested Permitted Emissions is leti blank,the APCD will calculate emissions based on the information supplied in sections 03-07. Section 08—Applicant Certification-I hereby certify that all information contained herein and information submitted with this application is complete,true and correct. '1 / // Wes1e__Hil1 _ Senior Env.Specialist Signature;uE Ncrsem I cg,sllc ;\uttt.rnted to Supply Data Date Name of Legally Authorized Pei.urn(Plena:print) 1 tic: Page 2 of 2 FormAPCD-200-GeneralAPEN-Ver 4.10-2008-GreeleyP-132doc doe — Ayn, --V • AIR POLLUTANT EMISSION NOTICE(APEN)&Application for Construction Permit—Fugitive Component Leak Emissions Permit Number: 95OPWE038 [Leave blank unless APCD has airily assigned a pennit fl&AIRS ID) Emission Source AIRS ID: 123 / 0099 / 114 Facility Equipment ID: Fugitive Emissions(P-133) (Provide Facility Equipment ID to identify how this equipment is referenced within your organization.J Section 01—Administrative Information Section 02—Requested Action(Check applicable request boxes) Company Name: DCP Midstream,LP NAICS,or ❑ Request for NEW permit or newly reported emission source SIC Code: 1321 Request MODIFICATION to existing permit(check each box below that applies) Source Name: Greeley.Natural Gas Processing Plant O �I g Pp Source Location: SWSW Section 25,TSN,1166W County: Weld O Change process or equipment ❑ Change company name Elevation: 4,670 Feet ® Change permit limit O Transfer of ownership O Other Mailing Address: 370 17'h Street,Suite 2500 ZIP Code: 80202 O Request to limit HAPs with a Federally enforceable limit on PIE Denver,CO ❑ Request APEN update only(check the box below that applies) Person To Contact: Susan Rosenberg Phone Number: 303-605-1984 ❑ Revision to actual calendar year emissions for emission inventory Update 5-Year APEN term without change to permit limits or previously E-mail Address: serosenbery{e?depntidstream-com Fax Number: 303-605-1957 ❑ reported emissions Additional Combine fugitive emissions sources 114 and 117(P133 andP137)into one info.& source and Increase VOC permit limit. Section(13—General Information Notes: For existing sources,operation begat'on: / / 1986 For pew or reconstructed sources,the projected startup date is: - / / Normal Hours of Source Operation: 24 hours/day 7 days/week 52 wecks/year Brief description of equipment associated with these components: Natural Gas Processing Plant Will this equipment be operated in any NAAQS nonattainment area? ® Yes O No ❑ Don't I (htto:l/www.cdphe.state.cusiap`attaintnaintain.lrtml) know Section 04—Regulatory Information Colorado Department of Public Health and Environment Air Pollution Control Division(APCD) Is this equipment subject to NSPS 40 CFR Part 60,Subpart KKK? Ej Yes O No O Don't This notice is valid for five(5)years. Submit a revised APEN prior to know Durt,t expiration of five-year term, or when a significant change is made Is this equipment subject to NESHAP 40 CFR Part 63,Subpart HH? O Yes ® No ❑ (increase production,new equipment,change in fuel type,etc). know List any other NSPS or NESHAP Subpart that applies to this equipment: Mail this form along with a check(or$152.90 to: Colorado Department of Public Health&Enviro(unent APCU-SS Bf %0e Section 05—Stream Cuustituekits / 4300 Cherry Creek Drive South .1'4 Identify the VOC&HAP content of each applicable stream. Denver,CO 80246-1530 VOC Deanne Toluene Ethylbenzene Xylene a-Hexane For guidance on how to complete this APEN form: Stream (wt.Vs) (wt.%) (wt.%) (wt.%) (wt.%) (wt.%) Air Pollution Control Division: (303)692-3150 Gas 22.34 Small Business Assistance Program(SBAP): (303)692-3148 or (303)692-3175 Heavy Oil(or Heavy Liquid) - APEN fonns:http:liwww.cdphe.state.co.us/up/downloadforms,html Light Oil(or Light Liquid) 100 Application status:http://www.cdphe.state.c.o.usiapiss/sspept.html . Water/Oil - ❑ Submit a representative gas and liquid extended!analysis(including BTEX)to support emission calculations O Check box to request copy of draft permit prior to issuance. O Check box to request copy of draft permit prior to public notice. FORM APCD-203 291397 rice 1_ , Page 1 of 2 03_FonnAPt.'D-203-Fount veComponentt eaksAPEN-Vcr.9-10-2008.doc IIIIMIIMINNES • .4.IR POLLUTANT EMISSION NOTICE(APEN) &Application for Construction Permit—Fugitive Component Leak Emissions Permit Number: 95OPWE038 Emission Source AIRS ID: 123 / 0099 / 114 Section 04—Location Inforinatiolrt(Provide Datum and either Lat/Long or UTM) Section 07—Leak Detection&Repair(LDAR)&Control Inf9rtnation Horizontal Datum UTM UTM Casting or UTM Northing or Method of Collection for Check appropriate boxes to identify LDAR program conducted at this site: (NAD27,NAD83, Zone Longitude Latitude Location Data(e.g.map,GPS, 0 LDAR per NSPS KKK 0 No LDAR program W0584) (12 or 13) (meters or degrees) (metes or degnxsl Googleharih) 0 Other: Used LDAR Control percentages defined In permit. WCS 84 40.3643 -104.7305 CPS If LDAR per NSPS KKK with 10,000 ppmv leak definition: D Monthly monitoring.Control:88%gas valve,76%It.liq.valve,68%It.liq pump ❑ Quarterly monitoring.Control:70%gas valve,61%h.liq.valve,45%It.liq.pump Section 08—Emission Factor Information Identify the emission factor used to estimate emissions under"C.F.",along with the units relating to the emissiom factor(e.g.lb/fir/component). Check this box if you used fable 2-4 of U.S.EPA's 1995 Protocol for Equipu,enr Leak&Jivsws Etiolates to estimate emissions. You do not need to enter the emission factors below if checked. Service Equipment Type Cas Heavy Oil(or Heavy Liquid) Light Oil(or Light Liquid) Water/Oil Count' E.F. Units Count' E.F. Units Count' E.F. Units Counts E.F. Units Connectors 1470 0 4201 0 Flanges 70 0 3 0 Open-Ended Lines 0 0 0 0 Pump Seals 0 0 37 0 Valves 1053 0 2101 0 Other 86 0 46 0 1 'Count shell be the actual or estimated number ofcompouen is in each type of service used to cakulate the"Actual Calendar Year t:.uisswtu"below. O Estimat.d Count O Actual Count conducted on the following date: Section 09—Emissions Inventory Information&Emission Control Information ❑ Emission Factor Documentation attached Data year for actual calendar year emissions blow(e.g.2007): I Requested Permitted Estimation Method Control Device Description Control Emission Factor Actual Calendar Year Emissions' Emissions' or Pollutant Efficiency Uncontrolled Controlled Uncontrolled Controlled Emission Factor Primary Secondary (%Reduction) Uncontrolled Basis Units (Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Source VOC 79.92 24.13 EPA Benzene To/luene bertzenc Identify in Section 07 Identify in Section 08 Cth Y , Xylmie n-Hexane r _ Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. 'Annual emnission fees will be based on actual emtissiontia reported here. If left blank,annual emission fees will be based on requested emissions. You may request pc'nnitted emissions in excess of actual emissions to account fur eomponent count and gas composition variability.If Requested Permitted Emissions is lett blank,emissions will be based on info.in See.03 09. Section 10—Aoolicau Certification-1 hereby certify that all information contained herein and information submitted with this application is complete,true and correct. .. . -- Li Q 3/0 y Susan Rosenberg gale t ^� Senior Env.Specialist Signatur of Person Legally Authorized to Supply Data Date f Name of Legally Authorized Person(Please print) Title Page 2 of 2 03 FonnAPCD-203-FugitiveCompouentLwksAPEN-Ver.9-10-200k.doc 4 AIR POLLUTANT EMISSION NOTICE (APEN)&Application for Construction Permit—General Permit.•:umber: 95OPWE038 [Leave blank unless APCD has already assigned a permit N&AIRS ID) Emission Source AIRS ID: 123 / 0099 / 115 Facie i.-: Equipment ID: P135 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 01 —Administrative Information Section 02—Requested Action(check applicable request boxes) . Company Name: DCP Midstream,LP NAICS,or ❑ Request for NEW permit or newly reported emission source SIC Code 1321 Source Name: Greeley Natural Gas Processing Plant O Request PORTABLE source permit Source l.ocation: Section 25,TSN,R66W County: Weld O Request MODIFICATION to existing permit(check each box below that applies) Elevation: 4691 Feet O Change fuel or equipment O Change company name Portable Source O Change permit limit O Transfer of ownership O Other Home Base: O Request to limit HAPs with a Federally enforceable limit on PTE Mailing Address: 370 17th Street,Suite 2500 ZIP Code: 80202 ® Request APEN update only(check the box below that applies) Denver,CO O Revision to actual calendar year emissions for emission inventory Person To Contact Wesley Hill Phone Number: 303-605-1716 ® Update 5-Year APEN term without change to permit limits or previously reported emissions E-mail Address: wdhillwdcpmidstream.com Fax Number: 303-605-1957 Additional Info.& Notes: Section 03—General Information For existing sources,operation began on: 01 / 01 1 1990 For new or reconstructed sources,the projected startup date is: / / Normal Flours of Source Operation: 24 hours/day 7 days/week 52 weeks/year General description of equipment and purpose: Pressurized Product Truck Loadout Rack Will this equipment be operated in any NAAQS nonattainment area? Don't (http://www.cdphe.state.co.usiapiattainmaintain.htinl) ® Yes O No O know Colorado Department of Public Health and Environment Air Pollution Control Division(APCD) Section 04—Processin /Manufacturing Equipment Information&Material Use This notice is valid for five(5)years. Submit a revised APEN prior to Description of equipment': expiration of five-year term, or when a significant change is made (increase production,new equipment,change in fuel type,etc). Manufacturer: Model No.: Serial No.: Mail this form along with a check for 5152.90 taaa' Actual Level Annual Requested Permitted Lever Design Process Rate Colorado Department of Public Health&Environment Description For Data Year) (Specify Units) (Specify Units/Hour) APCD-SS-BI { (`Peci) p` 4300 Cherry Creek Drive South NGLs 560 MMgal/yr Denver,CO 80246-1530 Raw For guidance on how to complete this APEN form: Materials: , Air Pollution Control Division: (303)692-3150 Small Business Assistance Program(SI3AP): (303)692-3148 or Finished (303)692.3175 Products: APEN forms:http://www.cdphe.state.co.us/ap/downloadforms html Application status:http://www.cdphe.state.co.us/ap/ss/sspcpt.html Other Process: 'If additional space is required,please attach a separate list of equipment,materials and throughputs. O Check box to request copy of draft permit prior to issuance. 'Requested values will become permit limitations. Requested level should consider process growth over the next five years ❑ Check box to request copy of draft permit prior to public notice. FORM APCD-200 291398 Page 1 oft Greeley P135FormAPCD-20U-GeneralAPEN-Vcr,9-IU-30U8.doc IP AIR POLLUTANT EMISSION NOTICE(APEN)& Application for Construction Permit—General Ali Permit Number: 95OPWE038 Emission Source AIRS ID: 123 / 0099 t 115 Section 05—Emission Release 1 nformation(Attach a separate sheet with relevant information in the event of multiple releases;provide datum&either Lat/Long or UTM) Operator Base Discharge Height Temp. Flow Rate Velocity Moisture Horizontal Datum UTM I UTM Fasting or UTM Northing or Stack Elevation Above Ground (NAD27,NAD83, Zone I Longitude ! Latitude Method of Collection for Location ID No. (feet) Level(Feet) ('F) i (ACFbt) (H sec) (%) WGS84) (12 or 13) (meters or degrees) ! (meters or degrees) Data(e-g map.GPS,GoogleEarth) WGS 84 13 522,877 4,468,151 CPS _ Direction of outlet(check one): ❑ Vertical ❑ Vertical with obstructing raincap ❑ Horizontal ❑ Down ❑ Other(Describe): Exhaust Opening Shape&Size(check one): ❑ Circular:Inner Diameter(inches)= ❑ Other:Length(inches)= Width(inches)_ Section 06—Combustion Equipment& Fuel Consumption Information Company equipment Identification No.: Manufacturer: Model: Serial No.: — Fuel Type Design Input Rate Actual Level Annual Requested Permitted Level Fuel Heating Value(Indicate: Percent by Weight Seasonal Fuel Use 5%of Annual Use) (106 Btu/ir) (For Data Year) (Specit}Units) Btullb.Btulgal,Btu/SCF) Sulfur Ash Dec-Feb Mar-May Jun-Aug Sep-Nov 'Requested values will become permit hmintions. Requested level should annsider process growth over the next live years Section 07—Emissions Inventory Information& Emission Control Information Attach any emission calculations and emission factor documentation to this APEN form. ❑ Emission Factor Documentation attached Data year for actual calendar yr.emissions below&throughput above(e.g.2007): I Control Device Description Overall Control Emission Factor Actual Calendar Year Requested Permitted Estimation Pollutant Collection Efficiency Emissions Emissions4 Method or Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Emission Factor Primary Secondary Efficiency (%Reduction) Basis Units (Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Source TSP PM10 PM2 s SOX NOx VOC 43.15 AP-42 CO Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. i Annual emission fees will be based on actual emissions reported here. If left blank,annual emission fees will be based m requested emissions. 'if Requested Permitted Emissions is left blank,the APCD will calculate emissims based on the information supplied in sections 03-07. Section 08—Applicant Certification-I hereby certify that all information contained herein and information submitted*this application is complete,true and correct. l, /1�ie----1�? f//?0/e, cf Wesley Hill --(AASr. Environmental Specialist Signature of Pcrs Legally Authorized to Supply Data Date Name of Legally Authorized Person(Please print) Title Page 2 of 2 Greeley PI35 FomiAPCD-200-GeneralAPEN-Ver.9-10-2008 doc AIR POLLUTANT EMISSION NOTICE(APEN)& Application for Construction Permit—General Permitftumber: 95OPWE038 (Leave blank unless APCD has already assigned a permit#&AIRS ID] Emission Source AIRS ID: 123 / 0099 / 120 Faciiiii4Equipment ID: P-139 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01—Administrative Information Section 02—Requested Action(check applicable request boxes) Company Name: DCP Midstream,LP NAICS,ory permit newly reported emission source Source Name: Greeley Natural Gas Processing Plant SIC Code: 1321 O Request for NEW or ❑ Request PORTABLE source permit Source Location: SW Sec 25,T5N,R66W County: Weld ® Request MODIFICATION to existing permit(check each box below that applies) Elevation: 4,691 Feet O Change fuel or equipment O Change company name Portable Source permit limit Home Base: 0 Change O Transfer of ownership O Other ❑ Request to limit HAPs with a Federally enforceable limit on PTE Mailing Address: 370 17's Street, Suite 2500 ZIP Code: 80202 O Request APEN update only(check the box below that applies) ❑ Revision to actual calendar year emissions for emission inventory Person To Contact: Susan Rosenberg Phone Number: 303-605-1984 O Update 5-Year APEN term without change to permit limits or previously reported emissions E-mail Address: serosenberg(u dcpmldstream.com Fax Number: 303-605-1957 Additional Info.& Update Heater Burner Rating Notes: Section 03—General Information For existing sources,operation began on: 12 1 1 / 2008 For new or reconstructed sources,the projected startup date is: / / Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year General description of equipment and purpose: Hot Oil Heater Will this equipment be operated in any NAAQS nonattainment area? Don't (http://www.cdahe.state.co.us/an!attaimnaintain.html) 0 Yes O No O know Colorado Department of Public Health and Environment Air Pollution Control Division(APCD) Section 04—Processine/Manufacturine Equipment Information&Material Use This notice is valid for five(5)years. Submit a revised APEN prior to Description of equipment': expiration of five-year term, or when a significant change is made (increase production,new equipment,change in fuel type,etc). Manufacturer. Model No.: Serial No.: Mail this form along with a check for S152.90 to: Actual Level Annual Rcxtuested Permitted Lcveh Design Process Rate Colorado Department of Public Health&Environment Description (For Data Year) APCD-SS-B1 (Specify Units) (Specify Units/Hour) , 4300 Cherry Creek Drive South s<"4 Raw Denver,CO 80246-1530 4 f Materials: For guidance on how to complete this APEN form: %.f�,� Air Pollution Control Division: (303)692-3150 Small Business Assistance Program(SBAP): (303)692-3148 or Finished ' (303)692-3175 Products: APEN forms:http://www.cdphe.state.co.us/ap/downloadforms.html Other Process: Application status:http://www.cdphe.state.co.us/ap/ss/sspcpt.html elf additional space is required,please attach a separate list of equipment,materials and throughputs. O Check box to request copy of draft permit prior to issuance. IRequestaf values will become permit limitations. Requested level should consider process growth over the next live years. O Check box to request copy of draft permit prior to public notice. FORM APCD-200 Page 1 of 2 FonnAPCD-200-GeneralAPEN-Ver.9-10-2008.doc 291399 AIR POLLUTANT EMISSION NOTICE (APEN)& Application for Construction Permit—General Permit Number: 95OPWE038 Emission Source AIRS ID: 123 / 0099 / 120 opp Section 05—Emission Release Information(Attach a separate sheet with relevant information in the event of multiple releases;provide datum&either Lat/Long or UTM) Operator Base Discharge Height Temp, Flow Rate Velocity Moisture Horizontal Datum UTM UTM Fasting or UTM Northing or Method of Collection for Location Stack Elevation Above Ground (NAD27,NAD83, Zone Longitude Latitude 1D No. (feet) Level(For[) (`F) (ACFM) (ft/sec) (%) WGS84) (12 or 13 (meters or dr rrxe) (meters or degrees) Data(e g.map.GPS,GoogleEarth) g P-139 WGS 84 13 522,886.35 4,468,218 GPS Direction of outlet(cheek one): 0 Vertical O Vertical with obstructing raincap O Horizontal O Down O Other(Describe): Exhaust Opening Shape&Size(check one): 0 Circular:Inner Diameter(inches)= O Other:Length(inches)= Width(inches)_ Section 06—Combustion Equipment&Fuel Consumption Information Company equipment Identification No.: P-139 Manufacturer: G.C.Broach Model: Hot Oil Heater Serial No.: Fuel T Design Input Rate Actual Level Annual Requested Permitted Level2 Fuel Heating Value(Indicate: Percent by Weight Seasonal Fuel Use 5%of Annual Use) YF (10°Btu/hr) (For Data Year) (Specify Units) Bm,'lb,Btw'gat,Btu/SCF) Sulfur Ash Dec-Feb Mar-May Jun-Aug Sep-Nov Natural Gas 35.1 MMBTU/hr 292.83 MMSCF/yr 1,050 BTU/SCF 2Requested values will become permit limitations. Requested level should consider process growth over the next five years. • Section 07—Emissions Inventory Information&Emission Control Information Attach any emission calculations and emission factor documentation to this APEN form. ❑ Emission Factor Documentation attached Data year for actual calendar yr.emissions below&throughput above(e.g.2007): I Control Device Description Overall Control Emission Factor Actual Calendar Year Requested Permitted Estimation Pollutant Collection Efficiency Emissions Emissions Method or Primary Secondary Efficiency (6/0 Reduction) Uncontrolled Units Uncontrolled Controlled Uncontrolled Controlled Emission Factor Basis (Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Source TSP PM 10 PM25 SOx NOx 14.64 AP-42 VOC 0.81 AP-42 CO 12.30 AP-42 Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. 'Annual emission fees will be based on actual emissions reported here. If left blank,annual emission fees will be based on requested emissions. 'If Requested Permitted Emissions is left blank,the APCD will calculate emissions based on the information supplied in sections 03-07. Section 08—Applicant Certification-I hereby certify that all information contained herein and information submitted with this application is complete,true and correct. 121 3 I Cnei Susan Rosenberg Senior Env.Specialist Signature Person n Legally Au rized to Supply Data Date Name of Legally Authorized Pers Please print) Title g Y A7) Page 2 of 2 `!40 FormAPCD-200-GeneralAPFN-Ver.9-10-200t.doc AIR POLLUTANT EMISSION NOTICE(APEN)& Application for Construction Permit—Glycol Dehydration Unit Permi;4amber: 95OPWE038 [Leave blank unless APCD has already assigned a permit#&AIRS ID] Emission Source AIRS ID: 123 / 0099 / 121 Facility Equipment ID: P-130 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01—Administrative Information Section 02—Rgouested Action(Check applicable request boxes) Company Name: DCP Midstream,LP NAICS,orpermit newly reported emission source 1321 O Request for NEW or Source Name: Greeley Natural Gas Processing Plant SIC Code: ® Request MODIFICATION to existing permit(check each box below that applies) Source i oration: SW Sec 25,TSN,R66W County: Weld •❑ Change prows or equipment O Change company name Elevation: 4,691 Feet ® Change permit limit O . Transfer of ownership O Other Mailing Address: 370 17t'St.Suite 2500 ZIP Code: 80202 O Request to limit HAPs with a Federally enforceable limit on PTE O Request APEN update only(check the box below that applies) Person To Contact: Susan Rosenberg Phone Number: 303-605-1984 O Revision to actual calendar ymir emissions for emission inventory E-mail Address: serosenberg(;depmidstream.com Fax Number: 303-605-1957 ❑ Update 5-Year APEN term without change to permit limits or previously reported emissions Addl.Info Section 03—General Information &Notes: For existing sources,operation began on: I / 1983 For new or reconstructed sources,the projected startup date is: / / Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year General description of equipment and purpose: Natural Gas Hydration Inhibition System using Ethylene Glycol ► is this unit subject to the 90%control requirement of Colorado Regulation No.7,XVII.D(total uncontrolled actual VOC emissions front all dehydration units at this stationary source,including APEN Exempt units,> 15 tons/yr)? ❑ Yes ® No O Don't know ► Will this equipment be operated in any NAAQS nonattainment area? (http://www.cdphe.state.co.us/ap/attainmaintain.html) 0 Yes O No ❑ Don't know ► Is this unit located at a stationary source that is considered a Major Source of Hazardous Air Pollutant(HAP)emissions? O Yes 0 No O Don't know Section 04—Dehydration Unit Equipment Information Colorado Department of Public Health and Environment Manufacturer. Model: Serial No.: Air Pollution Control Division(APCDI Reboiler Rating: 4.6 MMBtu/hr This notice is valid for five(5)years. Submit a revised APEN prior to Glycol Used: O TriEthylene Glycol(TEG) ® Ethylene Glycol(EG) O DiEthylene Glycol(DEG) expiration of five-year term, or when a significant change is made Glycol Pump Drive: ® Electric O Gas If gas,injection pump ratio: acfm/gpm (increase production,new equipment,change in fuel type,etc). Pump Make&Model: EMC tri plex #of Pumps: 1 Mall this form along with a check for$152.90 to: Glycol recirculation rate(gal/min): Max: 28 Requcstedt: 6 Lean glycol water content: 20 wt.% Colorado Department of Public Health&Environment Dehy.Gas Throughput: Design Capacity: 33.0 MMSCF/day Requested': 33.0 MMSCF/yr. 4300 Che-SSrrylCreek Drive South Calendar year actual: MMSCF/yr. Denver,CO 80246-1530 Inlet Gas: Pressure: 800 psig Temperature: 85 °F For guidance on how to complete this APEN form: Water Content: Wet Gas: lb/MMscf ® Saturated Dry Gas: lb/MMscf Air Pollution Control Division: (303)692-3150 Flash Tank: Pressure: psig Temperature: °F ® None Small Business Assistance Program(SBAP): (303)692-3148 or Cold Separator: Pressure. 700 psig Temperature: -40 °F O None (303)692-3175 Stripping Gas: ® None O Use flash gas O dryUse gas: scfmAPEN forms:http://www.cdphe.state.co.us/ap/downloadforms.html O Use N2: scfrn `Requested values will become permit limitations. Application status:Itttp://www.cdphe.state.co.us/ap/ss/sspcpt.html Additional O Attach a process flow diagram information ® Attach GRl-GLYCalc 4.0 Input Report&Aggregate Report(or equivalent simulation report/test results) O Check box to request copy of draft permit prior to issuance. Required: Attach the extended gas analysis(including BTEX&n-Hexane,temperature&pressure) O Check box to request copy of draft permit prior to public notice. FORM APCD-2U2 Page 1 of 2 2 OI t 3 95 FonnAPCD-202-GlycolDehydratorAPEN-Ver.9-I0-2008.doc 9 j ,) t )y tea AIR POLLUTANT EMISSION NOTICE(APEN)& Application for Construction Permit—Glycol Dehydration Unit I' Permit Number: 95OPWE038 Emission Source AIRS H): 123 / 0099 / 121 ,,gjj n 05—Stack Information(Combustion stacks must be listed here) Section 06—Stack(Source,if no combustion)Location(Datum&either Lai/Long or UTM) Operator Stack Base Stack Discharge t Horizontal Datum UTM UTM Easting or UTM Northing or Method of Collection for height Above Temp. Flow Rate Velocity Moisture Stack Elevation (NAD27,NAD83, Zone Longitude Latitude Location Data(e.g.map, Ground Level (°F) (ACFM) (insect (%) ID No. (feet) (feet) WGS84) (12 or 13) (meters or degrees) (meters or degrees) GPS,GoogleEarth) P-130 4,691 WGS84 13 522,886.35 4,468,218 GPS Direction of stack outlet(check one): ® Vertical 0 Vertical with obstructing raincap 0 Horizontal 0 Down 0 Other(Describe): Exhaust Opening Shape&Size(check one): 0 Circular:Inner Diameter(inches)= 0 Other: Length(inches)= Width(inches)= Section 07—Control Device Information (Indicate if a control device controls the flash tank and/or regenerator emissions) ❑ Condenser used for control of: 0 Combustion Device used for control of: Rating: MMBtu/hr Type: Make/Model: Type: Make/Model/Serial#: Temperature(°F): Maximum: Average: VOC&HAP Control Efficiency: Requested: % Manufacturer Guaranteed: % Requested VOC&HAP Control Efficiency: % Minimum temp.to achieve requested control: °F Waste gas heat content: Btu/sef ❑ VRU used for control of: Constant pilot light? 0 Yes 0 No Pilot burner rating: MMBtu/hr Size: Make/Model: 0 Closed loop system used for control of: Requested VOC&HAP Control Efficiency: % Description: Annual time that VRU is bypassed(emissions ventexl): % 0 Describe Any Other: Section 08—Emissions Inventory Information&Emission Control Information a Emission Factor Documentation attached Data year for actual calendar yr.emissions below&gas throughput above(e.g.2007): t Control Device Description Control Emission Factor Actual Calendar Year Emissions'' Requested Permitted Estimation Method Pollutant Efficiency Emissions or Primary Secondary (%Reduction) Uncontrolled Basis Units Uncontrolled Controlled Uncontrolled Controlled Emission Factor j (Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Source NOx VOC 6.5 Gly Cale CO Benzene Identify in Section 07 0.7611 Gly Cale Toluene 0.0487 Gly Cale Ethylbenzene 0.0068 Gly Calc Xylene 0.0867 Gly Calc - n-Hexane 0.0410 Gly Calc Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. 'Annual emission fees will be based on actual emissions reported here. If left blank,annual emission fees will be based on requested emissions. I If Requested Permitted Emissions is left blank,the APCD will calculate emissions based on the information supplied in sections 03-08. Section 09 Anplica t Certification-I hereby certify that all information contained herein and information submitted with this application is complete,true and correct. f 1........--., I I-4/(ag Susan Rosenberg Senior Env.Specialist Signature of Person Legally Autho ' to Supply Data Date Name of Legally Authorized Person(Please print) Title Page 2 of 2 to? 1 _l d$APCD-202-GIycolDehydratorAPEN-Ver.9-I0-2008.doc DCP Midstream 370 17th St.,Suite 2500 _r Denver,CO 80202 am, t303)605-2039 Mi dstream,e www.dcpmidstream.com April 28, 2016 UPS Tracking No. 1ZF469150294159750 Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 RE: DCP Midstream, LP Greeley Natural Gas Processing Plant Title V Operating Permit Number 95OPWE038 AIRS ID 123/0099/111 and 122 Title V Modification Application DCP Midstream, LP (DCP) is applying for an operating permit modification subsequent to the construction permit submittal to Colorado Department of Public Health and Environment (CDPHE) on May 1, 2015 for the gas plant known as Greeley Natural Gas Processing Plant in Weld County, Colorado to align with Regulation Number 7 requirements: • Modification to the glycol dehydrator (P-130, AIRS ID Ill) to add an enclosed combustor device (ECD) with 5% annual downtime to control overhead stream emissions (pending approval of construction permit) and subsequent emission calculations. a Modification to P-130 to add a flash tank equipped with a vapor recovery unit (VRU) to route flash tank emissions to the inlet. During VRU downtime, 5% of the time annually, emissions are routed to the ECD (pending approval of construction permit). Subsequent emission calculations are included with the modification. • Inclusion of the plant flare(AIRS ID 122) in the Operating Permit. A Title V permit modification application has been provided with the following attachments: • Attachment A— Process Description, Flow Diagram and Plot Plan • Attachment B — Supporting Documentation • Attachment C — Most Recent APENs (Note that the previously submitted AIRS ID for P-130 was incorrect with 121 instead of 111) • Attachment D— Filing Fees for APEN Renewal Submittals • Attachment E — APEN Renewal Submittals for C124, C116, C117, C118, C119, C120, C122 • Attachment F—Operating Permit Application Forms Page 1 1 Additionally, DCP would like to make a change to the Responsible Official at this facility to: William L. Johnson, Vice President of Operations. This is represented on the forms accompanying this modification application. We appreciate your review of this application and issuance of a modified operating permit inclusive of the above changes. If you have any questions I can be reached by phone at (303) - 605-2039 or via e-mail at rshankaran a dcpmidstream.com. Sincerely, DCP Midstream, LP Roshini Shankaran Environmental Engineer Attachments Page 2 Appendix A — Process Description, Flow Diagram and Plot Plan Process Description Greeley Natural Gas Processing Plant • Greeley is a gas processing plant designed to extract natural gas liquids from field produced natural gas and recompress the processed gas prior to transmission to the sales pipeline. Field gas is first piped to a separator where liquids formed during transport to the plant are separated from the gas stream. The gas stream discharged from the separator is processed through a glycol dehydrator, where moisture contained in the gas stream is absorbed by ethylene glycol. The moisture laden glycol discharged from the contactor is regenerated in a reboiler. The glycol solution is then re-circulated to the contactor. Emissions from the dehydrator still vent are routed to an enclosed combustor. Emissions from the dehydrator flash tank are routed to a vapor recovery unit (VRU) and routed back to plant inlet. During periods of VRU downtime, emissions will be routed to the enclosed combustor. After the moisture in the gas has been removed by the contactor the gas stream is piped to the processing plant where it is chilled by a refrigeration system coupled with the Joule-Thompson process to create a natural gas liquid (NGL) product and a residue gas stream. A fractionation assembly separates the NGL product into ethane, prc pane, butane, isopentane and natural gas streams that are stored in separate tanks and transported offsite by truck. The residue gas is recompressed by natural gas-fired internal combustion engines powered compressors and then routed to the sales gas pipeline. The facility operation also requires two natural gas-fired heaters, a pressurized truck loadout rack for condensate, a pressurized NGL truck loadout rack, and various pressurized storage tanks. The facility flare serves as a backup for maintenance, malfunction, startup, and shut down emissions. Greeley Gas Plant Process Flow Diagram Flash Backup Plant Flare for to ECD Maintenance and ' I Still Vent Emissions Malfunctions I Flash ENCLOSED __ J VRU FLASH Emissions D- COMBUSTOR C-124 t- TANK Recycled to Inlet INLET GAS Rich EG ETHYLENE INLET GAS EP. GLYCOL "-L-----Ei. SCRUBBER HEATER Lean EG ETHYLENE < RESIDUE RESIDUE GAS TO SALES Gas Liquids GLYCOL $' COMPRESSION A DEHYDRATOR ► A V INLET r 1T SKID COMPRESSION NGL TO FRACTIONATION ASSEMBLY I RACTIONATION NGL PRESSURIZED D ASSEMBLY NGL LOADING PRESSURIZED CONDENSATE la PRESSURIZED TANK LOADING Di;::ratan Crnta+ner I _---_-- • Vro.anWc�:am.e.vConb+.nna�::+ ( r lV,-- --—_ionwrr Cants. Unit ContentsField Nome D.00 Omn Capacity (001 or MN) Field Name Oea,Tbom i Cupaex+ (Tier re 604) I M-g NGL 30,000 col Product.C2.03,Gtr M-00 101. 30,000 gal Froctlarwtbn C3.00 M-tl SOL 30,000 gal Syetem Neater-Meem-600 I c5 901 M-I2- _._.. f:OL 20,000 40! (WtiPt.) 31-11 NCL 30,000 gal Refrigerat..+JT 5yalcn' Propane,Luba 06 I 15(10 gar ,LE ENO 38-14 Condensate 30,000 gal Wet Sand* Cm2encM, 2011 gale r ._ suer.�,,pr,epyn, N M-13 NGL. 30,000 got Ily+nxn+Conm 1N'.-16 NGL t 30,000 gal 61nNccler Slew System G2 <5 Hal Tit•-rtNOL 30,000 r48l Nei Cl 5yetem lherm 60 allne 0 <5 9 x I rra 17-1100 ix NGL 30,000 gal GI,.MG)Oelrydrgiiont CO i5 ga. a,,.a 31-41 NCL mowaol C5wl ass)s„, CI end Nymacorbons „ .41I .m. W E M-01-0b Condensate 30,000 got CoMa+satsy Labe at 5-laaa .----_Slap al —aa WA IMet Saparater NGL C1 93t- —,.I i sanura.,... 54 5-1090 5100 a 60 l bN Flare System Condensate, _---- 1N-10)2 $fa mevat� 303 WN ,� 5 M-1021 0 300 I gal <PCCry,rv01N:.....=c,r.o:n.n+.at:n 01/M-32 Slub.Oil 165 gal Gen ar 5n.rndary Cc:ea+•mn+a , n aawvM aomar w aP) M-M u�w 1 4005 got Tul_. v 38-34 i y_ eax M-3x Hot Oile 00 got Fl18 Name C+Plop,,. Capo00 (9a1 P WO M-33 Nd Oil 50 bd TR-0 Propane 0,000 USm C0. + U1M ql 32 m!-- M-2 Procne ..0,000 ga- 1 415!31 OA. 2 Oa Oil 55 gal IF-3 Popo. 30000 ag,� t V-6 Par CI Sumo. 55 SP M-t PrapdM 30,0[3 go r 5-108)1 Oily woe'.aeats 60 the I'. M-5 Propane 30,000 2, r 5-106]3 t py 40,0,1ter 80 bbl M-6 Propane 30,000, 90 1 5-1086 5040 al 60 901 10-7 Propane 30po0 ga I 5-1019 Sap Ur SO W 11, Prep.,-6 Prep 30,000 go 3.911,1 It lbena-6W 65 I IN-21 N6pmtane 29,835 g . 11,E104ER61 2 R•erm-4001 15 I -22 5utam ad 30,000 ' NOT OIL S1SiENm (13)55-gal 8198615 Englm 000 351) 0o M .N I -23 ...me :9,635 got , 610310E ENGINE OIL LANK Errine 0,1 lit--�gni r M-ts xutaro 29,835 gal3006V 5-1091 Oily Paler 40 l on M-25 Outana 30,000 gar - cam r Tr-30 MNegnal 100 bb © r.,car tr-S f Mo01 2,600 ad e r er --.. 18-35 EltrM a Gycm 2.000 go 3: a�ewu a r mar, 9,-37 TEl SCO ga nnO 0,,,,,,,... Unit Land al 01! or„ fl greed of Tilton Ss as �` en nos /J/ held Nam. 0..an0twn Capon r•�1 or 0400) User al Flt Drum O Id ed pn Mere 555 go ,,... «.. - a, c-122 f,,.rere rube Gr ®� C-024(,or.y+,e, r Labe Oil I �� -''�� 0-123 Ines Orb.Cr 100 C-152{Cemprea.ar' Luba ON 30 00 ' »• H4_"� � c-152 dra)♦ tub.CI 100 !� c— (ca,+,Preewr Loos CO So va _I n,Ira I . C-122,E9i4es Lub Cl 150 _gal_ 0-116{Compressor) Labe Cl! `30 gall I ,py 0-121 w 0i 150 •1 I 06.SCR \ \ \ uurel nnumlx INS 1 W 0i 150 �:� -,INLET SCRUBBER C-116 •Ines C. Cr 150 s i1 I - f-Ir9 w CS 150 e"r urn, y -116 Ines 'uba Ci 150 I = m 12. _ C-II)r bre Luba C2 t$0 .�t M r I I �.a Il RF RIGERAIµON JT SYSiEAI "_ARp^c min �� / Ili �...... _ _- E! , -. li d — l,r� _--_________—. �• R7ACTIUNA710N SYSTEM hi_f ..� E. 1��B�� ! _--_..-___-.POe5 ulcer'__--_ ._.f 001_ nt e a� `ne ,, al I. �.:-� jl 3 Io—.r' wW"^'+w ----- Fne%eson•rf" -- r`92.� d;i t I I IP�liEMI-!P.r%e g ee ` v F L —U .aWCI' u j r _ 1 URE + a � sys id oaul�c 61906 �, � �.�� (I t a 's:�� a:Z.' 70611410 o cL7cc - ❑l-1 33 �1' "� �131� YaEcuuR s�eie 55700 "°' Q l ! �_ l 1 0�0ri l t\' /l `p (6 Cam . LI.',am il II ,r-r—r—y— -1, ,.., fitii ..-^ '`'""a.>\ ) 1 1 1 L0N)WG,IAr r 1 °L6,. .r mm. I w`gall ]}Jere me appro:'irnofely 20 SSc gal dynes --�_ 690 veal ar 'fe l the time f fha,,,,sit; �. 015161, but the onther of Mrms mgy wry ---�.� hum month Yu month. SPCC PLOT PLAN pry 0605 60061)000 or j oa62 MGR. Ye 000 rums 6058000 O1 CIIN'O ENG!, ',V. GREELEY GAS PLANT 1 5-29-0x#0166,0 0 OFFS 9QT(31(z-3-os) J.R.E.I R.P.M. WELD COUNTY GATHERING SYSTEM 1 5-29-0] REN9CN5 PEP,RP.fI PEW 9tEYCN JAL�RP M. 2 8-22-12 1901191935 PER:02.CF.riELO 940 00 119.E I Y.C.F. /.st S... �J� Weld Courtly h 3 9-15 REM6Qi5 PER:Y.CF.811#38ET61 319E I C.EC Mid ea . COLORADO \data\Eh5Orawings\Mapping\Colorado\Wald\GTeeo y300C Appendix B — Supporting Documentation Natural Gas Dehydration Greeley Natural Gas Processing Plant DCP Midstream, LP AIRS ID 123/0099 Source ID 121 Stripping Gas? N Y/N Description 33 MMSCFD Dehy What is Stripping Gas? Manufacturer Stripping Gas Flow Rate N/A sctm Model Condenser?' N Y/N Serial# Condenser Temperature N/A deg F Operation Date Condenser Pressure NIA psis • Operation 8760 hr/yr ECD? N Y/N Wet Gas Temperature 95 deg F ECD Ambient Air Temp N/A deg F • Wet Gas Pressure 800 psig ECD Destruction Efficiency 95.00%. Wet Gas Water Content Saturated IbH2O/MMscf ECD Excess Oxygen 5.00'7 • Dry Gas Flow Rate 33 MMscfd Combustor Downtime 5.00% Dry Gas Water Content Saturated IbH2O/MMscf Lean Glycol Water Content 20.0 wt%H2O Lean Glycol Flow Rate 6 gpm - Cold Separator? Y Y/N Cold Separator Temperature -40 deg F Cold Separator Pressure 700 psig Glycol Pump Make&Model Kerr-Model KZ-3150 Glycol Pump Type Electric Elec.or Gas Glycol Pump Gas Flow Rate N/A actm/gpm Flash Tank? Y YIN Flash Tank Temperature 120.0 deg F Flash Tank Pressure 60.0 psig Flash Tank Control VRIJ wrth ECD backup VRU Downtime 5.00% Total Emissions from GRI-GLYCaIc 4.0 Uncontrolled Emissions CAS Flash Emissions' Still Vent Emissions' Total Dehy Emissions` Emission Factors Pollutant Number (t)y) (tpy) (tpY) (Ib/yr) (lb/MMscf) fl VOC 4.91 1.54 6.45 1.07 n-Hexane 110-54-3 0.02 0.01 0.02 48 0.00 Benzene 71-43-2 0.04 0.43 0.48 953 0.08 Toluene 108-883 1.60E-03 0.02 0.02 46 0.00 Ethylbenzene 100-41-4 1.00E-04 0.00 0.00 2 0.00 Xylene 1330-20-7 6.00E-04 0.02 0.02 32 0.00 Total HAP 0.013 0.48 0.54 0.09 1.Flash emissions and still vent emissions obtained from GlyCalc report dated April 24,2015. 2.Total dehy emissions calculated as a sum of Flash and S511 Vent emissions. Flash Tank Emissions Controlled Emissions CAS Flash Emissions Pollutant Number (tpy) VOC 0.01 n-Hexane 110-54-3 0.00 Benzene 71-43-2 0.00 Toluene 108-88-3 0.00 Ethylbenzene 100.41-4 0.00 Xylene 1330-20-7 0.00 Total HAP 0.00 3.Flash tank emissions are 100%recycled to inlet with the use of a VRU. 4.During VRU downtime flash tank emissions are taunted to the ECD. Still Vent Emissions Still Vent ECU Control CAS Emissions' ECD Downtime Emissions Total Still Vent Emissions' Pollutant Number (tpy) (tpy) (tpy) VOC 0.073 0.077 0.15 n-Hexane 110-54-3 0.000 0.000 0.00 Benzene 71-43-2 0.021 0022 0.04 Toluene 108.88-3 0.001 0.001 0.00 Ethylbenzene 100-41-4 0.000 0.000 0.00 Xylene 1330-20-7 0.001 0.001 0.00 Total HAP 0.023 0.024 0.05 5 Still Vent ECD control emissions refer to emissions controlled by the new enclosed combustor at 95%DRE. 6.ECD downtime emissions refer to emissions during a maximum of 5%enclosed combustor downtime for maintenance and malfunctions, 7.Total still vent emissions is a sum of still vent ECD control and ECU downtime emissions. Total Controlled Emissions CAS Dehy Emissions Dehy Emissions+20%Buffer' Overall System Control1) Pollutant Number (fpy) (tpy) VOC 0.16 0.20 n-Hexane 110-54-3 0.00 0.00 Benzene 71-43-2 0.04 0.05 Toluene 108-85-3 0.00 0.00 97% Ethylbenzene 100-41-4 0.00 0.00 Xylene 1330.20-7 0.00 0.00 Total HAP 0.05 0.06 8.Total controlled dehydrator emissions calculated as a sum of Flash Tank controlled emissions and Still Vent controlled emissions. 9.DCP is adding a 20%buffer to controlled emissions for variability in gas analysis and other actual parameters. 10.Demonstrating an overall system control of 95%,calculated as(100%-Total Controlled Dehy Emissions(0.32 tpy)/Total Uncontrolled Dehy Emissions(6.45 ipy)]. Natural Gas Dehydration Regenerator Overheads Stream Detail from GRIGLYCaIc 4.0 Description Roden Overheads Vent Flow Rate 4.58E+02 scf/hr Hours of operation 87,30 hrlyr Annual Flow Rate 4.012 MMscf/yr Pure Component Pure Component Component , Fraction Component Component Fraction Component Vol% Mol Fraction Mol Weight Mol Weight Mass Fraction Heat Value Heat Value (Ib/lb-moi) (lb/lb-moll (Btu/scf) (Btu/sc5 Methane 0,55 0.0056 16.04 0.09 0.1409 _ 1010.0 5,7 Ethane 0.134 0.0084 3007 0.25 0.3953 1769,6 14.9 Propane 025 00076 4410 0.12 0.1813 2516.1 6.6 i-Butane 0.02 0O002 58.12 0.01 0.0206 3251.9 0.7 n-Butane 0.03 0.0006 58.12 0.04 0.0585 3262.3 2.1 i-Pentane 0 01 00001 72 15 0.01 0.0155 4000.0 0.6 n-Pentane 0.01 0 0001 7215 0.01 0.0117 4008.9 0.4 Cyclopentane 0 01 0.0001 70.13 0.00 0.0074 3763.9 0.3 n-Hexane 13.)339-03 0.0000 86.18 0.00 0.0026 4755.9 0.1 Cycoohexane 0.01 0.0001 84.16 0.01 0.0114 4481.5 0.4 Other Hepanes 3.3335E-03 0.0000 86.18 0.00 0.0052 4755.9 0.2 Heptanes 3.70E-04 0.0000 100.20 0.00 0.0006 55025 0.0 Methylcyclohexane fi 709-04 0.0000 98.19 0.00 0.0O10 5215.7 0.0 2,2,4-Trimethylpentane 3 60E-07 0.0000 114.23 0.00 0.0000 6231.7 00 Benzene 5.11 0.0011 78.11 0.08 0 1278 3741.8 3.9 Toluene • T4.34E-03 0.0000 92.14 0.00 0.0062 4475.0 0.2 Ethylbenzene 1.92E-04 0.0000 106.17 0.00 0.0003 5222.2 0.0 Xylenes 2.74E-03 0.0000 318.50 0.01 0.0136 5208.8 0.1 Octanes+ 2469-06 0.0000 114.23 0.00 0.0000 6248.9 0.0 1.92 0.0192 0.64 1.00 36 1 Flash Tank Emissions Stream Detail from GRt-GLYCaIc 4.0 Description Flash Tank Off Gas Vent Flow Rate 2.37E+02 scf/hr Hours of operation 8760 hr/yr Annual Flow Rate 2.076 MMscf/yr Pure Component Pure Component Component Fraction Component Component Fraction Component Vol% Mol Fraction Mol Weight Mol Weight Mass Fraction Heat Value Heat Value (lb/lb-cool) (lb/lb-rnol) (Btu/scf) (Btu/scf) Methane 23.90 0.2390 16.04 3.83 5.9720 1010.0 241.4 Ethane 22.30 0.2230 30.07 6.71 10.4443 1769.6 3946 Propane 2.76 00276 44.10 1.22 1.8957 2516.1 69.4 i-Butane 0.24 0.0024 58.12 0.14 0.2146 3251.9 7.7 n-Butane 0.51 0.0051 56.12 0.30 0.4599 3262.3 16.6 i-Pentane 0.08 0.0008 72.15 0.06 0.0939 4000.9 3.3 n-Pentane 0 65 0.0005 72.15 0.04 0.0577 4008.9 2.1 Cyclopentane 0.01 0.0001 70.13 0.00 0.0075 3763.9 0.3 n-Hexane 0.01 0.0001 86.18 0.01 0.0087 4755.9 0.3 Cyclohexane 0 01 0.0001 84.16 0.01 0.0079 4481.5 0.3 Other Hexanes 0.02 0.0002 86.18 0.01 0.0226 4755.9 0.8 Heptanes 7.95E-04 0.0000 100.20 0.00 0.0012 55025 0.0 Methylcyclohexane 5.28E-04 0.0000 98.19 0.00 0.0008 5215.7 0.0 2,2,4-Trimethylpentane 1.77E-06 00000 114.23 0.00 0.0000 6231.7 0.0 Benzene 0.02 00002 78.11 0.02 0.0251 3741.8 0.8 Toluene 6 24E-04 0.0000 92.14 0.00 0.0009 4475 0 0.0 Ethylbenzene 251E-05 0.0000 106.17 0.00 0.0000 5222.2 0.0 Xylenes 2.22E-04 0.0000 318.50 0.00 0.0011 5208.8 0.0 Octanes iii 1.40E-06 0.0000 114.23 0.00 0.0000 6248.9 0.0 49.90 0.4990 12.34 19.21 738 Enclosed Combustor Emissions Greeley Natural Gas Processing Plant DCP Midstream, LP Enclosed Combustor Pilot Gas: 50 scf/hr Assist Gas: 350 scf/hr Fuel Heat Content: 1070 BTU/scf Total Natural Gas Usage: 400 scf/hr Hours per Year: 8,760 hr/yr Fuel Use: 3.504 MMSCF/yr Waste Gas Flow Rate: 4.116 MMSCF/yr 3,749 28 MMBTU/yr assist gas 222.40 MMBTU/yr from the waste stream 3,972 Total MMBTU/yr Criteria Pollutant Emission Calculations Emission Factors* Emissions Pollutant (Ib/mmbtu) (ton/yr) NOx 0.068 0.14 CO 0.37 0.73 •AP-42 Table 13.5-1 , Item/Tag No.: I Page 1 1 of 1 3 fProject No.: Revision: B I Date: 08 May 2014 LE' Project: — By: is Enviromental Control Equipment P.O.No.: - Checked: SG Data Sheet RFQ No.: - Approved: MS Client: DCP Ref.P&ID: - Site: Supplier: LEED FABRICATION Remarks: - Model No.: L80-0003-XX Unit/Lease: GENERAL s Design Code: NDE: LEED Fabrication Standards 2 Service: Customer Specs: ❑ Yes 3 Description: Temperature Controlled High Efficiency Combustor Unit [] No PROCESS DATA Process Conditions: Gas Composition: mol/ Variable Value Units 4 Methane Flow Rate Up to 40 Mscfd 5 Ethane Pressure Up to 12 oz/in2 6 Propane Temperature °F 7 I-Butane Molecular Weight a n-Butane Process/Waste Stream ❑✓ Gas ❑ Liquid 9 I-Pentane Detailed Process Description/Process Notes: so n-Pentane 1.Turndown 10:1.Based on an expected normal operating rate indicated above. 11 n-Hexane 2.Hydrocarbon DRE:98% operating at design conditions 12 CO2 3.Burner Pressure Drop:Min.0.10 oz/in2 4.Gas composition and flow rates provided by customer 13 N2 14 Helium 15 H2O 16 Cl 17 CB 18 C9 • 19 C10 20 C11+ 21 TOTAL OtherComponents: PPMV Available Utilities: 22 H2S Fuel/Pilot Gas Min.30psig Natural Gas/Propane 40-50 SCFH 23 Benzene Instrument Air NA 24 Toluene Power 120 V/60 Hz or Solar Power 25 E-Benzene Steam NA 26 Xylene Purge Gas DESIGN DATA 27 Ambient Temperatures: Noise Performance Requirements: Under 85 dBA 28 Low,°F -20 Structural Design Code: 29 High,°F 120 Wind Design Code: ASCE 30 Design Conditions: Pressure/Temperature 31 Max.Relative Humidity,% 90 Pressure/Speed 100 mph 32 Elevation(ASL),ft Category 33 Area Classification: Class I Div 2 Seismic Design Code: 34 Electrical Design Code: NEC Location - EQUIPMENT SPECIFICATION 35 Type: ❑ Elevated 0 Enclosed Equipment Design: 36 ❑ Above Ground Component Material/Size/Rating/Other 37 2 Stack ❑ Multiple Stack Burner 38 ❑ Portable/Trailer Burner Tip/Assist Gas Burner 304 SS 39 Burner Body Carbon Steel 40 Smokeless By: ❑ Steam ❑ Assist Air -Pilot 41 ❑ Gas Assist [J Staging Pilot Tip 304 5S 42 Pilot Line(s) Carbon Steel — 43 Stack: 0 Self Supporting Firebox/Stack 44 Flare Burner: ❑ Non-Smokeless 2 Smokeless ❑ Gas Assist Shell Carbon Steel 45 Pilot: ❑ Intermittent FA Continuous Piping Carbon Steel 46 Pilot Airinspirator: [1 Local ❑ Remote Nozzles Carbon Steel 47 Pilot Flame Control: ❑ No ❑ Yes(Thermocouple) Flanges Carbon Steel 43 Insulation Blanket . 49 Pilot Ignition: ❑ Flamefront Generator ❑ Inspirating Ignitor Insulation Pins 304 S5 so ❑ Electronic Q Automatic ❑ Manual Refractory NA 51 - ❑ With Pilot Flame Control Refractory Anchors NA s2 ❑ With Auto Pilot Re-Ignition Ladders and Platforms NA 53 Stack Sample Connections Per EPA requirements 54 Pilot Ignition Backup: El Manual Specify: i.e Piezo-Electric Sight Glass 2 55 ❑ Battery Pack Other I Item/Tag No.: _I Page 2 of 11 3 / f / Project No.: Revision: _----_ B LE Date: 08 May 2014 Project: By: JS ___ Environmental Control Equipment P.O.No.: Checked: SG -- ----------------- -- Data Sheet RFQ No.: Approved: MS Client: DCP Ref.P&ID: -- _....._...._.--- Site: Supplier. LEED FABRICATION _ Unit/Lease: Remarks: i- Model No.: L80-0003-X.X EQUIPMENT SPECIFICATION 56 Flame Detection: ❑ Thermocouple El Ionization Rod Auxiliary Equipment 57 ❑ UV Scanner Valves NA sa General Configuration: Blowers NA 59 Dampers NA 60 Inlet KO/Liquid Seal NA 61 Flame/Detonation Arrestor Yes 62 Instrumentation&Controls 63 Solenoids/Shut-Off Valves Check with Sales for available config. 64 Flow Meters NA 65 ° Calorimeter NA • 66 Pressure Switches/Transmitters NA 67 — Thermocouples Check with Sales for available config. 63 Temperature S sitches/Transmitters NA 69 f y' BMS Check with Sales for available config. 70 .•• — CEMS NA 71 Other NA 72 73 71 75 FABRICATION AND INSPECTION 76 Special requirements ❑ Skid Mounted ❑✓ Concrete Pad Equipment Info 77 ❑ Other Component Weight/Dimensions 78 Burner 79 Inspection ✓❑ Vendor Standard Burner Assembly 30 ❑ Other.Specify: Stack in Material Certification ❑✓ Vendor Standard Stack Assembly 24"OD x 24'II 82 ❑ MTR Pilot Tip 83 ❑ Certificate of Compliance Pilot Line(s) 31 ❑ Other(Specify): Stack Assembly as NDE n Vendor Standard Auxiliary Equipment 36 ❑ Radiography.Specify: Blowers 87 ❑ Ultrasonic.Specify: Inlet KO/Liquid Seal 88 ❑ Liquid Penetrant. Flame/Detonation Arrestor 89 ❑ Magnetic Particles. Skid 90 ❑ PMI.Specify: Instrumentation&Controls 91 ❑ Other.Specify: BMS 92 Surface Preparation Q Vendor Standard Control Panel 93 ❑ Other.Specify: 94 Paint System [d Vendor Standard 95 [] Other.Specify: 96 Finished Color Q Vendor Standard 97 n Other.Specify: 98 99 Additional Notes: Item/Tag No.: Page 3 I of I 3 Project No.: I Revision: B LE> Date: 08 May 2014 swemc4�+vv- Project: By: JS Environmental Control Equipment P.O.No.: - Checked: SG Data Sheet RFQ No.: - Approved: MS Client: DCP Ref.P&ID: - Site: Supplier: LEED FABRICATION Unit/Lease: Remarks: - Model No.: L8O-OOO3-XX GENERAL ARRANGEMENT • +r _ , Ii r t • • -r_.r EMPACT ANALYTIC SYSTEMS INC.• _- 365 S. MAIN ST. BRIGHTON, CO 80601 303-637-0150 EXTENDED NATURAL GAS ANALYSIS (*DHA) GLYCALC INFORMATION PROJECT NO. : 201412156 ANALYSIS NO.: 01 COMPANY NAME: DCP MIDSTREAM ANALYSIS DATE: DECEMBER 30, 2014 ACCOUNT NO. : BILLING CODE:G011 SAMPLE DATE : DECEMBER 19,2014 PRODUCER : CYLINDER NO. : 0583 LEASE NO. : SAMPLED BY : BRANDEN HAYES NAME/DESCRIP : PRE-DENY 08:40 GREELEY GAS PLANT ***FIELD DATA*** SAMPLE TEMP. : 95 F SAMPLE PRES. : 800 PSI AMBIENT TEMP.: VAPOR PRES. : GRAVITY . COMMENTS : SPOT;NO PROBE;ANNUAL GREELEY Componet Mole% Wt% Helium 0.00 0.00 Hydrogen 0.00 0.00 Carbon Dioxide 2.53 5.06 Nitrogen 0.21 0.27 Methane 75.34520 54.96550 Ethane 12.5156 17.1135 Propane 5.3901 10.8084 Isobutane 0.8511 2.2495 n-Butane 1.7930 4.7390 Isopentane 0.4746 1.5571 n-Pentane 0.4634 1.5204 Cyclopentane . 0.0176 0.0561 n-Hexane 0.0926 0.3629 Cyclohexane 0.0205 0.0784 Other Hexanes 0.1732 0.6761 Heptanes 0.0554 0.2516 Methycyclohexane 0.0152 0.0679 2,2,4 Trimethylpentane 0.0001 0.0005 Benzene 0.0207 0.0735 Toluene 0.0151 0.0633 Ethylbenzene 0.0002 0.0010 Xylenes 0.0024 0.0115 C8+Heavies 0.0139 0.0735 Subtotal 99.99990 99.99970 Oxygen/Argon 0.00 0.00 Alcohols 0.0001 0.0003 Total 100.00000 100.00000 THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT . STATE-OF-THE ART ANALYTICAL TECHNIQUES. THE APPLICATIONS OF THIS INFORMATION IS THE RESPONSIBILITY OF THE USER. EMPACT ANALYTICAL SYSTEMS,INC.ASSUMES NO RESPONSIBILITY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF IT'S APPLICATION. Emergency/Maintenance Flare Greeley Natural Gas Processing Plant DCP Midstream,LP Plant Flare (Equipment ID:Flare) AIRS ID: 123/0099/TED Source ID F-1 Description Flare Manufacturer John Zink Model EEF Series Serial# 9027692 Manufacture Date 2004 Fuel Heat Value 1040 Btu/scf Pilot Flow Rate 150 scf/hr Purge Gas Flow Rate 80 scf/hr Heat hput 0.24 MMEitu/hr Hours of Operation 8760 hr/yr Potential Fuel Usage 2.01 MMscf/yr Destruction Efficiency 95% Emissions from Fuel Combustion Emission Source of CAS Factor Emission Pollutant Number (lb/MMscf) (lb/hr) (Ib,yr) (ton/yr) Factor NOx 100 0.02 201.48 0.10 AP-421 CO 84 0.02 169.24 0.08 AP-42' VOC 5.5 0.00 11.08 0.01 AP-42' _ SO2 0.6 0.00 1.21 0.00 AP-42° PM 7.6 0.00 15.31 0.01 AP-42` 2-Methyinaphthalene 91-57-6 2.40E-05 5.52E-09 4.84E-05 2.42E-08 AP-42' 3-Methylchloranthrene 56.49-5 1.80E-06 4.14E-10 3.63E-06 1.81E-09 AP-423 7,12-Din ethylbenz(a)anthracene 1.60E-05 3.68E-09 3.22E-05 1.61E-08 AP-42' Acenaphthene 83.32-9 1.80E-06 4.14E-10 3.63E-06 1.81E-09 AP-42' Acenaphthylene 208-96-8 1.80E-06 4.14E-10 3.63E-06 1.81E-09 AP-423 Anthracene 120-12.7 240E-06 5.52E-10 4.84E-06 2.42E-09 AP-423 • Benz(a)anthracene 56-55-3 1.80E-06 4.14E-10 3.63E-06 1.81E-09 AP-423 Benzene 71-43-2 2.10E-03 4.83E-07 4.23E-03 2.12E-06 AP-423 Benzo(alpyrene 50.32-8 1.20E-06 2.76E-10 2.42E-06 1.21E-09 AP-423 Benzo(b)fluoranthene 205-99-2 1.80E-06 4.14E-10 3.63E-06 1.81E-09 AP-423 Benzo(g,h,i)perylene 191.24-2 1.20E-06 2.76E-10 2.42E-06 1.21E-09 AP-42" Benzo(k)fluoranthene 205-82-3 1.80E-06 4.14E-10 3.63E-06 1.81E-09 AP-423 Chrysene 218-01-9 1.80E-06 4.14E-10 3.63E-06 1.81E-09 AP-423 Dibenzo(a,h)anthracene 53-70-3 1.20E-066 2.76E-t0 2.42E-06 1.21E-09 AP-423 Dichlorobenzene 25321-22-6 1.20E-03 2.76E-07 2.42E-03 1.21E-06 AP-423 Fluoranth en 206-44-0 3.00E-06 6.90E-10 6.04E-06 3.02E-09 AP-42' Ruorene 86-73-7 2.80E-06 6.44E-10 5.64E-06 2.82E-09 AP-42' Formaldehyde 50-00.0 7.50E-02 1.73E-05 1.51E-01 7.56E-05 AP-42' n-Hexane 110-54-3 1.80E*00 4.14E-04 3.63E+00 1.81E-03 AP-423 Indeno(1,2,3-c,d)oyrene 193-39-5 1.60E-06 4.14E-10 3.63E-06 1.81E-09 AP-423 Naphthalene 91-20-3 6.10E-04 1.40E-07 1.23E-03 6.15E-07 AP-42' Phenanthrene 85-01-8 1.70E-05 3.91E-09 3.43E-05 1.71E-08 AP-423 Pyrene 129-00-0 5.00E-06 1.15E-09 1.01E-05 5.04E-09 AP-42' Toluene 108.88-3 3.40E-03 7.82E-07 6.85E-03 3.43E-06 AP-42' Arsenic 7440-38-2 2.00E-04 4.60E-08 4.03E-04 2.01E-07 AP-424 Beryllium 7440-41.7 1.20E-05 2.76E-09 2.42E-05 1.21E-08 AP-424 Cadmium 7440-43-9 1.10E-03 2.53E-07 - 2.22E-03 1.11E-06 AP-42° Chromium 7440-47.3 1.40E-03 3.22E-07 2.82E-03 1.41E-06 AP-42' Cobalt 7440.484 8.40E-05 1.93E-06 1.69E-04 8.46E-08 AP-424 Manganese 7439-96.5 3.80E-04 8.74E-08 7.66E-04 3.83E-07 AP-42" Mercury 7439-97-6 2.60E-04 5.98E-08 5.24E-04 2.62E-07 AP-42' Nickel 7440-02-0 2.10E-03 4.83E-07 4.23E-03 2.12E-06 AP-42' Selenium 7782-49-2 2.40E-05 5.52E-09 4.84E-05 2.42E-08 AP-424 Total I-lAPs 4.34E-04 3.8039 0.0019 'EPA AP-42,Volume I.Fifth Edition,July 1998,Table 1.4-1 2 EPA AP-42,Volume I,Fifth Edition,July 1998,Table 1.4-2 3 EPA AP-42,Volume I,Fifth Edition,July 1998,Table 1.4-3 °EPA AP-42,Volume I.Fifth Edition,July 1998,Table 1.4-4 DCP Midstream I Greeley Natural Gas Processing Plant Page 1 of 2 Vents to Combustion Device Row Rate Operation Flow Rate Heat Value Heat Rate Vent Stream (scf/hr) (hr/yr) (MMscf/yr)2 (Btu/scf)' (MMBtu/yr) Waste Gas to Flare J 6382.34 8760 55.91 1300 72682.1 'Per 40 CFR60.18(cX4)(ii),minimum healing value of 1000 Btu/scf required for non-assisted flares is required.Average heat value obtained from actual waste gas flow to the flare. 2 Calculated based on worst case flow rate routed to the plant flare during the course of a year. Emissions from Combustion NOx EF' NOx NOx CO EF' CO CO Vent Stream (lb/MMBtu) (lb/hr) (Ipy) (lb/MMBtu) (lb/hr) (ipy) Waste Gas to Rare 0.068 0.565 2.475 0.310 2.573 11.270 Fuel Gas2 Emissions 0.023 0.101 0.019 0.085 Total 0.59 2.58 2.59 11.35 'NOx and CO emission factor obtained from EPA AP-42 Section 13.5,Table 13.5-1 and 13.5.2(April 2015). 2 Fuel gas emissions reflect pilot and purge gas combustion. Inlet Gas Composition-12/2014 Mot%' MW Component Masse 4%' N2 0.2100 28 5.9 0.2700 Carbon Dioxide 2.5300 44 111.3 5.0600 Methane 75.3452 16 1205.5 54.9655 Ethane 12.5156 30 375.5 17.1135 Propane 5,3901 44 237.2 10.8084 i-Butane 0.8511 58 49.4 2.2495 n-Butane 1.7930 58 104.0 4.7390 • i-Pentane 0.4746 72 34.2 1.5571 n-Pentane 0.4810 72 34.6 1.5765 n-Hexane 0.0926 86 8.0 0.3629 Cyclohexane 0.0205 86 1.8 0.0784 Other Hexanes 0.1732 86 14.9 0.6761 Heptanes 0.0554 100 5.5 0.2516 Methylcyclohexane 0.0152 98.186 1.5 0.0679 2,2,4 Trimethylpentane 0.0001 114.23 0.0 0.0005 Benzene 0.0207 78.1 1.6 0.0735 Toluene 0.0151 , 92.1 1.4 0.9633 Ethylbenzene 0.0002 106.2 0.0 0.0010 Xylenes 0O024 106.2 0.3 0.0115 Octanes a 0.0139 __ 114 - 1.6 0.0735 Total 100 2194.05 100 MW of Gas' 21.94 • VOC Wt%4 22.59 Conservative VOC wt%' 24.50 yo 'Mol%and wt%obtained from inlet gas analysis for December 2014. 'Component mass=Mol%x MW. 3 MW of Gas=Total Mass/Total wt%. a VOC WI%calculated as sum of individual VOC components. s Conservatively increasing permitted VOC wt%to 24.5%to allow for inlet EGA variance. Total Flared Emissions Specific Volume of Air 379 scf/mol Uncontrolled' Controlled' Fuel Combustion' Total' Pollutant (tpY) (tpy) (tPY) (tpy) VOC 396.49 19.82 0.01 19.83 (lb/yr) (Ib/yr) (lb/yr) (Ib/yr) n-Hexane 11746 , 587 3.63 591 2,2.4 Trimethylpentane 16 1 1 Benzene 2379 119 4.23E-03 119 Toluene 2049 102 6.85E-03 102 Ethylbenzene 32 2 2 Xylenes 372 19 - 19 'Uncontrolled emissions calculated based on ideal gas law: VOC(tpY)=Flared Volume(MMscf/vrl x MW gas[lb/lb-moll x(106 scf/MMscfl x VOC wt% Air Specific Volume jscf/lb-mol]x[2000 lb/ton] 2 Controlled emissions calculated using DRE of 95%: Controlled VOC(tpy)=Uncontrolled VOC(tpy)x(100-95)% 3 Fuel combustion emissions reflect pilot and purge gas combustion. 'Total emissions are the sum of controlled emissions and fuel combustion emissions DCP Midstream I Greeley Natural Gas Processing Plant Page 2 of 2 Control Colorado Department of Public Health and Environment Air �____. Form APCD-102 Pollution Division C D P H E �p , Facility Wide Emissions Inventory Form Ver.April,20I 5 ' r .. Company Name:DCP MI5ltcun,LP . , q Source Name:Greclov bas Plant Source AIRS ID:123'0099 rmmnrrolled Potential to 000119'0) l'un(roilal P61mOnl to Emit(PIE) Criteria rn'll -.... __.. 1101',:161yr1 Criteria I11.Y, OAP,(Ms/yr) AIM 10 F:qul4onumocseripdon TSP PAIIII 1'011.5 902 NO, YO(' (:0 IIC110 leetal AmO ti, T6l En Ny) n-Ilex Meth 284-ISIS' ESP 1'6110 1.018.5 502 NO, N0C C0 11(110 A0,aal Acr6 —6!. Tol P.O 6yl n--tie. Meal 224'I'SI• 23/0090'109 E0000 3%152N-11N 0.70 0.79 0.70 0.02 13009 511 95.00 1.677 228 215 29 40 2 16 230 0.79 0.79 0.79 0.02 2124 .3.,11 _05> 407 114 108 65 2:5 I II 125 790099'1)18 I???0,00 065 0,05 0.65 0.02 122.41 4.31 77,17 1,305 106 1'75 05 37 2 17 214 . 0.65 0.65 0.65 0.02 1'7.30 4.73 21.90 126 91 65 51 1) 2 13 201 210099/102 lit -124'1'-12I 0.01 0.09 008 000 960 1160 ii.16 179 24 20 14 S 0 1_ 27 000 0.08 001 0 0 3.02 060 4.:2_4 43 12 II 7 2 1 I II 21,0099,107 I-nr:nc 0.111,7120 0.79 0.79 0.79 002 138.';9 5.3 93000 11,77 22k III 29 46 2 10 250 0.1'') 0.79 0.79 11.02 26,55 5.31 26.55 401 114 100 05 20 122 _23,'0099:103 Fn6inc C-116,l'I_22 0.79 0.70 0.79 002 13%00 5.7 95.00 1,077 128 215 29 49 2 II 100 11,7'0 079 0,09 0.02 20.55 5,31 26.55 401 114 108 65 23 I25 0595,0'I04 Engine 0-117;7.125 0.79 0.79 0.79 0.02 131.09 5. 05.617 1677 228 215 19 49 2 16 250 079 0.79 0.79 0.02 26..05 5.11 20.55 407 114 ION 65 23 125 2VJ094,105 facia,C.IIB'l'-114 0.79 0.79 0.79 0.112 130.09 5.3 95.60 1077 22) 215 20 4), 2. 10 230 0.79 0.70 0.79 002 26.55 9.31 26 55 403 314 100 65 23 125 - 21,0099'1111 Einar,0.1229,129 0.79 0.79 079 0.02 130.09 0.1 95.60 1,677 224 215 29 46 2 16 250 0.79 0.79 0.79 0.02 20.55 5.11 26.55 403 _ 114 108 65 13 25 23;139,190 Engin,C.119,R125 070 11.79 (079 0.112 110.09 5 1 05.09 1,677 224 215 29 46 1 - 16 250 _ U,:9 0.79 0.73 3701 21,24 5.31 2655 401 114 100 65 21 '.25 239009.'121 P130 0.14 04 0.'7 9.53 46 2 71 48 0.14 0.20 0.73 101 5 2 23707990 13 3'1327110 Oil ileotcr 0.48 0.40 0.48 0.004 6.32 O 1 9.91 0 0 227 0.48 0.40 0.40 0.04 6.11 0.35 5.31 9 0 227 23;0003/120 PI39FI91011 Heater I.II III III 0.09 101,4 0.8 10.30 22 I 527 1 I III III 0.04 14.64 09) 12.70 ._ I .2. 23:00091115 I'135,Pre.ssuri-cd truck Loading 43 II 43.13 23!0609'114 Fugitives 79.92 • 4,440 24.13 1,340 27'0099.')22 Elam 0.01 0.01 0.01 0.00 2.58 19649 11.35 2,179 2.049 12 372 11;745 001 0,01 0.01 '9.00 2.55 19.83 11.35 Ill 1112 _ 19 5'01 _ Permitted Source.Subtotal- 4,0 4.0 4.0 02 4353 146.6 305,1 5063 685 646 1,34_' 183 8 %I 5,243 I 751 0 4.0 4.0 4.0 0.2 95.4 84.6 98.0 1.219 312 323 296 73 l 28 2,097 376 0 OPEN Only-Perndt E,empt Sources I I I I l OPEN Only Subtotal- 0.0 0.0 0.11 0.0 0.0 00 0.0 I 6 U 0 0 0 0 0 0 0 0 11.11 0.0 0.0 11.0 (1.0 0.0 11,0 0 0 0 0 0 0 0 11 0 0 APEN Eeempt/Inslsnin,anl sources In,ilonfeont Ao9ivi0c, 4.1 55 34 -- 157 '71 4.1 5.5 3.1 152 173 I 1 01,Irnl0em,t Subtotal^ 0.0 0.0 0.0 0.0 4.1 5.5 71 I 0 II 11 0 0 0 II 151 273 0 11.0 0.0 0.0 0.0 4,1 65 3,4 13 0 0 0 0 0 II 152 273 11 fatal,All Source,=' 4.0 I 4.0 I 4.0 I 0.2 I 430.4 I 152.1 I 308.6 I 5,063 I 485 I 646 I 1,340 I I%:3 8 I 80 15,194 I 1,024 I 9 I 4.0 I 4O I 4.0 I 0.2 I 99.5 I 90.1 I 101.4 1,239 I 042 I 323 I 296 I 73 13 I 28 12,248 I 648 0 ('ncuntrnllcdli.51's Summan(IPY)-I 2.5 0,3 I 0.3 I 0.7 I 0.1 I 0.0 I 0.0 I ,7 I 0.5 I 0.0 ' Controlled 1Lll's Summon 111'1'141 0.6 I 02 I 0.2 I 0.1 I 0.0 I 0.0 I 0.0 I 1,1 I 01 I 0.0 Uncontrolled Total,:ill HAP,0100 I-I 7.2 ('0,0,01150 Total,All 1207,(TPl•1=I 2.6 I Footnotes: 1.This form should be completed to include both cooling 104(069 and all prop000i new orn3cdificatinos t0,Sistine emissions 1001,5 2 If the emissions source is new then enter"proposed"under the Yvan:!No and AIRS ID ilia.,columns 3.HAP ahbrevinliens include, IIZ=8,0,45 e 224,1MP-3.2,4-I rimelltvlpcoIooe TO-'Inhume Aeetal=Acculdclp do FD=Flhylhavene Acro-Acroicin Xyl=Xvlene n-I let-n-11030. 11O7IO=Fnnu ldohydc Meth-Methmol 4.Al')N G.or.pelnsignifi,:m1 Sauna.should be:1)440,50)edam wanmdedl. DCP Midstream 4/28/2016 Page 1 of 1 AIR POLLUTANT EMISSION NOTICE(APEN) &Application for Construction Permit—Glycol Dehydration Unit' iti Permit Number: 95OPWE038 heave blank unless APCD has aheady assigned a permit ai&AIRS 1Di Emission Source AIRS ID: 123 / 0099 / 421' Facility Equipment ID' P-130 [Provide Facility lquipment ID to identify how this equipment is referenced within your organization.] Section 0 i —Administrative information Section 02—Requested Action(Check applicable request boxes) • Company Name: DCP Midstream,LP NAICS.or 13 Request for NEW permit or newly reported emission source Processing > SIC Code: 1321 Source Name: Greeley Natural Gas Plant Q Request MODIFICATION to existing permit(check each box below that applies) Source Location: Sts'Sec 25,'I'SN,R66\V County: Weld ® Change process or equipment ❑ Change company name Elevation: 4,691 Feet ❑ Chance permit limit ❑ Transfer of ownership ❑ Other Mailing Address: 370 17`1 Street,Suite 2500 ZIP Code: 80202 ❑ Request to limit 1IM's with a Federally enforceable limit on VIE Denver,CO ❑ Request APEN update only(check the box below that applies) Person In Contact: Roshini Shankaran Phone Number: 303-605-2039 ❑ Revision to actual calendar year emissions for emission inventory, _ Update 5-Year APEN term without change to permit limits or previously E-mail Address: t'slwiiI it lniu;rlmprnidstrcann.cout I ax Number: 303-605,1957 ❑ reporter!emissions Addl.Info. Section 03—General Information Notes: 20%added to emissions to account for possible changes in gas composition. I.or e'istme sources.operation began on: - 1983 For new or reconstructed sources,the projected startup date is: 04 I / 2015 Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year General description of equipment and purpose: Natural Gas Hydration Inhibition.System Using Ethylene Glycol. A- is this unit subject to the 90"o control requirement of Colorado Regulation No.7.XVILI)(total uncontrolled actual VOC emissions from all dehydration units at tins stationary source.including APEN Exempt units, 13 ionadyr)? [3 Yes ® No ID Don't know i► Will this equipment be operated in any NAAQS nonattainment area? (hit o: u•wit color,ilw ov c dphr-atlainineni) [1 Yes ❑ No E Don't know ® Is this unit located at a stationary source that is considered a Major Source of hazardous Air Pollutant(I emissions? ❑ Yes ❑ No ❑ Don't know Section 04—Dehydration Unit Equipment Information Manulaetarcr: Model: Serial No.: Colorado Department of Public Health and Environment air Pollution Control Division(APCD) Reboi ler Rating: -1.6 MMl3 hr Glycol Used: ❑ Trilithykne Glycol(11iG) ❑ I thykne.Glycol(LG) ❑ DiL"thyleue Glycol(DEG) This notice is valid Mr live(5)years. Submit a revised APEN prior to Glycol Pump Drive: Q Electric ❑ Gas If gas.injection pump ratio: aultm% ptm expiration of live-year term, or when a significant Change is made (increase production,new equipment,ehattge in Inca type,etc). !'coup Make&Model: Kerr—\lodel KZ-3150 :i of Pumps: 1+backup Glycol recirculation rice(1ii i tin): Max: Requested': 6 Lean glycol water content: 2i) wt.gii Mail this form along with a check for 5152.911 to: Colorado Department of Public I leatth&It:m ironmunt I)chy.Gas Throughput: Design Capacity: 33.(1 MMSCF/day Requested I: 12,0.15 MMSCF/yr. APCD-SS-l31 Calendar year actual: 9,131.0 MMSCF/yr. 4300 Cherry Creek Drive South Inlet Gas: Pressure: 80(1 psig Temperature: 95 1' Denver,CO 81)246-1530 Water Content: Wet Gas: IbiMMsef ❑ Saturated Dry Gas: lb/M,Mscf For guidance on how to complete this APEN loran: Flash"lank: pressure: (0 prig Temperature: 121) 1' ❑ None Air Pollution Control Division: (303)092-3150 Small Business Assistance Program(SBAP): (303)692-3148 or Cold Separator: Pressure: 701) psig Temperature: -40 I' ❑ None (303)692-3175 Stripping Gas: Li None L Use flash gas ❑ Use dry gas: selin ❑ Use N,: sclin APEN forms:hip:•:www.Colorado.00v cdphorAI'f•:Nlimrnis 'You.sill be charged:in additional AP1iN Is.,if,APEN is tilted out incorrectly or missing information and requires re-submitiail' Apinlicatiuu status: miii is ow-,uolru•:nfn,±it s s.iI;ho'Perntiltilnluv 'IZcqueci est in Incs Will become permit limitations. Additional 0 Attach a process flow diagram Information (7} Attach GRI-G1.YCalc 4.0 Input Report ek Aggregate Report(or equivalent simulation report test results) © Check box to request copy of draft permit prior to issuance. Required: ❑X Attach the extended gas analysis(including I3I'PX 1.n-Hexane.temperature&pressure) ® Check box to request copy ol'draft permit prior to public notice. FORM APCD-202 ' Page 101 2 Greeley-Form APCD-202 Glycol Dehydrator APEN AIR POLLUTANT EMISSION NOTICE(APEN) &Application for Construction Permit—Glycol Dehydration Unit' Permit Number: 95OPWE038 Emission Source AIRS ID: 123 / 0099 I 121 Section 05—Stack Information (Combustion stacks must be listed here) Section 06—Stack(Source,if no combustion)Location(Datum&either Eat/Long or I)'I'M) Stack Diseharre Horizontal Datum UTM tJ"fvI Easuat or U"111 Northing or Method of Collection for Operator Stria;BasevS Stack Elevation Height Above Temp. Flow Rate Velocity Moisture (NAD27,N:1D83, Zone Longitude Latitude Location Data(e.g.matt. ID No. J (Feet) Ground Level (`F) (AChA1) ((!,sec) CIO \VGS34) (12 or 13) (meters or degrees) (meters or degrees) CPS,GoogleEarth) _ (feet) P-130 ( 4,691 I 24 I NVC1S84 I 13 I 522,836.35 1 4,468,218 I (:1'S Direction of stack outlet(check outs): [] Vertical ❑ Vertical with obstructing raineap ❑ Horizontal El Down ❑ Other(Describe): Exhaust Opening Shape S:.Size(check one): ® Circular: Inner Diameter(inches) 24 E Other:Length(inches) - Width(inches)'- Section 07—Control Device Information (Indicate if a control device controls the flash tank and/or regenerator emissions) ❑ Condenser used tar control of t © Combustion Device used for control of: Re,,!en.Overheads Streatn Rating: 0.45 MMBtu/hr Type: Make/Model: Type: Enclosed Combustor Make/Model/Serial t=: I.EED Fabrication—I.80-0003-XX I cinperatuor E-T): Maximum: Average: VOC&HAP Control Efficiency: Requested: 95. 0,0 Manufacturer(.ivaranteed: 98 ,;a Requested VOC..d I IA l'Control Efficiency: rio Minimum temp.to achieve requested control: 'F Waste gas hest content: 540 Btu/sal ❑ VRU used Fir control of: Flashing'lank Emissions Constant pilot light? © Yes ❑ No Pilot burner rating: 11.05 MNIlituihr Site: Make/Model: ' ❑ Closed loop system used for control of: Requested VOC&I1AP Control Efficiency: 95 °s Description: Annual time that VRU is bypassed(emissions vented): 5* 'o Describe Any Other: *ECD controls flash tank emissions during VRU downtime. Section 08—Emissions Inventory Information ir Emission Control Information I I Emission Factor Documentation attached Data year for actual calendar yr.emissions below&gas throughput above(e.g.2007): 2014 1 _ Requested Permitted Intimation Method Control Device Description Control Emission Factor Actual Calendar Year Emissions' Emissions or Pollutant Efficiency Uncontrolled Controlled Uncontrolled Controlled Emission Factor Primary Secondary (`l'u Reduction) Uncontrolled Basis Units ('Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Source NON 0.065 Ib/MM13TU 0.14 11.14 AP--I2 YOU 1.07 lb/MIVISCF 3.07 5.07 6.45 0.20 GLYCulc CO (1.37 lb/NIMBI-1) 0.73 0.73 'AP--12 }'omens (1.08 lb/n-IIMISCIf 0.31 0.31 0.48 0.(15 GLYCulc — Identify in Section 07 Iota rat e Ethyl bcnzcne Xslcnc n-Ilcxane Please use the;1P('l),Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. t You will IN,charged art additional APEN ice if API N is filled out incorrectly or missing information and requires re-submittal. 'Amami cntisston tees twin be!rased on actual emissions reported here. If left blank,annual cmissiun tees Mill be based on requested emissions. a Section 09-, ppiieant Certification-I hereby certify that all information contained herein and information submitted with this application is complete,true and correct. ` c5 (C)I l26/S- Rushini Shankaran Environmental Engineer Sign•Lure of Person Legally Authorized to Supply Data Date Name of Legally Authorized Person(Please print) Title Page 2 of 2 Greeley-Form:vPC'D-202_Glycol Dehydrator:WEN -4' DP' ' " General APEN - Form APCD-200 4 Air Pollutant Emission Notice (APEN)and V Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities,including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. There may be a more specific APEN for your source (e.g. paint booths, mining operations,engines,etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD)website at www.colorado.gov/cdphe/apcd. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made(significant emissions increase, increase production, new equipment,change in fuel type, etc). See Regulation No, 3, Part A, II.C. for revised APEN requirements. Permit Number: AIRS ID Number: 95C7PWE038 123 /0099/ [Le,: a b ;r.k unless AFCD has:ali_3 , ssi_r d a per .i, ? j,,.RS iD) Section 1 - Administrative Information Company Name': DCP Midstream, LP Site Name: Greeley Natural Gas Processing Plant Site Location: Site Location SW 1/4 Section 25,T5N, R66W County: Weld NAICS or SIC Code: 1321 Mailing Address: (include Zip Code) 370 17th St, Suite 2500 Denver, CO Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 Portable Source E-Mail Address: RShankaranudc midstream.com Home Base: p 'Please use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. rum rFC-0 _. i< t j _0 5 Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 2- Requested Action ❑r NEW permit OR newly-reported emission source(check one below) O STATIONARY source ❑ PORTABLE source -OR- ❑ MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment O Change company name O Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership2 ❑ Other(describe below) -OR- • APEN submittal for update only(Please note blank APENs will not be accepted) -Aootrlo AL PEWIT ACTIONS- ❑ Limit Hazardous Air Pollutants(NAPS)with a federally-enforceable limit on Potential To Emit(PTE) ❑ APEN submittal for permit exempt/grandfather€d source Additional Info a Notes: Flare with a DRE of 95%to handle maintenance and malfunction emissions. DCP is requesting en annual limit of 55.91 MMscf/yr for the volume of emissions being routed to the flare. z For transfer of ownership,a completed Transfer of Ownership Certification Form(Form APCD-104)nxlst be submitted. Section 3 - General Information General description of equipment and purpose: Plant Flare Manufacturer: John Zink Model No.: EEF Series Serial No.: 9027692 Company equipment Identification No. (optional): Flare For existing sources, operation began on: 2004 For new or reconstructed sources, the projected start-up date is: ❑Check this box if operating hours are 8,760 hours per year;if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/weer weeks/year Seasonal use percentage: Dec-Feb: Mar-May: June-Aug: Sept-Nov: COLORR0O Form APCD-20O-General APEN -Revision 7/2015 2 ( ,. ,r,"°,':':. Permit Number: 95OPWE038 AIRS ID Number: 1 23 /0099/ e __ blank urless r.PCC has-. dr,.._. =.1 a G .i F=;:lrj i ) Section 4 - Processing/Manufacturing Information a Material Use ✓❑Check box if this information is not applicable to source or process From what year is the cctuot cnxulal cmcunt? Design Process Actual Annual Requested Annual Description Rate Amount Permit Limit3 (Specify Units) (Specify Units) {Specify Units) Material Consumption: Finished Product(s): 3Requested values will become permit limitations. Requested limit(s)should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 522877, 4468151 ❑Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Discharge Height Temp. Flow Rate Velocity Stack ID No. Above Ground Level (SF) (ACFM) (ft/sec) (Feet) Flare 65 Indicate the direction of the stack outlet: (check cne) Eli Upward ❑ Downward ❑Upward with obstructing raincap ❑ Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) El Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth(inches): ❑ Cther(describe): Fr',. 7 "2115 31 • Permit Number: 95OPWE038 AIRS ID Number: 123 >0099/ tiss - cd a p_r =a"d, PS ID] Section 6 - Combustion Equipment a Fuel Consumption Information 0 Check box if this information is not applicable to the source(e.g. there is no fuel-burning equipment associated with this emission source) Design Input Rate Actual Annual Fuel Use Requested Annual Permit Limit3 (MMBTUIhr) (Specify Units) (Specify Units) 0.24 2.01 MMscflyr true}only),55.91 G5Modtyr(waste gas) From what year is the actual annual rod use data? Indicate the type of fuel used'': ®Pipeline Natural Gas (assumed fuel heating value of 1,020 8TU/SCF) ❑ Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 8TU/SCF) ❑Coal Heating value: BTU/lb Ash Content: Sulfur Content: CI Other(describe): 55.91 MMscf/yr(Waste Gas) Heating value(give units): 1300 Btu/scf 3 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 4 If fuel heating value is different than the listed assumed value, please provide this information in the"Other"field. Section 7 - Criteria Pollutant Emissions Information Attach alt emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ®Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency(%reduction): Pollutant Control Equipment Description Overall Control Efficiency (%reduction in emissions) TSP (PM) PM10 PM 2.5 Sa x NOx CO VOC Flare 95% Other: V,-J F_. t :;ill' t ,i 4 1r Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ (Leave b cnk unle•t AS(D t.n-3..ca'jy_s!-. a t-- ,.:t- :.-rd'iRS 01 Section 7(continued) From what year is the following reported cc tucl cnrucl emissions data? N/A Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Emission Uncontrolled Requested Annual Permit Factor Actual Annual Emissions Pollutant Emission Emission Limit(s)3 Source Fact(Specify orits)r (AP-42,Mfg. Uncontrolled Controlleds Uncontrolled Controlled etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) TSP(PM) PMtio I PM0.s !I SOX I NO. 0.068 lb/MMBtu AP-42 2.58 2.58 CO 0.31 lb/MMBtu AP-42 11.35 11.35 VOC 14183 lb/MMscf Mass Balance 396.49 19.83 Other: a Requested values will become permit limitations. Requested limit(s)should consider future process growth. sAnnual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. Section 8 - Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP- hazardous air pollutant)emissions equal to or greater than 250 0 Yes ❑ No lbs/year? If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: Uncontrolled Uncontrolled Controlled CAS Overall Emission Emission Factor Actual Actual Chemical Name Control Source Number Factor Emissions Emissions Efficiency (specify units) (AP-42,Mfg.etc) (fbs/year) (ibs/year) 110-54-3 n-hexane 95% 210.2 lb/MMscf Mass Balance 11,749 591 AAnnual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. f r, _ ) %F 7 5 I �C y Permit Number: 95OPWE038 AIRS ID Number: 1 23 /0099/ (ter _ .,.,.{. ,r D s atr,c:.'.>>:.ssj "*�-ct 9 -u it 7 R_]!D1 Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. 17- Ai, /206 Signature of Legally Authorized Person(not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name(please print) Title Check the appropriate box to request a copy of the: E1 Engineer's Preliminary Analysis conducted Draft permit prior to issuance [1] Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised ADEN requirements. Send this form along with$152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Mr Pollution Control Division (303)692-3175 or(303)692-3148 APCD-SS-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 https://www.coloredo.gov/cdphe/apcd Telephone: (303)692-3150 =C_ � i I R,y? Y .i1, 6 �i: Appendix D — Filing Fees for APEN Renewal Submittals Appendix E — APEN Renewal Submittals for C124, C116, C117, C118, C119, C120, C122 AIR POLLUTANT EMISSION NOTICE(APEN) & Application for Construction Permit—Reciprocating Internal Combustion Engine' `i You will be charge an additional APEN fee if APEN is filled out incorrectly or missing information and requires re-submittal. Permit Number: 95OPWE038 [Leave blank unless APCD has already assigned a permit#&AIRS ID] Emission Source AIRS ID: 123 /0099/ 102 Facility Equipment ID: C 124/P 121 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01—Administrative Information Section 02—Requested Action(check applicable request boxes) Company Name: DCP Midstream,LP NAICS,or ❑ Request for NEW permit or newly reported emission source SIC Code: 1311 Source Name: Greeley Natural Gas Processing Plant E Request for coverage under GENERAL PERMIT number GP02(Natural Gas Only) Source Location: SW '/Section 25,T5N,R66W County: Weld ❑ Request MODIFICATION to existing permit(check each box below that applies) Elevation: 4,691 Feet ❑ Change fuel or equipment ❑ Change company name Portable Source ❑ Change permit limit ❑ Transfer of ownership ❑ Other Home Base: ❑ Request PORTABLE source permit Mailing Address: 370 17th Street,Suite 2500 ZIP Code: 80202 ® Request APEN Update Denver,CO Emissions data must he completed. Blank APENs will not be accepted Person To Dana Stephens Phone Number: 303-605-1745 Contact: E-mail Address: dstephens@dcpmidstream.com Fax Number: 303-605-1957 ❑ Notification of AOS permanent replacement Addl. Section 03—General Information Into.Notes:For existing sources,operation began on: 5120/1986 For new or reconstructed sources,the projected startup date is: / / Normal hours of source operation: 24 hours/day 7 days/week 52 weeks/year General description of equipment purpose: Natural Gas Compression Date the engine was ordered: Before 5/1986 Date engine construction commenced: Before 5/1986 Date of any Colorado Department of Public Health and Environment Date the engine was relocated into Colorado: N/A reconstruction/umditication: rr/a Air Pollution Control Division(APCD) Will this equipment be operated in any NAAQS nonattainmcnt area? Don't This notice is valid for five(5)years. Submit a revised ADEN prior to http://www.cdphe.state.co.us/a,/attainniaintain.hnnl) ® Yes ❑ No ❑ know expiration of five-year term, or when a significant change is made (littp://www.cdphe.state.co.us/ap/atta< / p y' b (increase production,new equipment,change in fuel type,etc). Section 04-Engine Information Engine date of manufacture: Before 5/1986 Engine displacement: 11 L/cyl Mail this form along with a check for $152.90 per APEN and $1,500 for each general permit registration to: Manufacturer: Waukesha Model: r-11G Serial No.: 5367457 Colorado Department of Public Health& Environment • APCD-SS-B1 Engine function: O Primary and/or peaking power O Emergency back-up power 4300 Cherry Creek Drive South 0 Compression O Pump jack ❑ Water pump O Other: Denver,CO 80246-1530 For guidance on how to complete this APEN form: Manufacturer's maximum rated horsepower @ sea level: 125 BHP @ 1,500 RPM Air Pollution Control Division: (303)692-3150 Manufacturer's maximum site rating: 125 BHP @ 1,500 RPM kW Small Business Assistance Program(SBAP): (303)692-3148 or Engine Brake Specific Fuel Consumption @ 100%Load: 7,920 Btu/HP-hr (303)692-3175 APEN forms: http://colorado.gov/cdjihc/APENtorilis Cycle Type: O 2-Stroke ® 4-Stroke Combustion: O Lean Burn ® Rich Burn Anolication status:htto://www.coloraclo.gov/cdolie/nennitstatus Ignition Source: ® Spark O Compression Aspiration: ® Natural O Turbocharged O Check box to request copy of draft permit prior to issuance. What is the maximum number of hours this engine is used for emergency back—up power? Hours/year O Check box to request copy of draft permit prior to public notice. FORM APCD-201 Page 1 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit—Reciprocating Internal Combustion Engine' Permit Number: 95OPWE038 Emission Source AIRS ID: 123 /0099/ 102 Section 05—Stack Information (Attach a separate sheet with relevant information in the event of multiple stacks;provide datum&either Lat/Long or UTM) Stack Discharge Operator ( Stack Base Horizontal Datum UTM UTM Fasting or UTM Northing or Method of Collection for Location Height Above Flow Rate Velocity Moisture (NAD27,NAD83, Zone Longitude Latitude Data(e.g.map,GPS, Stack Elevation Temp.(°P) ° g Ground Level (ACFM) (ft/sec) CYO ID No. (feet) WGS84) (12 or 13) (meters or degrees) (meters or degrees) GoogleEarth) (feet) P121 4,691 1 14.6 J, 1,100 615 52 AMB WGS 84 13 522,877 4,468,151 CPS Direction of stack outlet(check one): ® Vertical ❑ Vertical with obstructing raincap ❑ Horizontal ❑ Down ❑ Other(Describe): Exhaust Opening Shape&Size(check one): ® Circular:Inner Diameter(inches)= 6 ❑ Other:Length(inches)= Width(inches)--- Section 06—Fuel Consumption Information Annual Fuel Consumption(gal/yr or MMSCF/yr) Sulfur Seasonal Fuel Use(%of Annual Use) Fuel Use Rate @ 100%load Fuel Heating Value Fuel.Type SCF/hr,gal/hr) Actual Reported for Requested Permit Limit Btu/lb,'Btu/gal,Btu/SCF Content Dec-Feb Mar-Ma Jun- e Nov ( g` Calendar Year —__ q ( ) (%wt.) Y Augg Sep -Nov Natural Gas 952.05 SCF/hr 6.38 MMscf/hr 834 MMscf/yr 1,040 Btu/scf Neg. 25 25 . 25 25 l Is this engine equipped with an Air/Fuel ratio controller? ® Yes ❑ No Section 07—Emissions Inventory Information& Emission Control Information ® Emission Factor Documentation attached Data year for actual calendar yr,emissions below&fuel use above(e.g.2007): 2015 I Requested Permitted Estimation Method Control Device Description Control Emission Factor Actual Calendar Year Emissions` Emissions or Pollutant • Efficiency Uncontrolled Controlled Uncontrolled Controlled Emission Factor Primary Secondary (%Reduction) Uncontrolled Basis Units (Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Source TSP 1.94E-02 lb/MMBtu , 0.07 0.07 1 1. O.US AP-42 PM„} 1.94E-02 lb/MMBtu 0.07 0.07 0.08 0.08 AP-42 PM 2,5 1.94E-02 lb/MMBtu 0.07 0.07 0.08 0.08 AP-42 SOx 5.88E-04 tb/MMBtu 0.002 0.002 0.003 0.003 AP-42 NOx NSCR . 69 2.21 lb/MMBtu 7.89 2.48 9.58 3.02 Manuf. Spec. VOC - 0 0.14 lb/MMBtu 0.50 0.50 0.60 0.60 Manuf Spec. CO NSCR 74 3.72 lb/MMBtu 13.28 3.48 16.13 4.22 Manuf.Spec. Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. I You will be charged an additional APEN fee if APEN is filled out incorrectly or missing information and requires re-submittal. `Annual emission fees will be based on actual emissions reported here.If left blank,annual emission fees will be based on requested emissions. Section 08— 'leant Certification-I hereby certify that all information contained herein and information submitted with this application is complete,true and correct. LI2S 12016 Roshini Shankaran Environmental Engineer Signature of Person Legally Authorized to Supply Data hate Name of Legally Authorized Person(Please print) Title Page 2 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx AIR POLLUTANT EMISSION NOTICE(APEN) & Application for Construction Permit—Reciprocating Internal Combustion Engine' `i You will be charge an additional APEN fee if APEN is filled out incorrectly or missing information and requires re-submittal. Permit Number: 95OPWE038 [Leave blank unless APCD has already assigned a permit#4&AIRS ID] Emission Source AIRS ID: 123/0099/ 103 Facility Equipment ID: Cl 16/P 122 [Provide Facility Equipment ID to identity how this equipment is referenced within your organization.] Section 01—Administrative Information Section 02—Requested Action(check applicable request boxes) Company Name: DCP Midstream,LP NAICS,or ❑ Request for NEW permit or newly reported emission source SIC Code: 1311 Source Name: Greeley Natural Gas Processing Plant ❑ Request for coverage under GENERAL PERMIT number GP02(Natural Gas Only) Source Location: SW'/ Section 25,T5N,R66W County: Weld ❑ Request MODIFICATION to existing permit(check each box below that applies) Elevation: 4,691 Feet ❑ Change fuel or equipment ❑ Change company name • Portable Source ❑ Change permit limit ❑ Transfer of ownership ❑ Other Home Base: ❑ Request PORTABLE source permit Mailing Address: 370 17th Street,Suite 2500 ZIP Code: 80202 ® Request APEN Update Denver,CO Emissions data must be completed. Blank APENs will not be accepted Person To Dana Stephens Phone Number: 303-605-1745 Contact: E-mail Address: dstephens@dcpmidstream.com Fax Number: 303-605-1957 ❑ Notification of AOS permanent replacement Addl. Section 03—General Information Info.& Notes: For existing sources,operation began on: 1 /16/1986 For new or reconstructed sources,the projected startup date is: / Normal hours of source operation: 24 hours/day 7 days/week 52 weeks/year General description of equipment purpose: Refrigeration Date the engine was ordered: Before 1/1986 Date engine construction commenced: Before 1/1986 Date of any Colorado Department of Public Health and Environment Date the engine was relocated into Colorado: Before 1/1 986 reconstruction/modification: n/a Air Pollution Control Division(APCD) Will this equipment be operated in any NAAQS nonattainment area? ❑ Don't This notice is valid for five(5)years. Submit a revised APEN prior to Intp://www.cd lie.state.co.us/a /attainmaintain.html ® Yes ❑ No know expiration of five-year term, or when a significant is made ( 1 P�' ) P Y' g change (increase production,new equipment,change in fuel type,etc). Section 04-Engine Information Mail this form along with a check for $152.90 per APEN and Engine date of manufacture: Before 1/1986 Engine displacement: 9.58 L/cyl $1,500 for each general permit registration to: • Manufacturer: Waukesha Model: L-7042 CSI Serial No.: 368993 Colorado Department of Public Health& Environment APCD-SS-BI Engine function: O Primary and/or peaking power ❑ Emergency back-up power 4300 Cherry Creek Drive South Denver,CO 80246-1530 ® Compression ❑ Pump jack ❑ Water pump ❑ Other: For guidance on how to complete this APEN form: Manufacturer's maximum rated horsepower @ sea level: 1,100 BHP @ 900 RPM Air Pollution Control Division: (303)692-3150 Small Business Assistance Program(SBAP): (303)692-3148 or • Manufacturer's maximum site rating: 1,100 BHP @ 900 RPM kW (303)692-3175 Engine Brake Specific Fuel Consumption @ 100%Load: 8,490 Btu/HP-hr APEN forms:http://colorado.gov/cdphe/APENfortns Cycle Type: ❑ 2-Stroke 0 4-Stroke Combustion: ❑ Lean Burn ® Rich Burl Aonlication status:httn://www.colorado.eov/cdnhe/nermitsrttus Ignition Source: 0 Spark ❑ Compression Aspiration: ❑ Natural ® Turbocharged ❑ Check box to request copy of draft permit prior to issuance. What is the maximum number of hours this engine is used for emergency back—up power? Hours/year ❑ Check box to request copy of draft permit prior to public notice. FORM APCD-201 Page 1 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit—Reciprocating Internal Combustion Engine' Permit Number: 95OPWE038 Emission Source AIRS ID: 123 /0099/ 103 Section 05—Stack Information(Attach a separate sheet with relevant information in the event of multiple stacks;provide datum&either Lat/Long or UTM) Stack Discharg e Operator Stack Base 6 J Horizontal Datum UTM UTM Easting or UTM Northing or Method of Collection for Location Height Above How Rate Velocity Moisture (NAD27,NAD83, Zone Longitude Latitude I Data(e.g.map,GPS, Stack Elevation Ground Level Temp.(°�) (ACFM) g ID No. (feet) (tier) (ft/sec) (%) WGS84) (12 or 13) (meters or degrees) (meters or degrees) GoogleEarth) — P122 4,691 14.6 , 1,100 5,377 114 AMB WCS 84 13 522,877 4,468,151 , GPS Direction of stack outlet(check one): ' Vertical ❑ Vertical with obstructing raincap ❑ Horizontal ❑ Down D Other(Describe): Exhaust Opening Shape&Size(check one): ® Circular: Inner Diameter(inches)= 6 ❑ Other:Length(inches)= Width(inches)_ Section 06—Fuel Consumption Information Annual Fuel Consumption(gal/yr or MMSCF/yr) Sulfur Seasonal Fuel Use(%of Annual Use) Fuel Use Rate ri;; 100%load Fuel Heating Value Fuel Type SCF/hr,Cal/hr, Actual.Reported for Requested Permit Limit (Btu/lb,Btu/gal,Btu/SCF) Content Dec-Feb Mar-May Jun-Au Se Nov ( ) Calendar Year i (%wt.) g Sep -Nov Gas 8,984 SCF/hr 58.75 MMscf/hr 78.7 MMscf/yt- I 1,040 Btu/sef Neg. 25 25 25 25 J Is this engine equipped with an Air/Fuel ratio controller? ® Yes ❑ No Section 07—Emissions Inventory Information& Emission Control Information • ® Emission Factor Documentation attached Data year for actual calendar•yr.emissions below&fuel use above(e.g.2007): I 2015 — _ Requested Permitted Estimation Method Control Device Description Control Emission Factor Actual Calendar Year Emissions Emissions or Pollutant Efficiency Primary Secondary (°&Reduction) Uncontrolled Basis Units Uncontrolled Controlled Uncontrolled Controlled Emission Factor (Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Source TSP 1.94E-02 lb/MMBtu 0.64 0.64 0.79 0.79 AP-42 PM 10 1.94E-02 lb/MMBtu 0.64 0.64 0.79 0.79 AP-42 PM,.5 1.94E-02 lb/MMBtu 0.64 0.64 0.79 0.79 AP-42 SOx 5.88E-04 lb/MMBtu 0.02 0.02 0.02 0.02 AP-42 NOx NSCR 81 13.0 g/hp-hr 111.00 21.35 138.09 26.55 Manuf. Spec. VOC 0 0.5 g/hp-hr 4.27 4.27 5.31 5.31 Manuf.Spec. CO NSCR 72 9.0 g/hp-hr 76.84 21.35 95.60 26.55 Manut: Spec. Formaldehyde NSCR 76 2.05E-02 lb/MMBtu 0.67 0.16 0.84 0.20 AP-42 i I Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. You will be charged an additional APEN fee if APEN is filled out incorrectly or missing information and requires re-submittal. 2 Annual emission fees will be based on actual emissions reported here.If left blank,annual emission fees will be based on requested emissions. Section 08—A licant Certification-I hereby certify that all information contained herein and information submitted with this application is complete,true and correct. / - lk(2_Y/Z0(6 Roshini Shankaran Environmental Engineer Sign at re of Person Legally Authorized to Supply Data Date Name of Legally Authorized Person(Please print) Title Page 2 of 2 Form APCD-201-RICEAPEN-Ver.02.102014.docx AIR POLLUTANT EMISSION NOTICE(APEN) &Application for Construction Permit—Reciprocating Internal Combustion Engine' `'You will be charge an additional APEN fee if APEN is filled out incorrectly or missing information and requires re-submittal. Permit Number: 95OPWE038 [Leave blank unless APCD has already assigneda permit t&AIRS ID] Emission Source AIRS ID: 123/0099/ 104 Facility Equipment ID: C117/P123 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01—Administrative Information Section 02—.Requested Action(check applicable request boxes) Company Name: DCP Midstream,LP NAICS,or ❑ Request for NEW permit or newly reported emission source SIC Code: 1311 Source Name: Greeley Natural Gas Processing Plant ❑ Request for coverage under GENERAL PERMIT number GP02(Natural Gas Only) Source Location: SW 1/4 Section 25,T5N,R66W County: Weld ❑ Request MODIFICATION to existing permit(check each box below that applies) Elevation: 4,691 Feet ❑ Change fuel or equipment ❑ Change company name Portable Source ❑ Change permit limit ❑ Transfer of ownership ❑ Other Home Base: ❑ Request PORTABLE source permit Mailing Address: 370 17th Street,Suite 2500 ZIP Code: 80202 ® Request APEN Update Denver,CO Emissions data Faust be completed Blank/PENS will not be accepted Person To Dana Stephens Phone Number: 303-605-1745 Contact: E-mail Address: dstephens@dcpmidstream.com Fax Number: 303-605-1957 ❑ Notification of AOS permanent replacement Addl. Section 03—General Information Info.& Notes: For existing sources,operation began on: 12/11/2002 For new or reconstructed sources,the projected startup date is: / / Normal hours of source operation: 24 hours/day 7 days/week 52 weeks/year General description of equipment purpose: Natural Gas Compression Date the engine was ordered: Before 12/2002 Date engine construction commenced: Pre 12/2002 Date of any Colorado Department of Public Health and Environment Date the engine was relocated into Colorado: Before 12/2002 reconstruction/modification: n/a Air Pollution Control Division(APCD) Will this equipment be operated in any NAAQS nonattainment area? Don't This notice is valid for five(5)years. Submit a revised APEN prior to (http:Uwww.cdphe.state.co.us/ap/attainmaintain.html) ® Yes ❑ No ❑ know expiration of live-year term, or when a significant change is made (increase production,new equipment,change in fuel type,etc). Section 04—Engine Information Engine date of manufacture: Before 7/5/2005 Engine displacement: 9.58 L/cyl Mail this form along with a check for S152.90 per APEN and Manufacturer: Waukesha Model: L-7042 CSI Serial No.: 898468 $1,500 for each general permit registration to: Colorado Department of Public Health& Environment APCD-SS-BI Engine function: ❑ Primary and/or peaking power ❑ Emergency back-up power 4300 Cherry Creek Drive South ® Compression ❑ Pump jack ❑ Water pump ❑ Other: Denver,CO 80246-1530 For guidance on how to complete this APEN form: Manufacturer's maximum rated horsepower @ sea level: 1,100 BHP(/t 900 RPM Air Pollution Control Division: (303)692-3150 Manufacturer's maximum site rating: 1,100 BHP @ 900 RPM kW Small Business Assistance Program(SBAP): (303)692-3148 or Engine Brake Specific Fuel Consumption @ I00%Load: 8,490 Btu/HP-ht (303)692-3175 APEN forms:fifth://colorado.wv/cdohe/APENt rms Cycle Type: ❑ 2-Stroke ® 4-Stroke Combustion: ❑ Lean Burn ® Rich Bum Aonlication status:htto://www.colorado.cov/cdnhe/ocrmitstatus Ignition Source: ® Spark . ❑ Compression Aspiration: ❑ Natural ® Turbocharged D Check box to request copy of draft permit prior to issuance. What is the maximum number of hours this engine is used for emergency back—up power? Hours/year ❑ Check box to request copy of draft permit prior to public notice. FORM APCD-201 Page 1 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit—Reciprocating Internal Combustion Engines Permit Number: 95OPWE038 Emission Source AIRS ID: 123 /0099/ 104 Section 05—Stack Information(Attach a separate sheet with relevant information in the event of multiple stacks;provide datum&either Lat/Long or UTM) Stack Discharge Operator Stack Base Horizontal Datum UrM UTM Fasting or UTM Northing or Method of Collection for Location 1 Height Above Flow Rate Velocity Moisture ? Stack Elevation Temp.(°P) o (NAD_7,NAD83, Zone Longitude I Latitude Data(e.g.map,GPS, ID No. (feet) Ground Level (ACFM) (ltisec) (%) WGS84) (12 or 13) (meters or degrees) I (meters or degrees) GoogleEarth) (feet) P123 4,691 ( 26 1,055 5,377 114 AMB WGS 84 L 13 522,877 4,468,151 GPS Direction of stack outlet(check one): ® Vertical E Vertical with obstructing raincap ❑ Horizontal E Down E Other(Describe): Exhaust Opening Shape&Size(check one): ® Circular:Inner Diameter(inches)= 12 ❑ Other:Length(inches)= Width(inches)_ Section 06—Fuel Consumption Information Annual Fuel Consumption(gal/yr or MMSCF/yr) Sulfur Seasonal Fuel Use(%of Annual Use) Fuel Use Rate @ 100%load Fuel Heating Value Fuel Type SCF/hr,gal/hr) Actual Reported for Requested Permit Limit Btu/Ib,Btu/gal,Btu/SCF) Content Dec-Feb Mar-May Jun-Au Se Nov (SCF/hr, Calendar Year ( (%wt.) g Sep -Nov Natural Gas 8,984 SCF/hr j 59.62 MMscf/hr j_ 78.7 MMsctlyr 1,040 Btu/scf Neg. 25 25 25 25 Is this engine equipped with an Air/Fuel ratio controller? ® Yes ❑ No Section 07—Emissions Inventory Information& Emission Control Information ® Emission Factor Documentation attached Data year for actual calendar yr.emissions below&fuel use above(e.g.2007): I 2015_ _ _ _ Control Device Description Control Emission Factor Actual Calendar Year Emissions' Requested Permitted Estimation Method Pollutant •--- - - - - Efficiency Emissions or Primary Secondary (%Reduction) Uncontrolled Basis Units Uncontrolled Controlled Uncontrolled Controlled Emission Factor (Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Source TSP 1.94E-02 lb/MMBtu 0.65 0.65 0.79 0.79 AP-42 PMio 1.94E-02 lb/MMBtu 0.65 0.65 0.79 0.79 AP-42 PMT; 1.94E-02 lb/MMBtu 0.65 0.65 0.79 0.79 AP-42 SOx 5.88E-04 lb/MMBtu 0.02 0.02 0.02 0.02 AP-42 NOx NSCR 81 13.0 g/hp-hr 112.64 21.7 138.09 26.6 Manuf. Spec. VOC - 0 0.5 g/hp-hr 4.33 4.33 5.31 531 Manuf Spec. CO NSCR 72 9.0 g/hp-hr 77.98 21.7 95.60 26.6 Manuf Spec. Formaldehyde NSCR 76 2.05E-02 lb/MMBtu 0.68 0.16 0.84 0.20 AP-42 Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. r You will be charged an additional APEN fee if APEN is filled out incorrectly or missing information and requires re-submittal. `Annual emission lees will be based on actual emissions reported here.If left blank,annual emission fees will be based on requested emissions. Section 08—Applicant Certification-I hereby certify that all information contained herein and information submitted with this application is complete,true and correct. -1--/Z8/2O6 Roshini Shankaran Environmental> ngineer Signature of Person Legally Authorized to Supply Data Date Name of Legally Authorized Person(Please print) Title Page 2 of 2 Form APC D-201-RICEAPEN-Ver.02.10.2014.docx AIR POLLUTANT EMISSION NOTICE (APEN) &Application for Construction Permit—Reciprocating Internal Combustion Engine1 `'You will be charge an additional ADEN fee if APEN is filled out incorrectly or missing information and requires re-submittal. Permit N umber: 95OPWE038 [Leave blank unless APCD has already assigned a permit#&AIRS 1D] Emission Source AIRS ID: 123/0099 I 105 Facility Equipment ID: CI 18/P 124 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01—Administrative information Section 02—Requested Action(check applicable request boxes) Company Name: DCP Midstream,LP NAICS,or ❑ Request for NEW permit or newly reported emission source SIC Code: 1311 • Source Name: Greeley Natural Gas Processing Plant ❑ Request for coverage under GENERAL PERMIT number GP02(Natural Gas Only) Source Location: SW V.Section 25,T5N,R66W County: Weld ❑ Request MODIFICATION to existing permit (check each box below that applies) Elevation: 4,691 Feet ❑ Change fuel or equipment ❑ Change company name Portable Source ❑ Change permit limit ❑ Transfer of ownership D Other Home Base: ❑ Request PORTABLE source permit Mailing Address: 370 17th Street,Suite 2500 • ZIP Code: 80202 ® Request APEN Update Denver,CO Emissions data must he completed. Blank APENs will not be accepted Person To Dana Stephens Phone Number: 303-605-1745 Contact: E-mail Address: dstephens@dcpmidstream.com Fax Number: 303-605-1957 ❑ Notification of AOS permanent replacement Addl. Info.& Section 03—General Information Notes: For existing sources,operation began on: 2/19/2003 For new or reconstructed sources,the projected startup date is: / / Normal hours of source operation: 24 hours/day 7 days/week 52 weeks/year General description of equipment purpose: Natural Gas Compression Date the engine was ordered: Before 4/1975 Date engine construction commenced: 1975 Date of any Colorado Department of Public Health and Environment Date the engine was relocated into Colorado: Before 4/1975 n/a reconstruction/modification: Air Pollution Control Division(APCD) Will this equipment be operated in any NAAQS nonattainment area? Don't This notice is valid for five(5)years. Submit a revised APEN prior to (http://www.cdphc.state.co us/ap/attainmaintain.html) ® Yes ❑ No ❑ know expiration of five-year term, or when a significant change is made (increase production,new equipment,change in fuel type,etc). Section 04—Engine Information Engine date of manufacture: 4/9/ 1975 Engine displacement: 9.58 L/cyl Mail this form along with a check for $152.90 per APEN and $1,500 for each general permit registration to: Manufacturer: Waukesha Model: L-7042 GSI Serial No.: 286434 Colorado Department of Public Health& Environment APCD-SS-B1 Engine function: ❑ Primary and/or peaking power D Emergency back-up power 4300 Cherry Creek Drive South ® Compression ❑ Pump jack ❑ Water pump ❑ Other: Denver,CO 80246-1530 For guidance on how to complete this APEN f,.rm: Manufacturer's maximum rated horsepower fa sea level: 1,567 BHP @ 1,200 RPM Air Pollution Control Division: (303)692-3150 Manufacturer's maximum site rating: 1,100 BHP @ 1,200 RPM kW Small Business Assistance Program(SBAP): (303)692-3148 or Engine Brake Specific Fuel Consumption(a; 100%Load: 8,490 Btu/HP-hr (303)692-3175 APEN forms:hitp://colorndo.gov/cdplie/AP ENfbrms Cycle Type: O 2-Stroke ® 4-Stroke Combustion: O Lean Burn ® Rich Burn Application status:http://www.colorado.eov/cdohe/oermitstatus Ignition Source: ® Spark O Compression Aspiration: O Natural ® Turbocharged ❑ Check box to request copy of draft permit prior to issuance. What is the maximum number of hours this engine is used for emergency back—up power? Hours/year ❑ Check box to request copy of draft permit prior to public notice. FORM APCD-201 Page 1 of 2 Form APCD-201-RICEAPEN-Ver.02.102014.docx AIR POLLUTANT EMISSION NOTICE (APEN) &Application for Construction Permit— Reciprocating Internal Combustion Engines Permit Number: 95OPWE038 Emission Source AIRS ID: 123/0099 / 105 Section 05—Stack Information(Attach a separate sheet with relevant information in the event of multiple stacks;provide datum&either Lat/Long or UTM) Stack Discharge Operator Stack Base Horizontal Datum UTM LTM Fasting or UTM Northing or Method of Collection for Location Height Above How Rate Velocity Moisture Stack Elevation g Temp.(°F) (NAD27,NAD83, Zone Longitude Latitude Data(e.g.map,GPS, ��) ID No. (feet) o WGS84) (12 or 13) (meters or degrees) (meters or degrees) GoogleEarth) _ (feet) P124 4,691 26 1,055 5,377 114 AMB WGS 84 13 522,877 4,468,151 GPS Direction of stack outlet(check one): ® Vertical ❑ Vertical with obstructing raincap ❑ Horizontal ❑ Down ❑ Other(Describe): Exhaust Opening Shape&Size(check one): ® Circular:Inner Diameter(inches)= 12 E Other:Length(inches)= Width(inches)_ Section 06—Fuel Consumption Information Annual Fuel Consumption(gal/yr or MMSCF/yr) Sulfur Seasonal Fuel Use(%of Annual Use) Fuel Use Rate @ 100%load Fuel Pleating Value Fuel Type SCF/hr,gal/hr) Actual Reported for Requested Permit Limit (Btu/lb,Btu/ al,Btu/SCF) Dec-Feb Mar-May Jun-Aug Se Nov (SCF/hr, Calendar Year qg ) (%wt.) Jun-Aug P { Natural Gas 8,984 SCF/hr 59.8 MMscf/hr I 78.7 MMscf/yr 1,040 Btu/scf Neg. I 25 I- 25 25 25 Is this engine equipped with an Air/Fuel ratio controller? ® Yes ❑ No Section 07—Emissions Inventory Information& Emission Control Information E Emission Factor Documentation attached Data year for actual calendar yr.emissions below&fuel use above(e.g.2007): 2015 IL__ __ _._-_-. Requested Permitted Estimation Method Control Device Description Control Emission Factor Actual Calendar Year Emissions` j Emissions or Pollutant Efficiency Uncontrolled Controlled Uncontrolled Controlled Emission Factor Primary Secondary (%Reduction) Uncontrolled Basis Units (Tons/Year) (Tons/Year) Ions/Year) (Tons/Year) Source TSP 1.94E-02 lb/MMBtu 0.65 0.65 0.79 0.79 AP-42 PM,() -_- 1.94E-02 lb/MMBtu 0.65 0.65 0.79 0.79 AP-42 PM2 5 1.94E-02 lb/MMBtu 0.65 0.65 0.79 0.79 AP-42 SOx 5.88E-04 lb/MMBtu 0.02 0.02 0.02 0.02 AP-42 NOx NSCR 81 13.0 g/hp-hr 112.95 21.7 138.09 26.6 Manuf.Spec. VOC - 0 0.5 g/hp-hr 4.34 4.34 5.31 5.31 Manuf:Spec. CO NSCR 72 9.0 g/hp-hr 78.20 21.7 95.60 26.6 Manuf:Spec. Formaldehyde NSCR 76 2.05E-02 lb/MMBtu 0.69 0.16 0.84 0.20 AP-42 r Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. i You will be charged an additional APEN fee if APEN is filled out incorrectly or missing information and requires re-submittal. 1 Annual emission fees will be based on actual emissions reported here.[flat blank,annual emission fees will be based on requested emissions. • Section 08—A licant Certification-I hereby certify that all information contained herein and information submitted with this application is complete,true and correct. f L12 2-O6 Rosl>ini Shankaran Environmental Engineer Signal e of Person Legally Authorized to Supply Data Date Name of Legally Authorized Person(Please print) Title Page 2 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit—Reciprocating Internal Combustion Engine' `'You will be charge an additional APEN fee if APEN is filled out incorrectly or missing information and requires re-submittal. Permit Number: 95OPWE038 [Leave blank unless APCD has already assigned a permit€f&AIRS ID] Emission Source AIRS ID: 123 /0099/ 106 Facility Equipment ID: Cl 19/P 125 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01—Administrative Information Section 02—Requested Action(check applicable request boxes) Company Name: DCP Midstream,LP NA1CS,or E Request for NEW permit or newly reported emission source SIC Code: 1311 T Source Name: Greeley Natural Gas Processing Plant ❑ Request for coverage under GENERAL PERMIT number GP02(Natural Gas Only) Source Location: SW '/Section 25,T5N,R66W County: Weld ❑ Request MODIFICATION to existing permit(check each box below that applies) Elevation: 4,691 Feet D Change fuel or equipment ❑ Change company name Portable Source ❑ Change permit limit ❑ Transfer of ownership ❑ Other Home Base: ❑ Request PORTABLE source permit Mailing Address: 370 17th Street,Suite 2500 ZIP Code: 80202 ® Request APEN Update Denver,CO Emissions data must be completed. Blank APENs will not be accepted Person To Dana Stephens Phone Number: 303-605-1745 Contact: E-mail Address: dstephensldepmidstream.com Fax Number: 303-605-1957 ❑ Notification of AOS permanent replacement Addl. Section 03—General Information Info.& Notes: For existing sources,operation began on: 5/30/2001 For new or reconstructed sources,the projected startup date is: / / Normal hours of source operation: 24 hours/day 7 days/week 52 weeks/year General description of equipment purpose: Natural Gas Compression Date the engine was ordered: Before 1986 Date engine construction commenced: Before 1986 Date of an Colorado Department of Public Health and Environment Date the engine was relocated into Colorado: Before 2007 reconstruction/modification n/`t Air Pollution Control Division(APCD) Will this equips cnt be operated in any NAAQS nonattainment area? ® Yes ❑ No ❑ Don't This notice is valid for five(5)years. Submit a revised APEN prior to (http://www.cdphe.state.co.us/ap/attainmaintain.html) know expiration of five-year term, or when a significant change is made (increase production,new equipment,change in fuel type,etc). Section 04-Engine Information Engine date of manufacture: 3/1/ 1974 Engine displacement: 9.58 L/cyl Mail this form along with a check for $152.90 per APEN and $1,500 for each general permit registration to: Manufacturer: Waukesha Model: L-7042 GS' 261947 Colorado Department of Public Health& Environment APCD-SS-BI Engine function: ❑ Primary and/or peaking power ❑ Emergency back-up power 4300 Cherry Creek Drive South ® Compression ❑ Pump jack ❑ Water pump ❑ Other: Denver,CO 80246-1530 For guidance on how to complete this APEN form: Manufacturer's maximum rated horsepower @ sea level: 1,100 BHP cc, 900 RPM Air Pollution Control Division: (303)692-3150 Manufacturer's maximum site rating: 1,100 BHP @ 900 RPM kW Small Business Assistance Program(SBAP): (303)692-3148 or Engine Brake Specific Fuel Consumption _/ 100%Load: 8,490 Btu/HP-hr (30 )692-3175 (i APEN forms:http://colorado.gov/cdphe/APENforms Cycle Type: ❑ 2-Stroke ® 4-Stroke Combustion: ❑ Lean Bum ® Rich Burn Annlication status:httn://www.colorado.eov/cdphe/ocrmitstatus Ignition Source: ® Spark ❑ Compression Aspiration: ❑ Natural ® Turbocharged ❑ Check box to request copy of draft permit prior to issuance. What is the maximum number of hours this engine is used for emergency back—up power? Flours/year ❑ Check box to request copy of draft permit prior to public notice. FORM APCD-201 Page 1 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit— Reciprocating Internal Combustion Engine' Permit Number: 95OPWE038 Emission Source AIRS ID: 123/0099/ 106 Section 05—Stack Information(Attach a separate sheet with relevant information in the event of multiple stacks;provide datum&either Lat/Long or UTM) Stack Discharge Operator Stack Base Horizontal Datum UTM UTM Basting or UTM Northing or Method of Collection for Location Stack Elevation Height Above Temp.(°F) Flow Rate Velocity Moisture (NAD27,NAD83, Zone Longitude. Latitude Data(e.g.map,GPS, ID No. (feet) Ground Level (ACFM) ((t sec) ( °) WGS84 (12 or 13) (meters or degrees) (meters or degrees) GoogleEarth) (feet) ) b ) gr" ) P125 4,691 26 1,055 [ 5,377 114 AMB WGS 84 13 522,877 4,468,151 GPS I Direction of stack outlet(check one): ® Vertical ❑ Vertical with obstructing raineap ❑ Horizontal ❑ Down ❑ Other(Describe): Exhaust Opening Shape&Size(check one): ® Circular: Inner Diameter(inches)= 12 ❑ Other:Length(inches)= Width(inches)_ Section 06—Fuel Consumption Information Annual Fuel Consumption(gal/yr or MMSCF/yr) Sulfur Seasonal Fuel Use(%of Annual Use) Fuel Use Rate(a; 100%load Fuel Heating Value Fuel Type Actual Repotted for o Content (SCF/hr,gal/hr) Calendar Year Requested Permit Limit (Btu/lb,Btu/gal,Btu/SCF) (a/o ) Dec-Feb Mar-May Jun-Aug Sep-Nov Natural Gas 8,984 SCF/hr 58.79 MMscf/hr 75.7 IVIMscf/yr 1,040 Btu/scf Neg. 25 25 L 25 25 Is this engine equipped with an Air/Fuel ratio controller'' ® Yes ❑ No Section 07—Emissions Inventory Information& Emission Control Information ® Emission Factor Documentation attached Data year for actual calendar yr.emissions below&fuel use above(e.g.2007): 2015 I Requested Permitted Estimation Method Control Device Description Control Emission Factor Actual Calendar Year Emissionsz l Emissions or Pollutant Efficiency Primary Secondary (%Reduction) Uncontrolled Basis Units Uncontrolled Controlled Uncontrolled Controlled Emission Factor _ (Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Source TSP 1.94E-02 lb/MMBtu 0.64 0.64 0.79 0.79 AP-42 PM;0 1.94E-02 ib/MMBtu 0.64 0.64 0.79 0.79 AP-42 PM2 s 1.94E-02 lb/MMBtu 0.64 0.64 0.79 0.79 AP-42 SOX 5.88E-04 lb/MMBtu 0.019 0.019 0.024 0.024 AP-42 NOx NSCR 85 13.0 g/hp-hr 111.05 17.09 138.09 21.24 Manua:Spec. VOC - 0 0.5 g/hp-hr 4.27 4.27 5.31 5.31 Manuti Spec. CO NSCR 72 9.0 g/hp-hr 76.88 21.36 95.60 26.55 Manuf: Spec. Formaldehyde NSCR 76 2.05E-02 lb/MMBtu 0.67 0.16 0.84 0.20 AP-42 Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. r You will be charged an additional APEN fee if APEN is filled out incorrectly or missing information and requires re-submittal. 'Annual emission tees will be based on actual emissions reported here.If left blank,annual emission tees will be based on requested emissions. Section 08—Ap licant Certification-I hereby certify that all information//co�o//ntained herein and information submitted with this application is complete,true and correct. �/� L�-- 2 - I2Qb Roshini Shankaran Environmental Engineer Signatu e of Person Legally Authorized to Supply Data Date Name of Legally Authorized Person(Please print) Title Page 2 oft Form APCD-201-RICEAPEN-Ver.02.10.2014.docs AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit—Reciprocating Internal Combustion Engine' ri You will be charge an additional APEN fee if APEN is filled out incorrectly or missing information and requires re-submittal. Permit Number: 95OPWE038 [Leave blank unless APCD has already assigned a permit#&AIRS ID] Emission Source AIRS ID: 123 /0099/107 • Facility Equipment ID: C120/P 126 [Provide Facility Equipment ID to identity how this equipment is referenced within your organization.] Section 01—Administrative Information Section 02—Requested Action(check applicable request boxes) Company Name: DCP Midstream,LP NAICS,or ❑ Request for NEW permit or newly reported emission source SIC Code: 1311 Source.Name: Greeley Natural Gas Processing Plant ❑ Request for coverage under GENERAL PERMIT number GP02(Natural Gas Only) Source Location: SW 1/4 Section 25,TSN,R66W County: Weld ❑ Request MODIFICATION to existing permit(check each box below that applies) Elevation: 4,691 Feet ❑ Change fuel or equipment ❑ Change company name Portable Source ❑ Change permit limit ❑ Transfer of ownership ❑ Other Home Base: ❑ Request PORTABLE source permit Mailing Address: 370 17th Street,Suite 2500 ZIP Code: 80202 ® Request APEN Update Denver,CO Emissions data must be completed Blank APENs will not be accepted Person To Dana Stephens Phone Number: 303-605-1745 Contact: E-mail Address: dstephens(i>dcpmidstream.com Fax Number: 303-605-1957 ❑ Notification of AOS permanent replacement Addl. Section 03—General Information Info.& Notes: . For existing sources,operation began on: 1/14/1986 For new or reconstructed sources,the projected startup date is: / / Normal hours of source operation: 24 hours/day 7 days/week 52 weeks/year General description of equipment purpose: Natural Gas Compression Date the engine was ordered: Before 1986 Date engine construction commenced: Before 1986 Date of any Colorado Department of Public Health and Environment Date the engine was relocated into Colorado: Before 1986 reconstruction/modification: °/`t Air Pollution Control Division(APCD) Will this equipment be operated in any NAAQS nonattainment area? ❑ No ❑ Don't This notice is valid for five(5)years. Submit a revised APEN prior to (bath://www.edphe.state.co.us/ap/attainmaintain.html) ® Yes know expiration of five-year term, or when a significant change is made (increase production,new equipment,change in fuel type,etc). Section 04—Engine Information Mail this form along with a check for $152.90 per APEN and Engine date of manufacture: 10/15/79 Engine displacement: 9.58 L/cyl $1,500 for each general permit registration to: Manufacturer: Waukesha Model: L-7042 GSI Serial No.: 337569 Colorado Department of Public Health& Environment —— APCD-SS-B1 Engine function: 4300 Cherry Creek Drive South g ❑ Primary and/or peaking power ❑ Emergency back-up power Denver,CO 80246-1530 ® Compression ❑ Pump jack ❑ Water pump ❑ Other: For guidance on how to complete this APEN form: Air Pollution Control Division: (303)692-3150 Manufacturer's maximum rated horsepower @ sea level: 1,100 BHP @ 900 RPM Small Business Assistance Program(SBAP): (303)692-3148 or Manufacturer's maximum site rating: 1,100 BHP @ 900 RPM kW (303)692-3175 Engine Brake Specific Fuel Consumption @ 100%Load: 8,490 Btu/HP-hr APEN forms:http://colorado.gov/edphe/AP EN forms Cycle Type: ❑ 2-Stroke ® 4-Stroke Combustion: ❑ Lean Burn ® Rich Burn Anolication status:httu://www.colorado.eov/cdohe/nermitstatus i Ignition Source: ® Spark ❑ Compression Aspiration: ❑ Natural ® Turbocharged ❑ Check box to request copy of draft permit prior to issuance. What is the maximum number of hours this engine is used for emergency back--up power? Hours/year ❑ Check box to request copy of draft permit prior to public notice. FORM APCD-201 Page 1 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit— Reciprocating Internal Combustion Engine' Permit Number: 95OPWE038 Emission Source AIRS ID: 123/0099 / 107 Section 05—Stack Information(Attach a separate sheet with relevant information in the event of multiple stacks;provide datum&either Lat/Long or UTM) — j Stack Discharge Operator Stack Base Horizontal Datum UTM UTM Fasting or UTM Northing or Method of Collection for Location y Height Moisture Stack Elevation Temp.( F) o (NAD27,NAD83, Zone Longitude Latitude Data(e.g.map,GPS, ID No. (feet) �) WGS84) (12 or 13) (meters or degrees) (meters or degrees) GoogleEarth) (feet) — - C120/P126 4,691 28 1,055 5,377 114 AMB WGS84 1 13 522,877 4,468,151 GPS Direction of stack outlet(check one): ® Vertical ❑ Vertical with obstructing raincap ❑ Horizontal Cl Down ❑ Other(Describe): Exhaust Opening Shape&Size(check one): ® Circular: Inner Diametcr(inches)= 12 E Other: Length(inches)= Width(inches)_ Section 06—Fuel Consumption Information Annual Fuel Consumption(gal/yr or MMSCF/yr) Sulfur Seasonal Fuel Use(%of Annual Use) Fuel Use Rate @ 100%load Fuel Heating Value Fuel Type SCF/hr,gal/hr) Actual Reported for Requested Permit Limit (Btu/lb,Btu/gal,Btu/SCF) Content Dec-Feb Mar-May Jun-Aug Se Nov (SCF/hr, ) Calendar Year q g` > (%wt.) Sep -Nov Natural Gas I 8,984 SCF/hr 59.0 MMscf/hr 78.7 MMscf/yr I 1,040 Btu/scf I Neg. I 25 I 25 I 25 I 25 I Is this engine equipped with an Air/Fuel ratio controller? ® Yes ❑ No Section 07—Emissions Inventory Information& Emission Control Information El Emission Factor Docurne7tation attached Data year for actual calendar yr.emissions below&fuel use above(e.g.2007): 2015 Requested Permitted Estimation Method Control Device Description Control Emission Factor Actual Calendar Year Emissions' Emissions or Pollutant Efficiency Uncontrolled Controlled Uncontrolled Controlled Emission Factor Primary Secondary (%Reduction) Uncontrolled Basis Units (Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Source TSP 1.94E-02 lb/MMBtu 0.64 0.64 0.79 0.79 AP-42 PM,,, 1.94E-02 lb/MMBtu 0.64 0.64 0.79 0.79 AP-42 PM,; 1.94E-02 lb/MMBtu 0.64 0.64 0.79 0.70 AP-42 SON 5.88E-04 lb/MMBtu 0.019 0.019 0.024 0.024 AP-42 - NON NSCR 81 13.0 g/hp-hr 111.45 21.43 138.09 26.55 Manut:Spec. VOC - 0 0.5 g/hp-hr 4.29 4.29 5.31 5.31 Manu£ Spec. CO NSCR 72 9.0 g/hp-hr 77.15 21.43 95.60 26.55 Manu£ Spec. Formaldehyde NSCR 76 2.05E-02 Ib/MMBtu 0.68 0.16 0.84 0.20 AP-42 _ Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. _ You will be charged an additional APEN fee if APEN is filled out incorrectly or missing information and requires re-submittal. `Annual emission fees will be based on actual emissions reported here.If left blank,annual emission fees will be based on requested emissions. Section 08—Ap licant Certification-I hereby certify that all information contained herein and information submitted with this application is complete,true and correct. (23 I2 6 Roshini Shankaran Environmental Engineer Signature of Person Legally Authorized to Supply Data D�te Name of Legally Authorized Person(Please print) Title Page 2 of 2 Form APCD-201-RICEAPEN-Ver.02.102014.docx AIR POLLUTANT EMISSION NOTICE(APEN) & Application for Construction Permit—Reciprocating Internal Combustion Engine' `'You will be charge an additional APEN fee if APEN is filled out incorrectly or missing information and requires re-submittal. Permit Number: 95OPWE038 [Leave blank unless APCD has already assigned a permit#&AIRS ID] Emission Source AIRS ID: 123/0099/ 110 Facility Equipment ID: C122/P129 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01—Administrative Information Section 02—Requested Action(check applicable request boxes) Company Name: DCP Midstream,LP NAICS,or ❑ Request for NEW permit or newly reported emission source SIC Code: 1311 J Source Name: Greeley Natural Gas Processing Plant ❑ Request for coverage under GENERAL PERMIT number GP02(Natural Gas Only) Source Location: SW 1/4 Section 25,T5N,R66W County: Weld ❑ Request MODIFICATION to existing permit (check each box below that applies) Elevation: 4,691 Feet ❑ Change fuel or equipment ❑ Change company name Portable Source ❑ Change permit limit ❑ Transfer of ownership ❑ Other Home Base: ❑ Request PORTABLE source permit Mailing Address: 370 17th Street,Suite 2500 ZIP Code: 80202 0 Request APEN Update Denver,CO Emissions data must be completed Blank APENs will not he accepted Person To Dana Stephens Phone Number: 303-605-1745 Contact: E-mail Address: dstephens@dcpmidstream.com Fax Number: 303-605-1957 ❑ Notification of AOS permanent replacement Addl. Section 03—General Information Note N Sc Notes: For existing sources,operation began on: 4/14/2006 For new or reconstructed sources,the projected startup date is: i / Normal hours of source operation: 24 hours/day 7 clays/week 52 weeks/year General description of equipment purpose: Natural Gas Compression Date the engine was ordered: Before 4/2006 Date engine construction commenced: Before 4/2006 Date the engine was relocated into Colorado: Before 4/2006 Date of any Ilia Colorado Department of Public Health and Environment reconstruction/modification: Air Pollution Control Division{APCD) Will this equipment be operated in any NAAQS nonattainment area'' ® Yes ❑ No ❑ Don't This notice is valid for five (5)years. Submit a revised APEN prior to (http://www.cdphe.state.co.us/ap!attainmaintain.htmI) know expiration of five-year term, or when a significant change is made (increase production,new equipment,change in fuel type,etc). Section 04—Engine Information Engine date of manufacture: Before 4/2006 Engine displacement: 9.58 Ucyl Mail this form along with a check for $152.90 per APEN and $1,500 for each general permit registration to: Manufacturer: Waukesha Model: L-7042 GS! 260928 Colorado Department of Public Health& Environment APCD-SS-B1 Engine function: ❑ Primary and/or peaking power ❑ Emergency back-up power 4300 Cherry Creek Drive South ® Compression ❑ Pump jack ❑ Water pump ❑ Other: Denver,CO 80246-1530 For guidance on how to complete this APEN form: Manufacturer's maximum rated horsepower @ sea level: 1,100 BHP @ 1,100 RPM Air Pollution Control Division: (303)692-3150 Manufacturer's maximum site rating: 1,100 BHP @ 1,100 RPM kW Small Business Assistance Program(SBAP): (303)692-3148 or Engine Brake Specific Fuel Consumption @ 100%Load: 8,491 Btu/HP-ht (303)692-3175 APEN forms:littp://colorado.gov/cdphe/APENforms Cycle Type: ❑ 2-Stroke ❑ 4-Stroke Combustion: ❑ Lean Burn ® Rich Burn Application status:htto://www.colorado.eov/cdnhe/ocrmitstatus Ignition Source: ® Spark ❑ Compression Aspiration: D Natural ® Turbocharged ❑ Check box to request copy of draft permit prior to issuance. What is the maximum number of hours this engine is used for emergency hack—up power? Hours/year ❑ Check box to request copy of draft permit prior to public notice. FORM APCD-201 Page 1 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit— Reciprocating Internal Combustion Engines Permit Number: 95OPWE038 • Emission Source AIRS ID: 123/0099/ 110 Section 05—Stack Information(Attach a separate sheet with relevant information in the event of multiple stacks;provide datum&either Lat/Long or UTM) Stack Discharge Operator Stack Base Horizontal Datum UTM UTM Easting or UTM Northing or Method of Collection for Location Height Above How Rate Velocity Moisture Stack Elevation Temp.(19 (NAD27,NAD83, Zone Longitude Latitude Data(e.g.map,GPS, Ground Level (ACFM) (tUsec) (/o) ID No. (feet) (feet) WGS84) (12 or 13) (meters or degrees) (meters or degrees) GoogleEarth) 1 P129 4,691 26.86 1,055 5,377 114 AMB WGS84 13 522,877 4,468,151 GPS Direction of stack outlet(check one): ® Vertical ❑ Vertical with obstructing raincap ❑ Horizontal ❑ Down ❑ Other(Describe): Exhaust Opening Shape&Size(check one): ® Circular:Inner Diameter(inches)= 12 ❑ Other:Length(inches)= Width(inches)_ Section 06—Fuel Consumption Information Annual Fuel Consumption(gal/yr or MIVISCF/yr) Sulfur Seasonal Fuel Use(%of Annual Use) Fuel Use Rate( ), 100%load Fuel Heating Value Fuel Type SCF/hr,gal/hr) Actual Reported for Requested Permit LimitContent ( ) _ Calendar Year 1 (Btu/lb,Btu/gal,Btu/SCF) (ova wt.) ) Dec-Feb Mar-May Jun-Aug Sep-Nov Natural Gas 8,984 SCF/hr I 59.35 MMViscf/hr I 78.7 MMscf/yr 1,040 Btu/scf ^ Neg. 25 25 25 25 Is this engine equipped with an Air/Fuel ratio controller? ® Yes E No • Section 07—Emissions Inventory Information& Emission Control Information Ei Emission Factor Documentation attached Data year for actual calendar yr.emissions below&fuel use above(e.g.2007): 2015 • • • • Requested '° Estimation Method Control Device Description Control E Emissions or Pollutant Efficiency Uncontrolled Controlled Uncontrolled Controlled Emission Factor Primary Secondary (%Reduction) Uncontrolled Basis Units • • Source TSP 1.94E-02 lb/MMBtu 0.64 0.64 0.79 0.79 AP-42 PM i{; 1.94E-02 lb/MMBtu 0.64 0.64 0.79 0.79 AP-42 PM-; 1.94E-02 lb/MMBtu 0.64 0.64 0.79 0.79 AP-42 SOx 5.88E-04- lb/MMBtu 0.020 0.020 0.024 0.024 AP-42 NOx NSCR 85 13.0 g/hp-hr 112.12 21.6 138.09 26.6 Manuf Spec. VOC - 0 0.5 g/hp-hr 4.31 4.31 5.31 5.31 Manuf Spec. CO NSCR 72 9.0 g/hp-hr 77.62 21.6 95.60 26.6 Manuf. Spec. Formaldehyde NSCR 76 2.05E-02 lb/MMBtu 0.68 0.16 0.84 0.20 AP-42 Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. You will be charged an additional APEN fee if APEN is filled out incorrectly or missing information and requires re-submittal. Q 2 Annual emission fees will be based on actual emissions reported here.If left blank,annual emission fees will be based on requested emissions. Section 08— licant Certification-I hereby certify that all information contained herein and information submitted with this application is complete,true and correct. (2 (2 016/C Roshini Shankaran Environmental Engineer Signature of Person Legally Authorized to Supply Data Date Name of Legally Authorized Person(Please print) Title Page 2 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx Appendix F — Operating Permit Application Forms 1 Operating Permit Application FACILITY IDENTIFICATION FORM 2000-100 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name Name Greeley Natural Gas Processing and Plant mailing Street or Route 3009 West 44°i Avenue address City, State, Zip Greeley, Weld County, 80631 Code 2. Facility location Street Address 3009 West 44th Avenue (No P.O. Box) City,County, Zip Greeley, Weld County, 80631 Code 3. Parent Name DCP Midstream, LP corporation Street or Route 370 17th Street, Suite 2500 City, State, Zip Denver, Colorado, 80202 Code Country (if not U.S.) 4. Responsible Name William L. Johnson official Title Vice President of Operations Telephone 303-605-1752 5. Permit contact Name Roshini Shankaran person Title Environmental Engineer (If Different than 4) Telephone 303-605-2039 6. Facility SIC code: 1321 7. Facility identification code: CO 123-0099 8. Federal Tax I. D. Number: 84-1041166 9. Primary activity of the operating establishment: Natural Gas Liquids Processing and Gathering 10. Type of operating permit New M Modified ❑Renewal 11. Is the facility located in a "nonattainment" area: ® Yes No If "Yes", check the designated "non-attainment" pollutant(s): Carbon Monoxide ® Ozone PM 10 Other(specify) 12. List all (Federal and State)air pollution permits(including grandfathered units), plan approvals and exemptions issued to this facility. List the number, date and what unit/process is covered by each permit. For a Modified Operating Permit, do not complete this item. 1 Operating Permit Application FACILITY PLOT PLAN FORM 2000-101 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division Facility Name: Greeley Natural Gas Processing Plant Facility Identification Code: CO 1230099 The operating permit must be prepared and submitted on forms supplied by the Division. Use of this form is required for all operating permit applications. The Division will not consider or act upon your application unless each form used has been entirely completed. Completion of the information in the shaded area of this form is optional. Use "NA" where necessary to identify an information request that does not apply and is not in the optional shaded area. In order for a comprehensive air quality analysis to be accomplished, a facility plot plan MUST be included with the permit application. Drawings provided must fit on generic paper sizes of 8 1/2" X 11", 8 1/2" X 14" or 11" X 15", as appropriate to display the information being provided. Include the facility name and facility identification code on all sheets. For facilities with large areas, sketches of individual buildings, on separate drawings, may be needed to allow easy identification of stacks or vents. Insignificant activities do not need to be shown. ® 1. A plant layout (plan view) including all buildings occupied by or located on the site of the facility and any outdoor process layout. 2. The maximum height of each building (excluding stack height). ® 3. The location and coded designation of each stack. Please ensure these designations correspond to the appropriate stacks listed on the other permit forms in this application. The drawings need not be to scale if pertinent dimensions are annotated, including positional distances of structures, outdoor processes and free standing stacks to each other and the property boundaries. 4. The location of property boundary lines. ® 5. Identify direction "North" on all submittals. Refer to Appendix A of this application for plant plot plan Are there any outdoor storage piles on the facility site with air pollution emissions that need to be reported? El Yes ® No If "Yes", what is the material in the storage pile(s)? NA Are there any unpaved roads or unpaved parking lots on the facility site? ® Yes No List the name(s) of any neighboring state(s) within a 50 mile radius of your facility: Wyoming 2 Operating Permit Application SOURCE AND SITE DESCRIPTIONS FORM 2000-102 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division Facility Name: Greeley Natural Gas Processing Plant Facility Identification Code: CO 1230099 The operating permit must be prepared and submitted on forms supplied by the Division. Use of this form is required for all operating permit applications. The Division will not consider or act upon your application unless each form used has been entirely completed. Completion of the information in the shaded area of this form is optional. Use "NA" where necessary to identify an information request that does not apply and is not in the optional shaded area. 1. Briefly describe the existing Unit(s) to be permitted. Attach copies of Form 2000-700 as needed to provide the information. Process ftowsheets or line diagrams showing major features and locations of air pollution control equipment can be most effective in showing the location and relationships of the units. Providing mass flowrates/balances at critical points on the diagrams is very helpful when developing an understanding of the processes involved. •Modification requested for P130 — Ethylene Glycol Regeneration Unit. - Addition of an enclosed combustor device (ECD) to the ethylene glycol dehydrator (P130); - Addition of a flash tank with a vapor recovery unit (VRU) to P130. VRU downtime is backed up to ECD. •Add the Facility Flare to the Operating Permit. No changes to rest of the Plant as represented to CDPHE. Refer to Appendix A for process flow drawing and process description. 2. Site Location and Description (Include instructions needed to drive to remote sites not identifed by street addresses) Site is located at 3009 West 44th Avenue, Greeley, Weld County, 80631. The plant is in the SW 1/4 of Section 25, Township 5 North, Range 66 West. Driving Directions - From Greeley, go south on Highway 85 to Highway 34. Proceed west on Highway 34 to 35th Avenue and turn left. Follow 3555 Avenue to the "T" in the road. The plant is immediately on the left side about 300 feet down the road. 3. Safety Equipment Identify safety equipment required for performing an inspection of the facility: Protection ® Other, specify Eye Protection ® Hard Hat Flame retardant outerwear ® Safety shoes Hearing Protection Gloves 3 Operating Permit Application SOURCE DESCRIPTION-APENS FORM 2000-102A Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division Facility Name: Greeley Natural Gas Processing Plant Facility Identification Code: CO 1230099 NOTE: Each new or updated Air Pollutant Emission Notice (APEN) submitted must be accompanied by payment of $100 per APEN. 1. For each emission unit enclose a copy of the most current complete Air Pollutant Emission Notice (APEN) on file with the Division. If the most current APEN was not completely and correctly filled out, a revised APEN is required. List an APEN number, date, and a brief description of the unit/process covered by the APEN. (No filing fees are needed for these copies) P130 (123/0099/121) - Ethylene Glycol Dehydrator with ECD - 5/1/2015 Flare (123/0099/122) - Plant Flare - 12/14/2015 2. No APEN exists for an emission unit. List the new APEN and the appropriate descriptive information here. Submit the APEN with a construction permit application. New APEN and permit application submitted n with this application OR ri under separate cover to Construction Permits Section NA 3. A revised APEN was prepared and enclosed for an emission unit. List the APEN and the appropriate descriptive information here. A revised APEN is needed where a significant increase in emissions has occurred, or is planned; or a major modification of the unit has occurred or is planned; or the existing information needs correction or completion. A construction permit application may need to be submitted. Revised APEN submitted as part of this application: ® Yes No ® Filing Fee Enclosed New permit application enclosed: Yes ® No Permit modification application enclosed: El Yes ® No Note: this application requests to modify the operating permit to incorporate the recent construction permit modification (Draft Permit 15WE0939) for the Greeley Gas Plant. Note: Annual APEN renewals that are due by 4/30/2016 are attached to this modification application: •C-116/P-122 •C-117/P-123 •C-118/P-124 •C-119/P-125 •C-120/P-126 •C-122/P-129 •C-124/P-121 NOTE: Use additional copies of Form 2000-700 as needed to provide the above information. 5 Operating Permit Application STACK IDENTIFICATION FORM 2000-200 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 1230099 3. Stack identification code: P130 3a. Construction Permit Number: 15WE0939 4. Exhausting Unit(s), use Unit identification code from appropriate Form(s)2000-300, 301, 302, 303, 304, 305, 306, 307 2000-300 2000-301 2000-302 2000-303 2000-304 2000-305 2000-306 2000-307 P130 5. Stack identified on the plot plan required on Form 2000-101 6. Indicate by checking: ® This stack has an actual exhaust point. The parameters are entered in Items 7-13. El This stack serves to identify fugitive emissions. Skip items 7-13. Go to next form. • When stack height Good Engineering Practice(GEP) exceeds 65 meters (Colorad)Air Quality Reg 3.A.VIII.D)data emu-is required for Item 7. 7. Discharge height above ground level: — 24__. (feet) 8. Inside dimensions at outlet(check one and complete): • Circular 2 (feet) O Rectangular length(feet) width(feet) 9. Exhaust flow rate: Normal (ACFM) Maximum Not Available (ACFM) Velocity (FPS) El Calculated 0 Stack Test 10. Exhaust gas temperature(normal): (EF) 11. Does process modify ambient air moisture content? ❑ Yes ® No If"Yes", exhaust gas moisture content: Normal percent Maximum percent 12. Exhaust gas discharge direction: ® Up El Down El Horizontal 13. Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack? O Yes ® No ****'Complete the appropriate Air Permit Application Forms(s) 2000-300, 301, 302, 303, 304, ***** 305, 306, or 307 for each Unit exhausting through this stack. 7 Operating Permit Application STACK IDENTIFICATION FORM 2000-200 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 1230099 3. Stack identification code: Flare 3a. Construction Permit Number: 15WE0939 4. Exhausting Unit(s), use Unit identification code from appropriate Fonn(s) 2000-300, 301, 302, 303, 304, 305, 306, 307 2000-300 2000-301 2000-302 2000-303 2000-304 2000-305 2000-306 Flare 2000-307 5. Stack identified on the plot plan required on Form 2000-101 E 6. Indicate by checking: ® This stack has an actual exhaust point. The parameters are entered in Items 7-13. ❑ This stack serves to identify fugitive emissions. Skip items 7-13. Go to next form. ❑ When stack height Good Engineering Practice(_GEP)exceeds 65 meters(Colorado Air Quality Reg 3.A.VIII.D)data entry is required for Item 7. 7. Discharge height above ground level: 65 (feet) 8. Inside dimensions at outlet(check one and complete): ® Circular (feet) El Rectangular length(feet) width(feet) 9. Exhaust flow rate: Normal _ (ACFM) Maximum _(ACFM) Velocity (FPS) ❑ Calculated ❑ Stack Test 10. Exhaust gas temperature(normal): (°F) 11. Does process modify ambient air moisture content? ❑ Yes El No If"Yes", exhaust gas moisture content: Normal percent Maximum _ percent 12. Exhaust gas discharge direction: ® Up El Down ❑ Horizontal 13. Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack? ❑ Yes ® No *****Complete the appropriate Air Permit Application Forms(s) 2000-300, 301, 302, 303, 304, ***** 305, 306, or 307 for each Unit exhausting through this stack. 8 Operating Permit Application MISCELLANEOUS PROCESSES FORM 2000-306 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Gas Processing 2. Facility identification code: CO 1230099 Plant 3. Stack identification code: Flare 4. Process(Unit)code: Flare 5. Unit description: Plant Flare 6. Indicate the control technology status. ❑ Uncontrolled ® Controlled If the process is controlled, enter the control device code(s) from the appropriate form(s): 2000-400 Flare 2000-401 2000-402 2000-403 2000-404 2000-405 2000-406 2000-407 7. Actual annual process rates for 19 8. Date first placed in service: 2004 Date of last modification: 9. Normal operating schedule: 24 hrs./day 7 days/wk. 8760 hours/yr. 10. Describe this process(please attach a flow diagram of the process). Attached? Plant flare with a DRE of 95%'o to handle maintenance and malfunction emissions. 11. List the types and amounts of raw materials used in this process: Material Storage/material Actual usage Units Maximum usage Units handling process Clean-up solvents Other(specify) 12. List the types and amounts of finished products: Material Storage/material Actual amount Units Maximum Units handling process produced amount produced 13. Process fuel usage: Type of fuel Maximum heat input to Actual usage Units Maximum usage Units process million BTU/hr. Natural Gas 0.24 2.01 MMscf/yr Waste Gas 55.91 MMscf/yr 14. Describe any fugitive emissions associated with this process, such as outdoor storage piles, unpaved roads, open conveyors, etc.: ***** For this emissions unit,identify the method(s)of compliance demonstration by completing Form 2000-500, ***** DESCRIPTION OF METHODS USED FOR DETERMINING COMPLIANCE. Attach Form 2000-500 and its attachment(s)to this form. *44** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** 9 Operating Permit Application GLYCOL DEHYDRATION UNIT FORM 2000-307 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 1230099 3. Stack identification code: P130 4. Dehydrator(Unit) code: P130 5. Unit description: Gas dehydration using Ethylene Glycol (EG). This modification adds ECD and VRU to the dehydration unit. 6. Indicate the dehydrator control technology status. El Uncontrolled ® Controlled If the dehydrator is controlled, enter the control device number(s) from the appropriate forms: 2000-400 ECD 1 2000-403 7. Manufacturer: Custom 9. Regenerator heater design rate or maximum continuous rating (mmBTU/hr): 4.6 8. Model &serial number: Custom 10. Date first placed in service: 1983 Date of last modification: 5/1/2015 11. Flash Tank: ®Yes El No Flash tank vented to: El atmosphere ® process 12. Glycol Circulation rate: 6 gallons per minute gallon per pound of H2O 13. Pipeline Capacity: (mmscf/day): 33 (design capacity of dehydrator) 14. Glycol Type: El Triethylene Glycol ® Ethylene Glycol O Other(specify) 15. Glycol Make-up Rate(gallons/year): 16. Computer model input&output printout attached: 17. Gas Pressure(psig): 800 18. Gas Temperature(°F): 95 19. Gas composition test results VOC BTEX HEXANE Test date: 12/19/2014 value units value units value units 22.591 Wt % 0.149 Wt % 0.3629 Wt % *****For this emissions unit, identify the method of compliance demonstration by completing Form 2000-500, ***** DESCRIPTION OF METHODS USED FOR DETERMINING COMPLIANCE, Attach Form 2000-500 and its attachment(s)to this form. ***** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** NOTE: THE SPECIALIZED APEN FOR A GLYCOL DEHYDRATION UNIT MUST BE COMPLETED AND SUBMITTED IF THE STILL VENT EMISSIONS HAVE NOT BEEN REPORTED BEFORE 10 Operating Permit Application CONTROL EQUIPMENT-MISCELLANEOUS FORM 2000-400 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 1230099 3. Stack identification code: P130 4. Unit identification code: P130 5. Control device code: ECD I 6. Manufacturer and model number: Leed Fabrication 7. Date placed in service: 05/01/2015 Date of last modification: NA 8. Describe the device being used. Attach a diagram of the system.- Refer to Attachment B Enclosed combustor desiened for 98%DRE, and permitted at 95% DRE.___,._______ 9. List the pollutants to be controlled by this equipment and the expected control efficiency for each pollutant on the table below. ® Documentation attached EITHER the outlet pollutant concentration OR the control efficiency must be provided. Refer to Attaclunent B Pollutant Inlet pollutant Emission capture Outlet pollutant Control Efficiency (%) concentration efficiency (%) concentration gr/acf ppmv gr/acf ppmv VOC 95 n-Hexane 95 BTEX 95 10. Discuss how the collected material will be handled for reuse or disposal. 11. Prepare a malfunction prevention and abatement plan for this pollution control system. The plan does not have to be submitted with the application. It is suggested the plan include, but not be limited to the following: a. Identification of the individual(s), by title, responsible for inspecting, maintaining and repairing this device. b. Operation variables such as temperature that will be monitored in order to detect a malfunction or breakthrough, the correct operating range of these variables, and a detailed description of monitoring or surveillance procedures that will be used to show compliance. c. What type of monitoring equipment will be provided(temperature sensors, pressure sensors, CEMs). d. An inspection schedule and items or conditions that will be inspected. f. Where is this plan available for review? NOTE: COMPLETION OF INFORMATION IN SHADED AREA OF THIS FORM IS OPTIONAL 11 Operating Permit Application CONTROL EQUIPMENT-MISCELLANEOUS FORM 2000-400 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 123-0099 3. Stack identification code: Plant Flare 4. Unit identification code: Flare 5. Control device code: Flare 6. Manufacturer and model number: John Zink, EEF Series 7. Date placed in service: 2004 Date of last modification: 8. Describe the device being used. Attach a diagram of the system. Flare with a DRE of 95%to handle maintenance and malfunction emissions. 9. List the pollutants to be controlled by this equipment and the expected control efficiency for each pollutant on the table below. Documentation attached EITHER the outlet pollutant concentration OR the control efficiency must be provided. Pollutant Inlet pollutant Emission capture Outlet pollutant Control Efficiency (%) concentration efficiency (%) concentration gr/acf ppmv gr/acf ppmv Volatile Organic 95% Compounds n-Hexane 95% 10. Discuss how the collected material will be handled for reuse or disposal. 11. Prepare a malfunction prevention and abatement plan for this pollution control system. The plan does not have to be submitted with the application. It is suggested the plan include, but not be limited to the following: a. Identification of the individual(s), by title, responsible for inspecting, maintaining and repairing this device. b. Operation variables such as temperature that will be monitored in order to detect a malfunction or breakthrough, the correct operating range of these variables, and a detailed description of monitoring or surveillance procedures that will be used to show compliance. c. What type of monitoring equipment will be provided(temperature sensors, pressure sensors, CEMs). d. An inspection schedule and items or conditions that will be inspected. f. Where is this plan available for review? 12 Operating Permit Application COMPLIANCE CERTIFICATION-MONITORING AND REPORTING FORM 2000-500 Colorado Department of Public Health and Environment DESCRIPTION OF METHODS USED Rev 06-95 Air Pollution Control Division FOR DETERMINING COMPLIANCE All applicants are required to certify compliance with all applicable air pollution permit requirements by including a statement within the permit application of the methods used for determining compliance. This statement must include a description of the monitoring, recordkeeping, and reporting requirements and test methods. In addition, the application must include a schedule for compliance certification submittals during the permit term. These submittals must be no less frequent than annually, and may need to be more frequent if specified by the underlying applicable requirement or by the Division. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 1230099 3. Stack identification code: P130 4. Unit identification code: P130 5. For this Unit the following method(s) for determining compliance with the requirements of the permit will be used (check all that apply and attach the appropriate form(s)to this form). Continuous Emission Monitoring (CEM) - Form 2000-501 Pollutant(s): Periodic Emission Monitoring Using Portable Monitors-Form 2000-502 Pollutant(s): ® Monitoring Control System Parameters or Operating Parameters of a Process - Form 2000-503 Pollutant(s): VOC, HAPs Monitoring Maintenance Procedures-Form 2000-504 Pollutant(s): Stack Testing - Form 2000-505 Pollutant(s): Fuel Sampling and Analysis(FSA) -Form 2000-506 Pollutant(s): Recordkeeping -Form 2000-507 Pollutant(s): V0C HAPs Other(please describe) - Form 2000-508 Pollutant(s): Opacity 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February. 1, 2010 and every 12 months thereafter. (12 month maximum interval) Compliance monitoring reports will be submitted to the Division according to the following schedule: Compliance rrto utorin re orIs will beavailable ortrequest._ Start date: August l, 2009i and every 6 months thereafter. (6 month maximum interval) NOTE: EACH APPLICABLE REQUIREMENT ON FORM 2000-604 NEEDS TO BE SPECIFICALLY ADDRESSED IN ITEM 5. • 13 Operating Permit Application COMPLIANCE CERTIFICATION-MONITORING AND REPORTING FORM 2000-500 Colorado Department of Public Health and Environment DESCRIPTION OF METHODS USED Rev 06-95 Air Pollution Control Division FOR DETERMINING COMPLIANCE All applicants are required to certify compliance with all applicable air pollution permit requirements by including a statement within the permit application of the methods used for determining compliance. This statement must include a description of the monitoring, recordkeeping, and reporting requirements and test methods. In addition, the application must include a schedule for compliance certification submittals during the permit term. These submittals must be no less frequent than annually, and may need to be more frequent if specified by the underlying applicable requirement or by the Division. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 123-0099 3. Stack identification code: Plant Flare 4. Unit identification code: Flare 5. For this Unit the following method(s) for determining compliance with the requirements of the permit will be used (check all that apply and attach the appropriate form(s) to this form). ❑ Continuous Emission Monitoring (CEM) - Form 2000-501 Pollutant(s) _.. O Periodic Emission Monitoring Using Portable Monitors -Form 2000-502 Pollutant(s): ® Monitoring Control System Parameters or Operating Parameters of a Process - Form 2000-503 Pollutant(s): Pilot Flame Monitoring—__________ O Monitoring Maintenance Procedures- Form 2000-504 Pollutant(s): ❑ Stack Testing -Form 2000-505 Pollutant(s): O Fuel Sampling and Analysis(FSA) -Form 2000-506 Pollutant(s): • Recordkeeping - Form 2000-507 Pollutant(s): Nitrogen Oxide, Carbon Monoxide, and Volatile Organic Compounds__._________. O Other(please describe) -Form 2000-508 Pollutant(s): Opacity, Flare Gas Volume Monitoring, Wet Gas Composition 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February 1, 2010 and every - 12 months thereafter. (12 month maximum interval) Compliance monitoring reports will be submitted to the Division according to the following schedule: Start date: August 1, 2009 and every 6 months thereafter. (6 month maximum interval) NOTE: EACH APPLICABLE REQUIREMENT ON FORM 2000-604 NEEDS TO BE SPECIFICALLY ADDRESSED IN ITEM 5. 14 Operating Permit Application Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-503 Colorado Department of Public Health and Environment MONITORING CONTROL SYSTEM PARAMETERS OR Rev 06-95 Air Pollution Control Division OPERATING PARAMETERS OF A PROCESS The monitoring of a control system parameter or a process may be acceptable as a compliance demonstration method provided that a correlation between the parameter value and the emission rate of a particular pollutant is established in the form of a curve of emission rate versus parameter values. Ideally stack test data that bracket the emission limit, if possible, could be used to define the emission curve. This correlation shall constitute the certification of the system. It should be attached for Division approval. If it is not attached, please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 1230099 3. Stack identification code: P130 4. Unit identification code:P130 5. Pollutant(s)being monitored: VOC, HAPs 6. Name of manufacturer: Unknown 7. Model number: Unknown 8. Is this an existing system? ® Yes El No 9. Reserved for future use 10. Describe the method of monitoring: Per O&M plan lean glycol recirculation rate is monitored by recording the flow from the glycol flow meter, inlet gas volume is metered and pilot light of enclosed combustor is monitored by visual inspection._ 11. Backup system: In the event VRU is down, emissions are sent to the ECD. 12. Quality Assurance/Quality Control: Any monitoring system used with the record keeping shall be subject to appropriate performance specifications, calibration requirements and quality assurance procedures. A quality assurance/quality control plan for the monitoring system is attached for Division review. The plan is not attached, but will be submitted to the Division by Parameter monitoring is conducted as specified in O&M plan approved by Division as part of the construction permit process. 13. The applicant shall propose an appropriate averaging period, (i.e., a particular number of continuous hours) for the purpose of defining excess emissions. The Division may approve the proposed averaging period, or other period which the Division determines to be appropriate. Provide the proposed averaging period(s)below. Parameter Averaging Period NA NA• 15 Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-503 Colorado Department of Public Health and Environment MONITORING CONTROL SYSTEM PARAMETERS OR Rev 06-95 Air Pollution Control Division OPERATING PARAMETERS OF A PROCESS The monitoring of a control system parameter or a process may be acceptable as a compliance demonstration method provided that a correlation between the parameter value and the emission rate of a particular pollutant is established in the form of a curve of emission rate versus parameter values. Ideally stack test data that bracket the emission limit, if possible, could be used to define the emission curve. This correlation shall constitute the certification of the system. It should be attached for Division approval. If it is not attached, please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 123-0099 3. Stack identification code: Plant Flare 4. Unit identification code: Flare 5. Pollutant(s)being monitored: 6. Name of manufacturer: John Zink 7. Model number: EEF Series 8. Is this an existing system? ® Yes J No 9. Reserved for future use 10. Describe the method of monitoring: The pilot light is visually checked daily. A flame detector continuously monitors the pilot light. In case a flame is not detected, the pilot is automatically relit with an auto-igniter. 11. Backup system: 12. Quality Assurance/Quality Control: Any monitoring system used with the record keeping shall be subject to appropriate performance specifications, calibration requirements and quality assurance procedures. C A quality assurance/quality control plan for the monitoring system is attached for Division review. [1 The plan is not attached, but will be submitted to the Division by 13. The applicant shall propose an appropriate averaging period, (i.e., a particular number of continuous hours) for the purpose of defining excess emissions. The Division may approve the proposed averaging period, or other period which the Division determines to be appropriate. Provide the proposed averaging period(s) below. Parameter Averaging Period 16 Operating Permit Application Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of Public Health and Environment BY RECORDKEEPING Rev 06-95 Air Pollution Control Division Recordkeeping may be acceptable as a compliance demonstration method provided that a correlation between the parameter value recorded and the emission rate of a particular pollutant is established in the form of a curve or chart of emission rate versus parameter values. This correlation may constitute the certification of the system. For an existing program, the correlation demonstration must be attached for Division consideration for approval. If the correlation information has not yet been developed, please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 1230099 3. Stack identification code: P130 4. Unit identification code: P130 5. Pollutant(s)being monitored: VOCs/HAPs 6. Material or parameter being monitored and recorded: Gas processed, glycol recirculation rate, inlet gas temperature &pressure, enclosed combustor pilot light, inlet gas composition, VRU downtime 7. Method of monitoring and recording (see information on back of this page): Compliance is demonstrated by runningGlyCalc on a monthly basis using the most recent wet gas analysis and recorded operational values (gas volume processed, lean glycol recirculation rate and other operation values in O&M plan). _With the exception of inlet_gas volume, recorded operational values are averaged monthly for use inGlyCalc. 8. List any EPA methods used: NA 9. Is this an existing method of demonstrating 10. Start date: compliance? ® Yes O N 11. Backup system: NA 12 a. Data collection frequency: ® Daily ® Weekly Monthly O Batch(not to exceed monthly) O Other— specify Daily lean glycol recirculation rate, monthly inlet gas volume, weekly inlet gas temperature and pressure, daily enclosed combustor pilot light monitoring (see O&1vI plan). 12 b. Compliance shall be demonstrated: O Daily ❑ Weekly ® Monthly O Batch(not to exceed monthly) ® Other— specify Quarterly as specified 13. Quality Control/Quality Assurance: The monitoring system shall be subject to appropriate performance specifications, calibration requirements, and quality assurance procedures. A quality assurance/quality control plan for the recordkeeping system is attached for Division review. O The plan is not attached, but will be submitted to the Division by DCP currently conducts recordkeeping at this frequency at this facility. A combination of operator read-up sheets and internal databases are used to ensure proper frequency of recordkeeping. 14. O A proposed format for the compliance certification report and excess emission report is attached. DCP currently submits compliance certification reports and excess emission reports to CDPHE/APCD as required. The format for these submittals can be found in previous submittals from DCP. ** The compliance records shall be available for Division inspection. ***** The source shall record any malfunction that causes or may cause an emission limit to be exceeded. ****y Malfunctions shall be reported to the Division the next business day. Hazardous air releases shall be reported to the Division immediately. 17 Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of Public Health and Environment BY RECORDKEEPING Rev 06-95 Air Pollution Control Division Recordkeeping may be acceptable as a compliance demonstration method provided that a correlation between the parameter value recorded and the emission rate of a particular pollutant is established in the form of a curve or chart of emission rate versus parameter values. This correlation may constitute the certification of the system. For an existing program, the correlation demonstration must be attached for Division consideration for approval. If the correlation information has not yet been developed, please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 123-0099 3. Stack identification code: Plant Flare 4. Unit identification code: Flare 5. Pollutant(s)being monitored: NOR, CO, &VOC 6. Material or parameter being monitored and recorded: Waste gas volume 7. Method of monitoring and recording (see information on back of this page): DCP records waste gas volume routed to the plant flare with a flow meter, This gas volume is used in conjunction with other information such as heating__v_alue and gas analysis to calculate emissions. 8. List any EPA methods used: 9. Is this an existing method of demonstrating 10. Start date: Upon issuance of construction permit compliance? ❑ Yes ® No 11. Backup system: NA 12 a. Data collection frequency: ❑ Daily ❑ Weekly ® Monthly ❑ Batch(not to exceed monthly)❑ Other-specify 12 b. Compliance shall be demonstrated: ❑ Daily ❑ Weekly ® Monthly ❑ Batch(not to exceed monthly)❑ Other-specify 13. Quality Control/Quality Assurance: The monitoring system shall be subject to appropriate performance specifications, calibration requirements, and quality assurance procedures. ❑ A quality assurance/quality control plan for the recordkeeping system is attached for Division review. ❑ The plan is not attached, but will be submitted to the Division by DCP currently conducts recordkeeping associated with this facility. A combination of operator read-up sheets and internal databases are used to ensure proper frequency of recordkeeping. 14. ❑ A proposed format for the compliance certification report and excess emission report is attached. DCP currently submits compliance certification reports and excess emission reports to CDPHE/APCD as required. The format for these submittals can be found in previous submittals from DCP. ***** The compliance records shall be available for Division inspection. ***** The source shall record any malfunction that causes or may cause an emission limit to be exceeded. ***** Malfunctions shall be reported to the Division the next business day. Hazardous air releases shall be reported to the Division immediately. 18 Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-508 Colorado Department of Public Health and Environment BY OTHER METHODS Rev 06-95 Air Pollution Control Division 1. Facility Name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 123-0099 it 3. Stack identification code: P130 4. Unit Identification code: P130 5. Pollutant(s) or Parameter(s)being monitored: Opacity 6. Description of the method of monitoring: Opacity is visually checked daily by daily Method 22 readings. 7. Compliance shall be demonstrated: (Specify the frequency with which compliance will be demonstrated) Compliance will be demonstrated by submission of annual compliance reports 19 Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-508 Colorado Department of Public Health and Environment BY OTHER METHODS Rev 06-95 Air Pollution Control Division 1. Facility Name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 123-0099 3. Stack identification code: Plant Flare 4. Unit Identification code: Flare 5. Pollutant(s)or Parameter(s) being monitored: Opacity of effluent, flare gas volume monitoring 6. Description of the method of monitoring: Opacity is visually checked by daily Method 22 readings. The volume of waste gas flared is metered and is monitored monthly for compliance against permit limits. An initial extended wet gas analysis(EGA) will be conducted, and emission factors for criteria and HAP pollutants will be determined Additional annual extended wet gas analyses(EGA) will be conducted, and emission factors for criteria and HAP pollutants will be determined 7. Compliance shall be demonstrated: (Specify the frequency with which compliance will be demonstrated) NA 20 Operating Permit Application EMISSION UNIT CRITERIA AIR POLLUTANTS FORM 2000-601 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 1230099 3. Stack identification code: P130 4. Unit identification code: P130 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached (l Emissions listed are emission limits in draft construction permit 15WE0939,Issuance 1. Air pollutant Actual Potential to emit Maximum allowable Quantity U TPY U TPY Particulates (TSP) TPY PM-10 TPY Nitrogen oxides TPY Volatile organic 0.20 TPY 0.20 8 0.20 compounds Carbon monoxide TPY Lead TPY Sulfur diok:ide TPY Total reduced sulfur TPY Reduced sulfur TRY compounds Hydrogen sulfide TPY Sulfuric Acid Mist TPY Fluorides TPY Units (U) should be entered as follows: 1 = lb/hr 2 = lb/mmBTU 3 = grains/dscf 4 = lb/gallon 5 = ppmdv 6 = gram/HP-hour 7 = lb/mmscf 8 = other(specify) tons per year 9 = other(specify) 10 = other(specify) 21 Operating Permit Application EMISSION UNIT CRITERIA AIR POLLUTANTS FORM 2OOO-6O1 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 123-0099 3. Stack identification code: Plant Flare 4. Unit identification code: Flare 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached ❑ Emissions listed are emission limits in draft construction permit 15WE0939, Issuance 1. Air pollutant Actual Potential to emit Maximum allowable Quantity U TPY Quantity U TPY Quantity U TPY Particulates (TSP) PM-1O Nitrogen oxides 0.068 2 2.6 2.6 Volatile organic 14183 7 19.8 19.8 compounds Carbon monoxide 0.31 2 11.4 11.4 Lead Sulfur dioxide Total reduced sulfur Reduced sulfur compounds Hydrogen sulfide Sulfuric Acid Mist Fluorides Units (U) should be entered as follows: 1 = lb/hr 2 = lb/mmBTU 3 = grains/dscf 4 = lb/gallon 5 = ppmdv 6 = gram/HP-hour 7 = Ib/mmscf 8 = other(specify) 9 = other(specify) 10 = other(specify) 22 Operating Permit Application PLANT-WIDE HAZARDOUS AIR POLLUTANTS FORM 2000-602 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 1230099 3. Complete the following emissions sununary for all hazardous air emissions at this facility. Calculations attached. Attach a copy of all calculations to this form. Attached ® Refer to Attachment B Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name Quantity Units Quantity Units Total HAPs 20.0 TPY Any individual HAP 8.0 TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY TPY NOTE: If there is a permit for this unit, the permit limits are the same as the potential to emit. 23 Operating Permit Application PLANT-WIDE CRITERIA AIR POLLUTANTS FORM 2000-6G3 Colorado Department of Public Health and Environment 09.94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Gas 2. Facility identification code: CO 123-0099 Processing Plant 3. Complete the following emissions summary for the listed emissions at this facility. Air pollutant Actual Potential to emit Maximum allowable TPY TPY TPY Particulates (TSP) 4.0 PM-10 4.0 Nitrogen oxides 99.5 Volatile organic compounds 90.1 Carbon monoxide 101.4 Lead Sulfur dioxide 0.2 Total reduced sulfur - Reduced sulfur compounds - Hydrogen sulfide - Sulfuric acid mist - Fluorides - 24 Operating Permit Application APPLICABLE REQUIREMENTS AND FORM 2000-604 Colorado Department of Public Health and Environment STATUS OF EMISSION UNIT Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 123-0099 3. Stack identification code: P130 4. Unit identification code: P130 5. Pollutant 6. Colorado Air Quality 7. 8. Limitation 9. Compliance Regulations State Status or Only IN OUT Construction Permit Number VOC Draft 15WE0939 0.2 TPY X 10. Other requirements(e.g., malfunction reporting, special operating conditions from an existing State Only Compliance permit such as material usage, hours of operation, etc.) Status Note:All requirements only apply upon issuance of construction permit. IN OUT 15WE0939, Issuance 1, Condition 1: YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division. 15WE0939, Issuance 1, Condition 2: Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall he 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. 15WE0939, Issuance 1, Condition 3: 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 IILE.) 15WE0939, Issuance 1, Condition 5: The following information shall be provided to the Division within fifteen(15) days of the latter of commencement of operation or issuance of this permit. Manufacturer, model number, serial number. 15WE0939, Issuance 1, Condition 7: Emissions shall not exceed the following limitations for X P130 Point 111; 0.2 tpy VOC. 15WE0939, Issuance 1, Condition 7: During the first twelve months of operation, compliance with both the monthly and annual limitations is required. After the first twelve months of X operation, compliance with only the annual limitation is required. 15WE0939, Issuance 1, Condition 7: Compliance with the annual limits shall be determined by recording the facilities annual criteria pollutant emissions, (including all HAPs above the X de-minimis reporting level) from each emission unit, on a rolling twelve month total. 15WE0939, Issuance 1, Condition 8: Compliance with the emission limits in this permit shall be demonstrated by running the GRI GlyCalc model version 4.0 or higher on a monthly basis using the most recent wet gas analysis and recorded operational values (including gas throughput, lean glycol recirculation rate, VRU downtime and other operational values X specified in the O&M Plan.) Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into GRI GlyCalc and be provided to the Division upon request. 15WE0939, Issuance 1, Condition 9: The P-130 emission point shall be operated and maintained with a vapor recovery unit controlling the flash tank. During VRU downtime X these emissions are controlled by an enclosed combustor. The still vent shall be controlled by an enclosed combustor. 15WE0939, Issuance 1, Condition 10: Point 111: 95% of emissions that result from the flash tank associated with this dehydrator shall be recycled and recompressed. Maximum of 5% X downtime from the flash tank associated with this dehydrator shall be routed to the enclosed combustor. 15WE0939, Issuance 1, Condition 11: During the first twelve months of operation, compliance with both the monthly and annual limitations is required. After the first twelve X months of operation, compliance with only the annual limitation is required. 15WE0939, Issuance 1, Condition 11: Compliance with the annual limits shall be determined X on a twelve month rolling total. 15WE0939, Issuance 1, Condition 12: Point 111: This unit shall be limited to the maximum lean glycol circulation rate of 6.0 gallons per minute. The lean glycol recirculation rate shall X be recorded daily in a log maintained on site and made available to the Division for inspection upon request. 25 15WE0939, Issuance 1, Condition 13: The permit number and AIRS ID point number shall X X be marked on the subject equipment for ease of identification. 15WE0939, Issuance 1,Condition 14: Visible emissions shall not exceed twenty percent opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed thirty Y percent opacity for more than 6 minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions. 15WE0939, Issuance 1, Condition 15: This source is subject to the odor requirements of X X Regulation No. 2. 15WE0939, Issuance 1, Condition 16: Point 111: This equipment is subject to the control requirements for glycol natural gas dehydrators under Regulation No. 7, Section XII.H. Beginning May 1, 2005, uncontrolled actual emissions of volatile organic compounds from the still vent and vent from any gas-condensate-glycol(GCG)separator(flash separator or X flash tank), if present, shall be reduced by at least 90 percent through the use of air pollution control equipment. This source shall comply with all applicable general provisions of Regulation 7, Section XII. 15WE0939, Issuance 1, Condition 17: Point 111: The flare covered by this permit is subject to Regulation No. 7, Section XVILB 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 X X operations, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XVII. 15WE0939, Issuance 1, Condition 19: Upon issuance of this permit, 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 X with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. 15WE0939,Issuance 1, Condition 20: Point 111: The owner or operator shall demonstrate compliance with opacity standards, using EPA Method 22 to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any X period or periods of duration greater than or equal to one minute in any fifteen minute period during normal operation. 15WE0939,Issuance 1, Condition 21: Point 111: The owner or operator shall complete the initial annual extended wet gas analysis testing required by this permit and submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. 15WE0939, Issuance 1, Condition 22: Point 111: A source initial compliance test shall be conducted on emissions point 111 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emission limits in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time. Volatile Organic Compounds using EPA approved methods. 15WE0939, Issuance 1, Condition 25: Point 111: The owner or operator shall complete an extended wet gas analysis prior to the inlet of the EG dehydrator on an annual basis. Results of the wet gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per this permit and be provided to the Division upon request. 15WE0939,Issuance 1, Condition 26: Point 111: The owner or operator shall demonstrate compliance with opacity standards, using EPA Method 22 to determine the presence or absence of visible emissions per the frequency required in the O&M Plan. "Visible X 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. *Unit has not yet operated for twelve months following modification. **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 26 Operating Permit Application APPLICABLE REQUIREMENTS AND FORM 2000-604 Colorado Department of Public Health and Er vironment STATUS OF EMISSION UNIT Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural Gas Processing Plant 2. Facility identification code: CO 123-0099 3. Stack identification code: Plant Flare 4. Unit identification code: Flare 5. Pollutant 6. Colorado Air Quality 7. 8. Limitaton 9. Compliance Regulations State Status or Only IN OUT Construction Permit Number NOx 15WE0939 2.6 TPY X CO 15WE0939 11.4 TPY X VOC 15WE0939 19.8 TPY X 10. Other requirements(e.g., malfunction reporting, special operating conditions from an existing State Only Compliance permit such as material usage, hours of operation, etc.) Status Note:All requirements only_apply upon issuance of construction permit. IN OUT 15WE0939, Issuance 1, Condition 1: YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division. 15WE0939, Issuance 1, Condition 2: Within one hundred and eighty days(180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. 15WE0939, Issuance 1, Condition 3: 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.) 15WE0939, Issuance 1, Condition 5: The following information shall be provided to the Division within fifteen(15) days of the latter of commencement of operation or issuance of this permit. Manufacturer, model number, serial number. 15WE0939, Issuance 1, Condition 7: Emissions shall not exceed the following limitations for Flare Point 122; 2.6 tpy NOx, 19.8 VOC, 11.4 CO. 15WE0939, Issuance 1, Condition 7: During the first twelve months of operation, compliance with both the monthly and annual limitations is required. After the first twelve months of operation, compliance with only the annual limitation is required. 15WE0939, Issuance 1, Condition 7: Compliance with the annual limits shall be determined by recording the facilities annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve month total. 15WE0939, Issuance 1, Condition 9: Flare AIRS Point 122 shall he operated and maintained with the control equipment of an open flare to reduce VOC and HAP emissions. 15WE0939, Issuance 1, Condition 11: The Flare AIRS Point 122 shall be limited to 55.91 AIINIscf/yr and 4.75 l4LNIscf/month natural gas volume. 15WE0939, Issuance 1, Condition 11: During the first twelve months of operation, compliance with both the monthly and annual limitations is required. After the first twelve months of operation, compliance with only the annual limitation is required. 15WE0939, Issuance 1, Condition 11: Compliance with the annual limits shall be determined on a twelve month rolling total. 15WE0939, Issuance 1, Condition 13: The permit number and AIRS ID point number shall be marked on the subject equipment for ease of identification. X 15WE0939, Issuance 1, Condition 14: Visible emissions shall not exceed twenty percent X opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed thirty percent opacity for more than 6 minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.l.d or XVII.B.2.b shall have no visible emissions. 15WE0939, Issuance 1, Condition 15: This source is subject to the odor requirements of X X Regulation No. 2. ?7 15WE0939, Issuance 1, Condition 18: The Division has determined this flare shall comply X with the New Source Performance Standards requirements of Subpart A Section 60.18, General Control Device and Work Practice Requirements. 15WE0939, Issuance 1, Condition 18: 60.18(b)Flares. Paragraphs(c)through (0 apply to X flares. 15WE0939, Issuance 1, Condition 18: 60.18(O(1) Flares shall be designed for an operated X with no visible emissions as determined by the methods specified in paragraph (0, except for periods not to exceed a total of 5 minutes during any 2 consecutive hours. 15WE0939,Issuance 1, Condition 18: 60.18(c)(2) Flares shall be operated with a flame X present at all times, as determined by the methods specified in paragraph (0. 15WE0939, Issuance 1, Condition 18: 60.18(0(3) An owner/operator has the choice of X adhereing to either the heat content specifications in paragraph (c)(3)(ii) of this section and the maximum tip velocity specifications in paragraph (c)(4)of this section, or adhering to the requirements in paragraph(c)(3)(i) of this section. 15WE0939, Issuance 1, Condition 18: 1.a.i.1.1.1.1 60.18(c)(3)(i)(A) Flares shall be used that X have a diameter of 3 inches or greater, are nonassisted, have a hydrogen content of 8.0 percent(by volume), or greater, and are designed for and operated with an exit velocity less than 37.2 in/sec(122 ft/sec) and less than the velocity,Vmax. 15WE0939, Issuance 1, Condition 18: 60.18(c)(3)(i)(B) The actual exit velocity of a flare shall X be determined by the method specified in paragraph(0(4) of this section. 15WE0939, Issuance 1, Condition 18: 60.18(c)(3)(ii) Flares shall be used only with the net X heating value of the gas being combusted being 11.2 MJ/scm (300 Btu/scf) or greater if the flare is steam-assisted or air-assisted; or with the net heating value of the gas being combusted being 7.45 MJ/scm (200 Btu/scf) or greater if the flare is nonassisted. The net heating value of the gas being combusted shall be determined by the methods specified in paragraph(0(3) of this section. 15WE0939,Issuance 1, Condition 18: 60.18(c)(5) Air-assisted flares shall be designed and X operated with an exit velocity less than the velocity, Vmax, as determined by the method specified in paragraph(0(6). 15WE0939, Issuance 1, Condition 18: 60.18(c)(6) Flares used to comply with this section X shall be steam-assisted, air-assisted, or nonassisted. 15WE0939, Issuance 1, Condition 18: 60.18(d) Owners or operators of flares used to comply X with the provisions of this subpart shall monitor these control devices to ensure that they are operated and maintained in conformance with their designs. Applicable subparts will provide provisions stating how owners or operators of flares shall monitor these control devices. 15WE0939, Issuance 1, Condition 18: 60.18(e) Flares used to comply with provisions of this X subpart shall be operated at all times when emissions may be vented to them. 15WE0939, Issuance 1, Condition 18: 60.18(0(1)Method 22 of Appendix A to this part shall X be used to determine the compliance of flares with the visible emission provisions of this subpart. The observation period is 2 hours and shall be used according to Method 22. 15WE0939,Issuance 1, Condition 18: 60.18(0(2) The presence of a flare pilot flame shall be X monitored using a thermocouple or any other equivalent device to detect the presence of a flame. 15WE0939,Issuance 1, Condition 18: 60.18(0(3) The net heating value of the gas being X combusted in a flare shall be calculated using the following equation: See 60.18(0(3). 15WE0939, Issuance 1, Condition 18: 60.18(0(4) The actual exit velocity of a flare shall be X determined by dividing the volumetric flowrate(in units of standard temperature and pressure), as determined by Reference Methods 2, 2A, 2C, or 2D as appropriate; by the unobstructed(free) cross sectional area of-the flare tip. 15WE0939, Issuance 1, Condition 18: 60.18(0(5) The maximum permitted velocity, Vmax, X for flares complying with paragraph (c)(4)(iii) shall be determined by the following equation (see 60.18(0(5). 15WE0939, Issuance 1, Condition 18: 60.18(0(6) The maximum permitted velocity, Vmax, X for air-assisted flares shall be determined by the following equation(see 60.18(0(6)). 15WE0939, Issuance 1, Condition 19: Upon issuance of this permit, 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. 28 15WE0939, Issuance 1, Condition 23: Point 122: The operator shall complete an initial site specific extended gas analysis within one hundred and eighty days after commencement of operation or issuance of this permit, whichever conies later, of the natural gas vented from • this emissions unit in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane content(weight fraction) of this emission stream and using volume from the flare meter along with a 95% DRE to demonstrate compliance with emission limits. Results of testing shall be sued to calculate site-specific emission factors for the pollutants referenced above using Division approved methods. Results of site-specific sampling and emission factor analysis shall be submitted to the Division as part of the self-certification and demonstrate the emissions factors established in the permit application "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this sampling and analysis is greater than the emissions factor developed through this sampling and analysis is greater than the emissions factors established in the permit application and "Notes to Permit Holder" the operator shall submit to the Division withing 60 days, a request for permit modification to update emissions factors and emissions limits specified in this permit. 15WE0939, Issuance 1, Condition 24: Point 122: The owner or operator shall demonstrate compliance with opacity standards using EPA Method 9 to measure opacity from the flare. 15WE0939, Issuance 1, Condition 27: Point 122: 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 and using volume from the flare meter along with a 95% DRE to demonstrate compliance with emission limits. 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. *Unit has not yet operated for twelve months following modification. ****USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** 29 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural 2. Facility identification code: CO 123-0099 Gas Processing Plant 3. Stack identification code: PI30 4. Unit identification code: P130 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. ® We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. ❑ This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Deadline Actions 1. 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter 30 Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Natural 2. Facility identification code: CO 123-0099 Gas Processing Plant 3. Stack identification code: Plant 4. Unit identification code: Flare Flare 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. • We will continue to operate and maintain this Unit in compliance with all applicable requirements. • Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. ❑ This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Deadline Actions 1. 2. 3. Progress reports will'be submitted: Start date: and every six (6) months thereafter 31 Operating Permit Application SUPPLEMENTAL INFORMATION FORM 2OOO-7OO Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Gas Processing Plant 2. Facility identification code: CO 123-0099 3. This form supplements Form 2000 - _604 for Emission Unit (e.g. B001, POOL, etc.) P130 Permit Limitation Compliance Methods Permit Limitations and Compliance Methods are included in Draft Construction Permit 15WE0939. These compliance methods will be established upon issuance of construction permit. 32 Operating Permit Application SUPPLEMENTAL INFORMATION FORM 2000-700 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Greeley Gas Processing Plant 2. Facility identification code: CO 123-0099 3. This form supplements Form 2000- 604 for Emission Unit(e.g. B001, POOL etc.) Flare Permit Limitation Compliance Methods Permit Limitations and Compliance Methods are included in Draft Construction Permit 15WE0939. These compliance methods will be established upon issuance of construction permit. 33 Operating Permit Application TABULATION OF PERMIT APPLICATION FORMS FORM 2000-800 Colorado Department of Health 09-94 Air Pollution Control Division Facility Name: Greeley Gas Processing Plant Facility Identification Code: CO 1230099 I. ADMINISTRATION This application contains the following forms: ® Form 2000-100,Facility Identification - ® Form 2000-101,Facility Plot Plan ® Forms 2000-102,-102A,and-l02B,Source and Site Descriptions II. EMISSIONS SOURCE Total Number DESCRIPTION of This Form This application contains the following forms ® Form 2000-200,Stack Identification 2 (one form for each facility boiler-orintina O Form 2000-300,Boiler or Furnace Operation Form 2000-301,Storage Tanks 0 Form 2000-302,Internal Combustion Engine O Form 2000-303,Incineration • Form 2000-304,Printing Operations Form 2000-305,Painting and Coating Operations ® Form 20(X)-306,Miscellaneous Processes 1 ® Form 2000-307.Glycol Dehydration Unit' 1 III. AIR POLLUTION CONTROL Total Number SYSTEM of This Form This application contains the following forms: ® Form 2000-400, Miscellaneous 2 D Form 2000-401,Condensers • Form 2000-402,Adsorbers O Form 2000-403,Catalytic or Thermal Oxidation O Form 2000-404,Cyclones/Settling Chambers • Fornt 2000-405,Electrostatic Precipitators • Form 2000-406,Wet Collection Systems • Form 2000-407,Baghouses/Fabric Filters IV. COMPLIANCE Total Number DEMONSTRATION of This Form This application contains the following forms ® Form 2000-500,Compliance Certification-Monitoring and Reporting 2 (one for each facility boiler-orinting Form 2000-501,Continuous Emission Monitoring • Form 2000-502,Periodic Emission Monitoring Using Portable Monitors • Form 2000-503,Control System Parameters or Operation Parameters of a 2 v« ac l Form 2000-504,Monitoring Maintenance Procedures O Form 2000-505,Stack Testing O Form 2000-506,Fuel Sampling and Analysis ® Form 2000-507,Recordkeeping 2 Form 20(X)-508,Other Methods 2 34 V. EMISSION SUMMARY AND Total Number COMPLIANCE CERTIFICATION of This Form This application contains the following forms O Form 2090-600,Emission Unit Hazardous Air Pollutants quantifying emissions,certifying compliance with applicable requirements,and developing a compliance plan • Form 2000-601,Emission Unit Criteria Air Pollutants 2 Form 2000-602,Facility Hazardous Air Pollutants 1 Form 2000-603,Facility Criteria Air Pollutants Form 2000-604,Applicable Requirements and Status of Emission Unit 2 ❑ Fonn 2000-605,Permit Shield Protection Identification ® Form 2000-606,Emission Unit Compliance Plan-Commitments and Schedule 2 ❑ Form 2000-607,Plant-Wide Applicable Requirements ❑ Form 2000-608,Plant-Wide Compliance Plan-Commitments and Schedule VI. SIGNATURE OF RESPONSIBLE OFFICIAL - FEDERAL/STATE CONDITIONS A. STATEMENT OF COMPLETENESS I have reviewed this application in its entirety and,based on information and belief formed after reasonable inquiry,I certify that the statements and information contained in this application are true,accurate and complete. B. CERTIFICATION OF FACILITY COMPLIANCE STATUS-FEDERAL/STATE CONDITIONS(check one box only) ® I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. ❑ I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements,except for the following emissions unit(s): (list all non-complying units) WARNING: Any person who knowingly,as defined in§ 18-1-501(6),C.R.S.,makes any false material statement,representation, or certification in,or omits material information from this application is guilty of a misdemeanor and may be punished in accordance with the provisions of§25-7 122.1,C.R.S. Printed or Typed Name Title William L. Johnson Vice President of Operations Signature Date Signed 19-7 I 2al co 32 Operating Permit Application CERTIFICATION FOR STATE-ONLY CONDITIONS FORM 2000-800 Colorado Department of Health 09-94 Air Pollution Control Division Facility Name:Greeley Gas Processine Plant Facility Identification Code:CO 1230099 VI. SIGNATURE OF RESPONSIBLE OFFICIAL-STATE ONLY CONDITIONS A. STATEMENT OF COMPLETENESS I have reviewed this application in its entirety and,based on information and belief formed after reasonable inquiry,I certify that the statements and information contained in this application are true,accurate and complete. B. CERTIFICATION OF FACILITY COMPLIANCE STATUS FOR STATE-ONLY CONDITIONS(check one box only) I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. ❑ I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements,except for the following emissions unit(s): (list all non-complying units) WARNING: Any person who knowingly,as defined in§ 18-1-501(6),C.R.S.,makes any false material statement,representation, or certification in,or omits material information from this application is guilty of a misdemeanor and may be punished in accordance with the provisions of§25-7 122.1,C.R.S. Printed or Typed Name Title William L.Johnson Vice President of Operations Signature Date Signed 4 I z-7 /z L� SEND ALL MATERIALS TO: COLORADO DEPARTMENT OF HEALTH APCD-SS-B I 4300 CHERRY CREEK DRIVE SOUTH DENVER,CO 80246-1530 33 dCDCP Midstream ---•..r,.�� 370 17th Sheet,Suite 2500 Midstream;. Denver, 80202 303-605-?0303 9 May 14, 2020 UPS Tracking No.: 1Z F46 915 01 9107 1735 Colorado Department of Public Health and Environment APCD-SS-B 1-1400 4300 Cherry Creek Drive South Denver, CO 80246 ATTN:Elie Chavez Subject: Greeley Natural Gas Processing Plant Operating Permit No. 95OPWE038 Like Kind Replacement under the Alternative Operating Scenario(AOS) Engine C-116 AIRS ID: 123/0099/103 Dear Mrs. Chavez: This letter and the attached APEN serve as an addendum to the Significant Modification application submitted April 24, 2020 for Title V permit 95OPWE038.This addendum requests an update to the serial number for engine C-116(AIRS 103),which was replaced with a like-kind unit. The replacement engine commenced operation on May 01, 2020 and was tested May 04,2020, using a portable analyzer to measure NOx and CO emissions in its exhaust stream. Compressor engine C-116 is currently identified as an 1,100 horsepower(hp) Waukesha L-7042 GSI engine, serial number 368993. The serial number for the replacement Waukesha L-7042 GSI engine is 398468. A field log is maintained at the facility to document all like-kind engine replacements. Both the test results and copy of the field log are included in this submittal, for reference. The replacement engine has not triggered any new Colorado Regulation 7,NSPS JJJJ,or NSPS ZZZZ requirements.The replacement unit is subject to the same requirements under these regulatory standards as the previous engine. Please see the attached regulatory applicability analysis for details. Please feel free to contact me at(303)605-2039 or rshankaran@dcpmidstream.com with any questions regarding this Title V modification addendum. Sincerely, DCP Operating Company,LP Roshini Shankaran Senior Environmental Engineer Attachments APEN for Replacement Engine Spark Ignition Engine APEN - Form APCD-201 Cry CDPHE Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for spark ignition (e.g. gas-fired) reciprocating internal combustion engines (RICE). If your engine is a compression ignition engine (e.g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. compression ignition engine, mining operations, asphalt plant, crusher/screen, etc.). In addition, the General APEN (Form APCD-200)is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website. This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE038 AIRS ID Number: 123 / 0099 /103 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Greeley Natural Gas Processing Plant Site Location Site Location: SW 1/4, Sec 25, T5N, R66W County: Weld NAICS or SIC Code: 1311 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 • Portable Source Home Base: E-Mail Address2: rshankaran@dcpmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits,exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. litlibilb:COLORADO Form APCD 201 Spark Ignition Engine APEN Revision 12/2019 1 I „ w ", Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/103 [Leave blank unless APCD has already assigned a permit Y and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly-reported emission source (check one below) ❑ STATIONARY source O PORTABLE source O Request coverage under a Construction Permit O Request coverage under General Permit GP023(Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of$1,875 must be submitted along with the APEN filing fee. -OR- ❑✓ MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment O Change company name' O Add point to existing permit ❑ Change permit limit ❑ Transfer of ownerships ❑✓ Other(describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ❑ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacement6 Additional Info Et Notes: Update serial number for engine C-116. This unit was replaced with a like-kind unit on 5/01/2020. 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted. s For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. 6 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1,Engine 3,etc.)? Yes If yes, provide the Company Equipment Identification No.: C-116 / P122 General description of equipment and purpose: Refrigeration For existing sources, operation began on: 1/16/1986 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (See APCD website for NAAQS nonattainment area boundary map) ll Yes O No Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec-Feb: 25% Mar-May: 25% June-Aug: 25% Sept-Nov: 25% �y/�►►Af-h.COLORADO Form APCD-201 Spark ignition Engine APEN - Revision 12/2019 2 I Permit Number: 95OPVVE038 AIRS ID Number: 123 /0099/103 [Leave blank unless APCD has azready assigned a permit it and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking Power ❑ Emergency(max. 500 hrs/year) ❑✓ Compression ❑ Pump Jack ❑Water Pump O Other: What is the maximum number of hours this engine will be used for emergency back-up power? hours/year Engine Make: Waukesha Engine Model: L7042 GSI Serial Number7: 398468 What is the maximum designed horsepower rating? 1,100 hp What is the maximum manufacturer's site-rating? 1,100 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8,490 BTU/hp-hr Is this APEN reporting an AO5 replacement engine? ❑✓ Yes ❑ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Waukesha Engine Model: L7042 GSI Serial Number: 368993 Engine Features: Cycle Type: O 2-Stroke ❑� 4-Stroke Combustion: O Lean Burn ❑✓ Rich Burn Aspiration: ❑ Natural ❑✓ Turbocharged Is this engine equipped with an Air/Fuel ratio controller(AFRC)? ❑✓ Yes ❑ No If yes, what type of AFRC is in use? ❑✓ OZ Sensor(mV) ❑NOx Sensor(ppm) ❑Other: Is this engine equipped with a Low-NOx design? O Yes ❑✓ No Engine Dates: What is the manufactured date of this engine? < 12/2002 O If the following date information is not available, check this box, and this engine will be considered newly constructed and/or newly relocated into the state of Colorado based on the engine start-up date. What date was this engine ordered? < 12/2002 What is the date this engine was first located to Colorado? < 12/2002 What is the date this engine was first placed in service/operation? < 12/2002 What is the date this engine commenced construction? < 12/2002 What is the date this engine was last reconstructed or modified? NA 7 The serial number must be submitted if coverage under GP02 is requested. y�► 'COLORADO Form APCD-201 Spark Ignition Engine APEN - Revision 12/2019 3 I »!ViOr I U `M Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/103 [Leave blank unless APCD has already assigned a permit 4 and AIRS ID] Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 4,468,151 / 522,877 Discharge Height :PT` erp., f iowt mate elocii y Above Ground Level . {r eet_ P122 14.6 1,100 5,377 114 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward ❑ Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑ Other(describe): Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter(inches): 12 ❑ Square/Rectangle Interior stack diameter(inches): Interior stack depth (inches): ❑Other(describe): Section 6 - Fuel Data and Throughput Information fuel Ilse Raie t Load- Actual Annual fuel Use Requested nuai emit Litnit8 ( (hour) _ (MMS /year)` (.MSCF/yeQr) 8,984 57.8 78.7 From what year is the actual annual amount? 2019 Indicate the type of fuel used9: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑Field Natural Gas Heating value: BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑✓ Other(describe): Residue Gas Heating Value (give units): 1,097 Btu/scf 8 Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider future process growth. Requested values are required on all APENs,including APEN updates. 9 If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. COLORADO Form APCD201 Spark Ignition Engine APE[' - Revision 12/2019 4 I x M Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/103 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the collection and control efficiencies: Control Equipment Collection Efficiency Control Efficiency Pollutant (%of total emissions captured by (%reduction of captured Description control equipment) emissions) TSP (PM) PAID PM2.5 SOx NOx NSCR 100% 83% VOC CO NSCR 100% 72% Other: HAPs NSCR 100% HCHO-76%,Other HAPs-50% From what year is the following reported actual annual emissions data? 201 9 Use the following table to report the criteria pollutant emissions from source: Emission Factor Actual Annual Emissions Requested Annual Permit Pollutant Emission Limit(s)8 Uncontrolled Units Source Uncontrolled Controlled Uncontrolled Controlled Basis (AP-42, Emissions Emissions1° Emissions Emissions Mfg.,etc.) (tons/year) (tons/year) (tons/year) (tons/year) TSP(PM) 1.94E-02 Ib/MMBtu AP-42 0.62 0.62 1.12 1.12 PM10 1.94E-02 Ib/MMBtu AP-42 0.62 0.62 1.12 1.12 PM2.5 1.94E-02 Ib/MMBtu AP-42 0.62 0.62 1.12 1.12 SOx 5.88E-04 Ib/MMBtu AP-42 0.02 0.02 0.03 0.03 NOx 13.0 g/hp-hr Mfg. 106.99 _ 20.60 138.09 24.00 VOC 0.5 g/hp-hr Mfg. 4.12 4.12 5.31 5.31 CO 9.0 g/hp-hr Mfg. 74.07 20.60 95.60 26.55 8 Requested values will become permit limitations or will be evaluated for exempt status,as applicable, and should consider future process growth. Requested values are required on all APENs,including APEN updates. 10 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide projected emissions. Section 8 - Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteriaEl Yes ❑No pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 lbs/year? If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: Chemical Emission Factor Actual Annual Emissions Abstract Source Uncontrolled Controlled Chemical Name Uncontrolled Service(CAS) Units (AP-42, Emissions Emissionsl° Basis Mfg.,Number etc.) (Ibs/year) (tbs/year) Formaldehyde 50000 2.05E-02 Ib/MMBtu AP-42 1,299.44 311.87 Acetaldehyde 75070 Acrolein 107028 Benzene 71432 Other: Methanol 67561 10 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide projected emissions. COLORADO Form APCD-201 Spark Ignition Engine APEN - Revision 12/2019 5 I Xi .=2:,:t= Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/103 Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP02. Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Senior Environmental Engineer Name(print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of$1,875, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 Air Pollution Control Division OR APCD-SS-B1 (303)692.3148 4300 Cherry Creek Drive South Denver,CO 80246-1530 APCD Main Phone Number (303) 692-3150 Make check payable to: Colorado Department of Public Health and Environment COLORADO Foam 11pcD 0! Spark I��r'tiCioi� Engine APEN K kiC 12 20N 6 rS'YIn`" 1,72= Engine Emission Calculations Greeley Gas Plant DCP Operating Company,LP Waukesha L 7042 GS! Engine C-116/P-122 123/0099/103 4 Stroke,Rich Bum Unit Rating: 1.1.^O hp BSFC: 0-.3rD btu/hp-hr Maximum Heat Input. 93 mmMu/hr Operating Schedule: 8.050 hr/yr _ PI-W. 1040 blu/scf Maximum Fuel Use 787Immscf/yr 20t8Aetud'Panlmetars Year FUN Use Heat Value_ HAMsd/yr) (Btu/sell January 4.86 1100.13 , February 4.70 1096.87 March 4.88 1102_88 April 4.91 1104.27 May 4.75 1103% June 4.77 1096.40 July 5.09 1096.40 August 4.64 1096.93 September - 523 1086.58 October _ 4.53 1089.95 November 4.77 1091.92 December 4.70 1091.92 291f 57.81 1096.52 Criteria Pollutant Emission Calculations Uncontrolled Controlled .otentlal Compliance 2011Actuil Emission Factors Potential Emissions Compliance Factors 2019 Actual l<fetk0Wls Emission Factors Emissions Factors Ezrlk�lella Pollutant (ton/yr) (lb/MMBto) (tonlyr) (tonlyr) Ilb/Mblittu) (tonlyr) NOx' 13.0 g/bhp-hr 138.09 3.38 106.99 2.3 g/bhp-hr 24.00 0.59 20.80 VOC' 0.53/bhp-hr 5.31 0.13 4.12 0.5 o/bhp-hr 5.31 0.13 4.12 CO° 9.03/bhp-hr 85.60 2.34 7407 2.53/bhp-hr 26.55 0.65 20.80 PM° 1.94E-02 Ib/mm8tu 0.79 1.94E-02 0.62 1.94E-02 Ib/mmBtu 0.79 1.94E-02 0.82 SO,' 5.88E-04 Ib/mmBtu 0.024 5.88E-04 0.019 5,88E-04 Ib/mmBtu 0.024 5 88E-04 0.019 a Manufacturers emissions factors °Uncontrolled mission lectors from 4-stroko,Roh-burn 140R61 engines tram AP-42.Chapter 3.Table 3.2-3,(7/00). Non-Criteria Reportable Pollutant Calculations Controlled • Car1 Golfed c11o9ActualAC Uncontrolled Potential Uncontrolled Ached, Control Patentlal Emissions afflit1605 ' Efficiency Emissions Pollutant HAP Emission factors° Dat Source llb/Yfl (Ib/yr) 'A (IWyr) pblyr) 1,1,2,2-TNmchlorcethane 2.53E-05 Ib/mnBtu PA 207 1.60 50% 1.03 080 1,1,2-Trichloraethane <1.53E-05 Ib/mmBtu PA 1 25 0.97 50% 0.63 0.48 1,1 Dichlorcelhane <1.13E-05 Ib/mmBtu PA 0.36 0.72 50% 0.18 0.36 1,2 Dichbrcethane <1.13E.05 Ib/mmBlu PA 0.36 0.72 50% 0.18 0.36 1,2Dichlocopropane <1.30E.05 Ib/mmBtu PA 041 0.82 50% 0.20 041 13-Butadiene 663E-04 Ib/mm6tu PA 5424 4203 50% 27.12 21.01 13-Dichlaropropene 01.27E-05 Ib/mmBlu PA 1.04 081 50% 052 0.40 Acetaldehyde 2.79E-03 Ib/mmBtu PA 228.25 17685 50% 114.12 88.43 Acrolein 2.63E-03Ib/mmBtu PA 215.16 166.71 50% 107.58 83.35 Benzene 1,58E-03Ib/mmBN PA 129.26 100.15 50% 64.63 5008 Carbon Tetrachloride <1.77E-05 Ib/mmBtu PA 1.45 1.12 50% 0.72 0.56 Chlarobenzene 01.29E-05 Ib/mmBtu PA 106 0.82 50% 0.53 0.41 Chloroform <1.37E-05 Ib/mmBtu PA 1.12 0.87 50% 0.56 0.43 Ethylbenzene 02.48E-05 Ib/mmBtu PA 2.03 1.57 50% 1.01 0.79 Ethylene Dibromide <2.13E-05 Ib/mmBtu PA 174 1.35 50% 0.87 0.68 Formaldehyde 2.05E-02 lb/ton-831U PA 1877.70 1299.44 76% 402.50 311.67 Methanol 3.06E-03 Ib/mmBtu PA 250.34 193.97 50% 125.17 96.98 Methylene Chloride 4.12E-05 Ib/mm8tu PA 337 261 50% 1.69 1.31 Naphthalene <9.71E-05 Ib/mmBtu PA 794 6.15 50% 397 3.08 PAH 1.41E-04 lb/mmBtu PA 11.54 894 50% 5.77 4.47 Styrene <1.196-05 Ib/mmBN PA 097 075 50% 0.49 0.38 Toluene 5.58E-00 lb/mmBN PA 45.65 35.37 50% 2182 1769 Vinyl Chloride <7.18E-06 Ib/mmBtu PA 0.59 0.46 50% 0.29 0.23 Xylenes(m,p,o) 1.95E-04 Ib/mmotu PA 15.95 1236 50% 7.98 6.18 TOTAL -- <2653 0 2057 0 891 0 891 °Uncontrolled mission factors from 4-stroke,Rich-burn(45861 engines from AP-42,Chapter 3,Table 3.2-3,17/001. • DCP Operating Company,LP 5/13/2020 Engine Regulatory Applicability Report Colorado Regulation No. 7 Sections XVI and XVII.E Company: DCP Operating Company, LP Source ID: 123/0099/103 Permit#: 95OPWE038 Date: May 14, 2020 Determination of compliance and reporting requirements for a Manufacturer: Waukesha Model: L7042 GSI Nameplate HP: 1,100 Construction date: < 12/2002 Date Relocated to Colorado: < 12/2002 Note: If the engine is exempt from a requirement due to construction date or was relocated from within Colorado, supporting documentation must be provided. Determination of Regulation No. 7 requirements: Regulation No. 7, § XVI ❑ Does not apply to this engine. Engine is not located in the ozone nonattainment area or does not have a manufacturer's design rate greater than 500 horsepower or did not commence operation on or after June 1, 2004. ® Does apply to this engine and applicable emissions controls have been installed. Regulation No. 7, § XVII.E ® Does not apply to this engine. Engine does not have a maximum horsepower greater than 100 or the construction or relocation date precedes the applicability dates. ❑ Does apply to this engine. The following emission limits apply to the engine: NOx(g/hp-hr): CO (g/hp-hr): VOC (g/hp-hr): Max Engine Construction or HP Relocation Date Emission Standards in g/hp-hr NOx CO VOC 100<Hp<500 January 1, 2008 2.0 4.0 1.0 January 1, 2011 1.0 2.0 0.7 500<Hp July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 NSPS JJJJ Report Note that as of September 1, 2008 that 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, § I.B (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. NSPS Subpart JJJJ: Standards of Performance for Stationary Spark Ignition Internal Combustion Engines Company: DCP Operating Company, LP Source ID: 123/0099/103 Permit#: 95OPWE038 Date: May 14, 2020 Manufacturer: Waukesha Model: L7042 GSI Nameplate HP: 1,100 Engine Type: 4 Stroke, Rich Burn Manufacture Date: < 12/2002 Date Engine Ordered: < 12/2002 Note: If the engine is exempt from a requirement due to construction/manufacture date, supporting documentation must be provided. Upon adoption of NSPS Subpart JJJJ into Colorado Regulation No. 6, Part A, if the engine is exempt because the engine was relocated within the state of Colorado, supporting documentation must be provided. ®NSPS JJJJ does not apply to this engine. ❑NSPS JJJJ does apply to this engine. Determination of NSPS JJJJ requirements: §60.4230 Applicability (a)(4)(i) Does not apply to this engine since it is a rich burn engine, greater than 500 HP, with a manufacture date prior to July 1, 2007. CONCLUSION OF FINDINGS This engine is an 1,100 HP, Waukesha L-7042 GSI which precedes the applicability date and is therefore not subject to the provisions of NSPS JJJJ. MACT ZZZZ Report MACT Subpart ZZZZ: National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Company: DCP Operating Company, LP Source ID: 123/0099/103 Permit#: 95OPWE038 Date: May 14, 2020 Manufacturer: Waukesha Model: L7042 GSI Nameplate HP: 1,100 Engine Type: 4 Stroke, Rich Burn Manufacture Date: < 12/2002 Date Engine Ordered: < 12/2002 Note: If the engine is exempt from a requirement due to construction/reconstruction date, supporting documentation must be provided. n MACT ZZZZ does not apply to this engine. MACT ZZZZ does apply to this engine. Note: Using the format below, the source must submit to the Division an analysis of all of the major or area source MACT ZZZZ applicable requirements that apply to this specific engine. The analysis below is an example only, based on a hypothetical new engine located at a major source of HAP emissions. Determination of MACT ZZZZ requirements: §63.6585 Applicability This subpart is applicable to DCP's engine since it is an existing stationary reciprocating internal combustion engine (RICE) at an area source of hazardous air pollutant(HAP) emissions. §63.6590 What Parts of My Plant Does This Subpart Cover? (a)(1)(iii) For stationary RICE located at an area source of HAP emissions, a stationary RICE is existing if you commenced construction or reconstruction of the stationary RICE before June 12, 2006. CONCLUSION OF FINDINGS This engine is subject to MACT ZZZZ since it is an existing non-emergency stationary RICE located at an area source of HAPs. DCP will comply with the provisions of this subpart by complying with the operating and emissions requirements outlined in 40 CFR 63, Subpart ZZZZ, Table 2d. Portable Analyzer Test Results C-116 AOS Old SN:368993 New SN:398468 Greeley Gas Plant Exhaust Flow Rate scf/hr=8710 scVMMBtu*Fuel Consumption MMBtu/hr*20.95%/(20.95%-O2%) Fuel Consumption MMBtu/hr = Fuel Consumption(scf/hr)*Fuel Heating Value(Btu/scf)/1,000,000(Btu/MMBtu) Emissions(lb/hr)=measured ppmv/1,000,000*Exhaust Flow(scf/hr)*mol.wt.(lb/lbmol)* 1 (lbmol)/385.33(scf) where: molecular weight CO = 28.00 molecular weight NOx = 46.07 Test Data Results(see attached): Title V ID No. P-120 P-121 P-122 P-123 P-124 P-125 P-126 P-127 P-128 P-129 Field ID No. C-121 C-124 C-116 C-117 C-118 C-119 C-120 C-123 C-152 C-122 Serial Number 5367457 398468 337569 286434 261947 388531 336485 327603 260928 Engine Stack Test Date Removed 5/4/2020 Meas.Conc.O2% = 0.6 Meas.Post-Converter CO ppmv = 3.682 Meas.Post-Convert.NOx ppmv = 28 Normal Fuel Heat Value Btu/scf = 1015.2 1 H5.2 114 .2 1145.2 1145.2 1145.2 1 1.5.2 1145.2 1 145.27 Max.Fuel Consumption(scf/hr) = 947 8984 8984 8984 8984 8984 7329 8984 8984 Max.Fuel Consump.(MMBtu/hr)= 3.94 0.99 10.29 10.29 10.29 10.29 10.29 7.60 10.29 10.29 Max.Exhaust Flow Rate(scf/hr) = 34317.4 8877.1 92252.8 89610.7 89610.7 89610.7 89610.7 66196.0 89610.7 89610.7 Max.Meas.CO Emiss.Rate(Ib/hr)= 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Permited CO Emiss.Limit(lb/hr) = 2.48 0.96 6.06 6.06 6.06 6.06 6.06 5.93 6.06 6.06 Compliance with Hrly CO Limit YES YES YES YES YES YES YES YES YES YES Max.Meas.CO Emiss.Rate(tpy) = 0.0 0.0 0.1 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Permited CO Emiss.Limit(tpy) = 10.86 4.22 26,55 26,55 26.55 26.55 26.55 25,96 26.55 26.55 Compliance with Yrly CO Limit YES YES YES YES YES YES YES YES YES YES Max.Meas.NOx Emiss.Rate(Ib/hr)= 0.0 0.0 0.3 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Permited NOx Emiss.Limit(lb/hr)= 2.48 0.69 5.48 6.06 6.06 6.06 6.06 3.95 6.06 6.06 Compliance with Hrly NOx Limit YES YES YES YES YES YES YES YES YES YES Max.Meas.NOx Emiss.Rate(tpy)= 0.0 0.0 1.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Permited NOx Emiss.Limit(tpy) = 10.86 3.02 24.00 26.55 26.55 26.5.5 26.55 17.30 26.55 26.55 Compliance with Yrly NOx Limit YES YES YES YES YES YES YES YES YES YES acp . Engine Emissions Test Report Emissions Test Date: 05/04/2020 Q2 ECOM Dcp Midstream ''ter t #'` n-,---,,'-en 1 ,,` f g f'_ 4,_„/„,,,,,, id s Shawn Malone p �y Phone: 3.682 28>00 3026 4th Ave Pass Greeley.CO 80631 *� Mobile: 970 302-1319 (900 ppm) (480 ppm) Email: spmalone@dcpmidstream.com PHYSICAL LOCATION Operational Area: Weld County Facility Name: Greeley Plant EQUIPMENT INFORMATION Equipment: C-116 Unit#: C-116 AF Controller Make: Altronic Model: Waukesha 7042 Gsi Serial#: 398468 AF Controller Model: EPC 100 Service: Refrigeration Ignition Timing: 19.0 Catalytic Converter Make: Stack Flow: Fuel Type: Gas: Natural Catalytic Converter Model: Intake MP: Left: 99 Intake MT: Left: 128 Fuel Consumption: 9400 Right: 90 Right: 127 Horsepower: 1233 Stack Height: FuelSG: RPM: 820 Equipment Fuel Pressure: 14 MV Target Set Point: .750 Hours: Stepper Left: 1101 Exhaust Temp: Left: 1196. MV Actual: Left: .754 Position: Right: 1095 Right: 1216 Right: .750 Catalyst dp: 3.8 Pre-Catalyst 1003 Post-Catalyst Temp: 1010 Temp: PERMIT INFORMATION Permit#: 95OPWE038 Permit Date: 10/18/2013 Permit CO Limit: 900 Permit Equipment#: Permit Units: ppm @ 0%O2 Permit NOx Limit: 480 • ANALYZER INFORMATION Model: ecom-J2KNpro Industrial Serial#: 9724 Last Stability Test: 5/4/2020 Last Linearity Test: 5/4/2020 EMISSIONS TESTRESULTS ,‘ •;.: . �„ ate: � ,:��.< . .� �z Parameter Test 1 Test 2 Test 3 Overall Average 02%; � 0.60 0.00 0.00 0.60 -Co pDsm 3.68 0.00 0.00 3.68 NO ,. 28.00 0.00 0.00 28.00 CO hr,gin: 0.000 0.000 0.000 0.000 N.Ox g/BHP4 r . 0.031 0.000 0.000 0.031 CO lb/hr. 0009 0.000 0.000 0.009 N0x11r, 0.085 0.000 0.000 0.085 CO 0.036 0.000 0.000 0.036 NDx,TY 0.375 - 0.000 0.000 0.375 CO 1$Imr0BTU` 0.000 0.000 0.000 0.000 ,NOx ib/t i L .�_.` 0.030 0.000 0.000 0.030 Time 02 CO NO NO2 NOx Iamb Taell 'Flow 10:35:52. 0.60 0.00 118.00 2.00 120.00 69.60 73.90 1.95 10:3652 `:0.60 2.00 65.00 1.00 66.00 69.60 73,90 1.96 1072 0.60 3.00 51.00 1.00 52.00 69.40 73.80 1.96 10:38;52 -'0.60 4.00 46.00 0.00 46.00 69.40 73.60 1.95 10:39:52 0.60 4.00 40.00 0.00 40.00 69.80 73.40 1.95 10;4052 0.60 4.00 31.00 0.00 31.00 69.60 73.40 1.93 10:41 52 0.60 4.00 27.00 0.00 27.00 69.40 73.40 1.94 10'x4252 0.60 4.00 24.00 0.00 24.00 68.90 73.20 1.93 10;43:52 0.60 4.00 21.00 0.00 21.00 68.70 73.00 1.94 10:44:52, 0.60 4.00 20.00 0.00 20.00 68.40 72.90 1.94 10:45:52 0.60 4.00 18.00 0.00 18.00 68.00 72.70 1,94 10:46:52 0.60 4.00 17.00 0.00 17.00 67.50 72.50 1.93 10:47:52 0.60 4.00 16.00 0.00 16.00 67.50 72.30 1.93 10:4852.' 0.60 4.00 15.00 0.00 15.00 66.90 72.10 1.95 10:49;52.`=0.60 4.00 15.00 0.00 15.00 66.90 72.00 1.94 10:50;52 0.60 4.00 14.00 0.00 14.00 66.90 71.80 1.93 10:51:52 :'0.60 4.00 13.00 0.00 13.00 67.30 71.60 1.96 10:52:52 0.60 4.00 13.00 0.00 13.00 67.50 71.60 1.95 10:53,52. 0.60 4.00 13.00 0.00 13.00 67.30 71.60 1.96 10:54:52 0.60 4.00 12.00 0.00 12.00 67.10 71.60 1.91 10:55:52 0.60 4.00 12.00 0.00 12.00 67.10 71.40 1.92 10:56:52 0.60 4.00 11.00 0.00 11.00 67.10 71.40 1.94 Average 02= 0.60°/0 Average NOx= 28.00 ppm Average CO= 3.68 ppm Average COmass= 3.682 ppm .._._._ Average NO= 27.82 ppm Average NOxmass= 28.000 ppm Average NO2= 0.18 ppm Time O2 CO NO NO2 NOx Iamb Taeti Mew 1 0:.57 -0.60 4.00 11.00 0.00 11.00 67.10 71.20 1.94 1Q5 ,19 21.00 0.00 7.00 0.00 7.00 67.30 71.20 2.60 105 .19, 21.00 0.00 6.00 0.00 6.00 66.90 71.40 2.60 11:08;19" 21.00 0.00 6.00 0.00 6.00 66.20 71.20 2.60 1' 01 19� ;"21.00 0.00 6.00 0.00 6.00 65.70 71.10 2.60 '11;0219 21.00 0.00 6.00 0.00 6.00 65.50 71.10 2.60 1.103:1 . '21.00 0.00 6.00 0.00 6.00 65.70 70.90 2.60 11:04:19 `21.00 0.00 6.00 0.00 6.00 65.50 70.90 2.60 .1O 9.'_'`;21.00 0.00 6.00 0.00 6.00 65.70 70.70 2.60 111:006 -.21.00 0.00 5.00 0.00 5.00 65.70 70.70 2.60 [11:07:19 `21.00 0.00 5.00 0.00 5.00 65.80 70.70 2.60 ANALYZER AVERAGE INFORMATION Total Average O2= 0.60% Total Average NOx= 28.00 ppm Total Average CO= 3.68 ppm Total Average 3,682 ppm Total Average NO= 27.82 ppm Total Average 28.000 ppm COmass= NOxmass Total Average NO2= 0.18 ppm NOTES* new engine start date 5/1/2020 TEST COMPLETED BY: Shawn Malone Dcp Midstream 3026 4th ave Greeley,CO 80631 Phone: Mobile:970 302-1319 Email:spmalone@dcpmidstream.com Home Page: MASS EMISSION CALCULATION: Equipment Type: Engine 500hp++with fuel meter Fuel Type: Gas: Natural Fuel Consumption :9400 Horsepower:1233 Fuel (F) Factor: Based on: EPA RM-19 at 68 deg F and 14.696 psia 140 --F^ SJZ 120 ..741$? Tr, eij 1000- 30— — 60 40 -- 20 — —_ 0 10 20 2f Technician Date 'icp{ Pre & Post Calibration Test Report Midstream Calibration Test Date: 05/04/2020 ECOM - Sensor Span Gas Expiration Zero Error Cal Error Zero Drift Span Drift Dop Midstream Value date %Limit %Limit %Limit %Limit Shawn Malone % 20.9 4/8/2022 0.3 0.5 0.5 0.5 Phone: CO pp j"., 1003 1/1/2021 3 5 5 5 3026 4th Ave NO pp .;;605 5/4/2021 3 5 5 5 Greeley,CO 80631 NO ppm',49 12/18/202 3 5 5 5 Mobile: 970 302-1319 _ 0 Email: spmalone@dcpmidstream.com PHYSICAL LOCATION Operational Area: Weld County Facility Name: Greeley Plant EQUIPMENT INFORMATION : Equipment: C-116 Unit#: C-116 AF Controller Make: Altronic Model: Waukesha 7042 Gsi Serial#: 398468 AF Controller Model: EPC 100 Service: Refrigeration Ignition Timing: 19.0 Catalytic Converter Make: Stack Flow: Fuel Type: Gas:Natural Catalytic Converter Model: Intake MP: Left: 99 Intake MT: Left: 128 Fuel Consumption: 9400 Right: 90 Right: 127 Horsepower: 1233 Stack Height: FuelSG: RPM: "._ 820 Equipment Fuel Pressure: 14 MV Target Set Point: .750 Hours: Stepper Left: 1101 Exhaust Temp: Left: 1196 MV Actual: Left: .754 Position. Right: 1095 Right: 1216 Right: .750 Catalyst dp: 3.8 Pre-Catalyst 1003 Post-Catalyst Temp: 1010 Temp: PERMIT INFORMATION Permit#: 95OPWE038 Permit Date: 10/18/2013 Permit CO Limit: 900 Permit Equipment#: Permit Units: ppm @ 0%O2 Permit NOx Limit: 480 ANALYZER INFORMATIPN Model: ecom-J2KNpro Industrial Serial#: 9724 Last Stability Test: 5/4/2020 Last Linearity Test: 5/4/2020 Calibration Soems: , . _ 3,• O2%u CO ppm .. NO ppm NO2 ppm Pre-Test Zero% 0.1 0.0 2 0.0 Post-Test Zero% 0.1 1 0.0 0.0 Mean Zero,Ccz 0.1 0.5 1.0 0.0 Zero Result Pass Pass Pass Pass Pre-Test Span 21.0 ,1019 - 611 50 Pre-Test Result Pass Pass Pass Pass Post Test Span 20.9 1007 601 49 Post Test Drift% 0.0 0.4 0.7 0.0 Post Test Results Pass Pass Pass Pass Span Drift(%) 0.5 1.2 1.6 2.0 Mean Span,Ccm 21.0 1013.0 606.0 49.5 Time NO NO2 (Flow O2 CO 10:17:55 21.0 0.0 2 0.0 1.96 10:17:58 21.0 *' 0.0 2 0.0 1.96 10:18:00 ' 21.0 0.0 it, 2 0.0 1.96 10:18:02 21.0 0.0 2 *` 0.0 1.97 10:18:03 21.0 0.0 2 0.0 *` 1.98 10:18:55 21.0 0.0 2 0.0 1.96 10:19:56 0.5 901 2 0.0 2.58 10:20:28, 0.1 *= 989 2 0.0 2.58 10:20:45 0.0 1019 *' 2 0.0 2.58 10:20:56`; 0.0 1028 2 0.0 2.56 10:21:56 0.0 234 520 3 2.04 1022:43 0.0 80 611 *' 3 2.02 10:22:56, 0.0 62 617 3 1.77 10:23:55 21.0 24 41 45 2.07 10:24:10 21.0 19 33 50 * 2.07 �'N"a.. " gam` "° nr-A�r �`�' ;_ fi# aa�'R . '`T a'::. -ft;.',...,7':*': ...4 5 _:„.- . L:" ......, 'a.... 'xY k, kt ,aP,u. .";e N .�. x Time O2 CO NO NO2 IFIow 11:10:36 20.9 1 0.0 0.0 1.86 11:10:38 20.9 1 *= 0.0 0.0 1.85 11:10:39 20.9 0.0 0.0 *- 0.0 1.85 11:10:40,' 20.9 0.0 0.0 0.0 * 1.85 111136 1.7 648 3 1 2.54 11:12:36 0.3 972 1 0.0 2.54 11:13;08` 0.1 *' 1006 1 0.0 2.54 1113:10`. 0.1 1007 *; 0.0 0.0 2.54 11:13:36 2.1 1017 1 1 1.68 1114:38` 0.1 157 587 3 1.99 11:14:51 0.1 115 601 *= 3 1.98 11:15:30 -`18.4 63 72 37 2.60 1.115.E 20.3 35 36 49 '*' 2.60 1116- 6 20.8 19 15 13 1.92 11:15:52 20.9 *_ 15 12 5 1.92 *: : Captured Zero * : Captured Cal Response NOTES: TEST COMPLETED BY: Shawn Malone Dcp Midstream 3026 4th ave Greeley,CO 80631 Phone: Mobile:970 302-1319 Email:sprralone@dcpmidstream.com Home Page: Technician Date Stability test 1003 CO Mid span linearity 527 CO ECOM Dcp Midstream Shawn Malone 3026 4th Ave Greeley,CO 80631 Phone: Mobile:970 302-1319 Email: spmalone@dcpmidstream.com ANALYZER INFORMATION Model# :ecom-J2KNpro Inch Serial# :9724 Last Stability Test:5/4/2020 Last Linearity Test: 5/4/2020 Test 1-05/04/20 Time CO Notes 7:53:18 1004 7:54:18 1009 7:55:18 1008 7:56:18 1009 7:57:18 1008 7:58:18 1008 7:59:18 1007 8:00:18 1005 8:01:18 1004 8:02:18 1004 8:03:18 1004 8:04:18 1003 8:05:18 1001 8:06:18 1001 8:07:18 1002 8:08:18 1001 8:09:18 698 8:10:18 529 8:11:18 528 8:12:18 528 8:13:18 530 8:14:18 532 8:15:18 532 Technician Date Stability test 605 NO Mid span linearity 307 NO ECOM Dcp Midstream Shawn Malone 3026 4th Ave Greeley,CO 80631 Phone: Mobile:970 302-1319 Email: spmalone@dcpmidstream.com ANALYZER INFORMATION Model#:ecom-J2KNpro Inds Serial# :9724 Last Stability Test : 5/4/2020 Last Linearity Test: 5/4/2020 Test 1-05/04/20 Time NO Notes 7:22:36 602 7:23:36 605 7:24:36 610 7:25:36 610 7:26:36 606 7:27:36 610 7:28:36 615 7:29:36 606 7:30:36 609 7:31:36 611 7:32:36 610 7:33:36 609 7:34:36 606 7:35:36 608 7:36:36 610 7:37:36 612 7:38:36 51 7:39:36 331 7:40:36 310 7:41:36 311 7:42:36 309 7:43:36 308 7:44:36 307 7:45:36 307 ' ,, Technician Date Stability test 49 NO2 Mid span linearity 20 NO2 ECOM Dcp Midstream Shawn Malone 3026 4th Ave Greeley,CO 80631 Phone: Mobile:970 302-1319 Email:spmalone@dcpmidstream.com ANALYZER INFORMATION Model#:ecom-12KNpro Ind(Serial#:9724 Last Stability Test: 5/4/2020 Last Linearity Test: 5/4/2020 Test 1-05/04/20 Time NO2 Notes 8:21:33 48 8:22:33 50 8:23:33 49 8:24:33 49 8:25:33 50 8:26:33 50 8:27:33 50 8:28:33 50 8:29:33 50 8:30:33 50 8:31:33 50 8:32:33 50 8:33:33 50 8:34:33 50 8:35:33 50 8:36:33 50 8:37:33 12 8:38:33 19 8:39:33 19 8:40:33 19 8:41:33 19 8:42:33 19 /.4 1.c .'`a Date Technician / • • •_i 1 � 4 # z • v-e '* . ,e :7:- ': ,Fps. - e� �r C{° lf� SERVICE TYPE . s li I1LIIIIiLIJJII!IIIPI! 1II*4 DATE OF MANUFACTURE . .a ef T DATE OF OVERHAUL " . y .+,�..., j ,V of g zs, s" ':x ' , z z. � .:: s � � :k _. .. ROD . S r-t EE . i .S . qe �5 gyp. Engine Replacement Field Log Title V Operating Permit No.95OPWE038 DCP Operating Company,LP—Greeley Natural Gas Processing Plant CDPHE Plant ID No. 123-0099 Source ID Like-Kind Original Engine Description Replacement Engine Description Engine Portable Engine Start Analyze Replacemen Date r Stack t Test Date Field Title V Yes No Make Model HP Serial Make Model HP Serial No. No. 121 P-120 X Waukesha L3521GSI 450 388044 Waukesha L3521GSI 450 327086 3/24/99 3/29/99 124 P-121 X Waukesha F1197G 125 3091390 Waukesha F1197G 125 5367457 9/17/99 9/20/99 116 P-122 X Waukesha L7042GSI 1100 240604 Waukesha L7042GSI 1100 316590 2/03/00 2/04/00 123 P-127 X Waukesha L7042GU 896 383195 Waukesha L7042GU 896 286822 5/31/00 6/01/00 119 P-125 X Waukesha L7042GSI 1100 252850 Waukesha L7042GSI 1100 337713 3/24/00 3/27/00 152 P-128 X Waukesha L7042GSI 1100 288037 Waukesha L7042GSI 1100 381337 5/21/02 5/24/02 152 P-128 X Waukesha L7042GSI 1100 381337 Waukesha L7042GSI 1100 598460 8/01/02 80/2/02 122 P-129 X Waukesha L7042GSI 1100 364768 Waukesha L7042GSI 1100 381337 9/13/02 9/17/02 120 P-126 X Waukesha L7042GSI 1100 260958 Waukesha L7042GSI 1100 364768 11/06/02 11/08/02 117 P-123 X Waukesha L7042GSI 1100 389017 Waukesha L7042GSI 1100 275444 12/18/02 12/19/02 118 P-124 X Waukesha L7042GSI 1100 380839 Waukesha L7042GSI 1100 389017 2/19/03 2/25/03 124 P-121 X Waukesha F1197G 125 5367457 Waukesha F1197G 125 5294177 2/4/05 2/4/05 122 P-129 X Waukesha L7042GSI 1100 381337 Waukesha L7042GSI 1100 260958 2/26/06 3/1/06 116 P-122 X Waukesha L7042GSI 1100 316590 Waukesha L7042GSI 1100 261947 6/28/07 7/2/07 123 P-127 X Waukesha L7042GU 896 286822 Waukesha L7042GU 896 269013 10/18/07 10/19/07 Engine Replacement Field Log Title V Operating Permit No.95OPWE038 DCP Operating Company,LP—Greeley Natural Gas Processing Plant CDPHE Plant ID No.123-0099 Source ID Like-Kind Original Engine Description Replacement Engine Description Engine Portable Engine Start Analyze Replacemen Date r Stack t Test Date Field Title V Yes No Make Model HP Serial Make Model HP Serial No. No. 119 P-125 X Waukesha L7042GSI 1100 337713 Waukesha L7042GSI 1100 327603 03/14/08 03/17/08 152 P-128 X Waukesha L7042GSI 1100 598460 Waukesha L7042GSI 1100 388531 07/02/08 07/03/08 120 P-126 X Waukesha L7042GSI 1100 364768 Waukesha L7042GSI 1100 337569 01/22/10 01/26/10 118 P-124 X Waukesha L7042GSI 1100 389017 Waukesha L7042GSI 1100 286434 7/14/11 7/18/11 117 P-123 X Waukesha L7042GSI 1100 275444 Waukesha L7042GSI 1100 898468 8/17/11 8/18/11 122 P-129 X Waukesha L7042GSI 1100 368993 Waukesha L7042GSI 1100 260928 3/24/14 3/28/14 116 P-122 X Waukesha L7042GSI 1100 261947 Waukesha L7042GSI 1100 368993 6/20/14 6/23/14 124 P-121 X Waukesha FIIG 125 5294177 Waukesha F11G 125 5367457 9/17/14 9/19/14 119 P-125 X Waukesha L7042GSI 1100 327603 Waukesha L7042GSI 1100 261947 08/17/15 08/19/15 152 P-128 X Waukesha L7042GSI 1100 388531 Waukesha L7042GSI 1100 327603 03/14/16 03/15/16 123 P-127 X Waukesha L7042GU 896 269013 Waukesha L7042GU 896 336485 08/24/18 08/27/18 120 C-120 X Waukesha L7042GSI 1100 337569 Waukesha L7042GSI 1100 388531 11/12/18 11/15/18 117 P-123 X Waukesha L7042GSI 1100 398468 Waukesha L7042GSI 1100 337569 5/02/19 5/06/19 116 P-122 X Waukesha L7042GSI 1100 368993 Waukesha L7042GSI 1100 398468 5/01/20 5/04/20 1 - Test engine using a portable analyzer within 7 calendar days from when the replacement engine began operation and complete APEN within fourteen (14)days from when the engine began operation. 2- Alternative Operating Scenario is limited to permanent like-kind engine replacements of the same make,model and hp. 6/10/2020 State.co.us Executive Branch Mail-Greeley Operating Permit for Source Review STATE OF \i •s• 4-. COLD ADO Chavez-CDPHE, Elie<elie.chavez@state.co.us> Greeley Operating Permit for Source Review Shankaran, Roshini <RShankaran@dcpmidstream.com> Fri, May 22, 2020 at 3:37 PM To: "Chavez-CDPHE, Elie"<elie.chavez@state.co.us> Hi Elie, Thank you for the opportunity to review and provide comments on this draft permit, and for an extension to our original deadline. The following are our comments: Section i Unit Comment Responsible I Facility- The RO for this facility has changed as of 5/18 to Charles A.Job,General Official wide Manager, North Area Operations, 303-605-1964 Page 6,Summary C-116 Can you please reflect the serial number of this engine per a recent swing. This of Emission Units has been submitted as an addendum to the Title V modification submitted in April. Please see attached for an electronic version. Page 9,Alternative 3 P-130, EG Can you please add in an AOS for glycol pumps similar to what we have been Operating Dehy,AIRS requesting on our construction permits? Please see Libsack Permit Scenarios 111 11WE1475.CP4(see attached) page 4. This will allow us to change out glycol pumps without seeking a permit modification.j.Page 21, NSPS JJJJ C-123 It was previously indicated that C-123 was subject to NSPS JJJJ. However upon review, it appears this engine is subject to Reg 7 limits but not NSPS JJJJ. The engine overhaul did not trigger reconstruction and therefore this engine continues to be a non-JJJJ engine. Please find attached documentation on the cost of the overhaul with respect to cost of a new engine to demonstrate reconstruction was not triggered. Accordingly, please delete reference to NSPS JJJJ in several portions of this permit including: Condition 1.11.1, 1.13, 1.14 I I Page 62,Section II, P-132 It appears that NSPS Dc also applies to this heater, please add a condition similar 4 to 3.8 if you agree. Page 72, 5.1.2 I P-133 Heavy liquid control percentages should match light liquid control percentages. This is because the LDAR program at the higher frequency monitoring will find and fix these leaks regardless of whether the composition is that of light or heavy liquid. https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1667428517546473662&simpl=msg-f%3A16674285175... 1/4 6/10/2020 State.co.us Executive Branch Mail-Greeley Operating Permit for Source Review I i I Page 77, 6.2 P-135 Please update as needed per the sig mod submitted 4/24. Page 79, 6.3 P-135 We would like to request removal of an extended liquid analysis requirement for each of the products. Would it be acceptable to pull an extended analysis of the worst-case liquid (condensate)since the number of loads are also based on the worst-case liquid? Page 87, 7.8 P-130 In Condition 7.8.1.1, can you please add "except during periods of permitted downtime"since VRU downtime is permitted? In Condition 7.8.2.1, can you please add "except during periods of permitted downtime"since ECD downtime is permitted? Page 95, Emission ; Flare I've been notified that the pilot rate is actually 100 scfh and purge rate is 20 scfh &Throughput (instead of 150 scfh and 80 scfh respectively). Can we request these be modified table,Conditions i in this permit? The corresponding annual limit would be 0.876 MMscf/yr for 8.3.2 and 8.3.3, I pilot and 0.17 MMscf/yr for purge. and 8.4 Additionally, please combine 8.3.2 and 8.3.3 into a combined measurement of purge and waste gas. There is no separate meter that meters only purge,the purge and waste is measured together in the flare header. It would also be great if,similar to Roggen,we can include wording to say a purge rate of 20 scfh will be assumed anytime the meter reads below detection limit. In Condition 8.4, it would be great if"waste gas" is reworded to"inlet gas" consistent with the Roggen permit. Please let me know if you'd like to discuss any of these further. Have a great long weekend! Thanks, Roshini Roshini Shankaran Environmental Engineer—Weld County DCP Midstream 370 17th Street, Suite 2500 Denver, CO 80202 Office: 303-605-2039 Cell: 720-391-7005 https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1667428517546473662&simpl=msg-f%3A16674285175... 2/4 6/10/2020 State.co.us Executive Branch Mail-Greeley Operating Permit for Source Review .fro STATE OF ' 9. f COLORADO Chavez-CDPHE, Elie<elie.chavez@state.co.us> Greeley Operating Permit for Source Review Shankaran, Roshini <RShankaran@dcpmidstream.com> Tue, May 26, 2020 at 8:52 AM To: "Chavez-CDPHE, Elie" <elie.chavez@state.co.us> Hi Elie—sorry I forgot to respond to the questions in your email. Here they are copy/pasted with responses provided. • Please confirm that no reciprocating compressor at Greeley has triggered NSPS OOOO/a requirements. I'm specifically concerned about the compressor driven by engine C-123 since that engine was reconstructed in 2018- just want to confirm the compressor attached to that engine wasn't modified in such a way that NSPS 0000a would have been triggered. Yes this is correct. Please see comment regarding C-123. • Please confirm that the engines listed in the insignificant activities summary provided on 5/31/2018 are non-road or otherwise not subject to any applicable requirement in MACT ZZZZ or NSPS JJJJ/111[. If any of these engines have applicable federal requirements, they will need to go into the permit body (like the methanol pump at Roggen). The engines have lost their portable status since they have been on-site longer than 12 months. • Please provide a significant modification application for the engines syn minor limits and the pressurized product loadout rack. This was submitted in April. Based on the information submitted with the minor modification, I have the following questions: o Heavy liquid control percentages—I'd asked this question previously and I think you're already looking into it—we will do whatever we decide for Spindle. o Pressurized product loadout rack emission factors—In order to retain the VOC emission limit, I think we either need to decrease the overall throughput or to take a separate condensate throughput limit. Because the condensate emission factor is most conservative,this emission factor multiplied by the number of loads per year must be equal to the permit limit. The throughput would either need to be reduced to 557,200 loads/year, or a separate condensate limit of 557,200 loads/year would need to be taken if you would like to retain the 43.15 tpy emission limit. Let me know which way you'd like to go and I'll redline the APEN. Thanks, Roshini Roshini Shankaran Environmental Engineer—Weld County DCP Midstream 370 17th Street, Suite 2500 Denver, CO 80202 Office: 303-605-2039 Cell: 720-391-7005 p Midstream [Quoted text hidden] https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1667765144945433980&simpl=msg-f%3A16677651449... 1/1 6/10/2020 State.co.us Executive Branch Mail-Greeley Operating Permit for Source Review STATE OF COLORADO Chavez-CDPHE, Elie<elie.chavez@state.co.us> Greeley Operating Permit for Source Review Shankaran, Roshini <RShankaran@dcpmidstream.com> Wed, Jun 3, 2020 at 12:08 PM To: "Chavez-CDPHE, Elie" <elie.chavez@state.co.us> Hi Elie, I think for the purposes of RICE MACT for the engines, I agree that the existing provisions apply. To the best of our knowledge,the following are the dates we could track down. While we don't have an actual date for the last unit here I think it's reasonable to assume it was pre-2006. Additionally,the facility noted that its 2 Briggs&Stratton and 1 Kohler unit. • Honda GX24O-07/08/2003 • Briggs&Stratton (model 303447-1295-E1)-11/01/2001 • Kohler Command Pro 8.5 (not in use)—02/05/2001 • Briggs&Stratton (model 030549—this is the emergency RICE)-unknown Please see my responses below to the rest of your email. Thank you again for your detailed review, always a pleasure working with you! Thanks, Roshini Roshini Shankaran Environmental Engineer—Weld County DCP Midstream 370 17th Street, Suite 2500 Denver, CO 80202 Office: 303-605-2039 Cell: 720-391-7005 P Midstream From:Chavez-CDPHE, Elie [mailto:elie.chavez@state.co.us] Sent:Tuesday, May 26, 2020 3:46 PM https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&perrrmsgid=msg-f%3A1668502203792395489&simpl=msg-f%3A16685022037... 1/5 6/10/2020 State.co.us Executive Branch Mail-Greeley Operating Permit for Source Review To:Shankaran, Roshini<RShankaran a©dcpmidstream.com> Subject: Re: Greeley Operating Permit for Source Review Hi Roshini, Thank you so much for getting these over to me! I've responded to your table comments in red (see below-you might have to scroll for a while to get to the table). And thank you for following up with the email this morning. I'm going to need some more information on the engines that were listed in the insig activities, so I can make sure I get the correct regulations into the permit. The big thing I need to know is whether the engines are existing or new(ZZZZ vs. JJJJ). I did some guessing based on the insignificant activity list descriptions and spec sheets I found online and have come up with the following ZZZZ applicability for the engines- let me know if these engine descriptions look right to you. • Honda GX240 engines: 7.9 hp Non emergency, non black start 4SRB (Subpart ZZZZ, Table 2d, Item 10) • Kohler pumps: 8.5 and 10 hp Non emergency, non black start 4SRB (Subpart ZZZZ, Table 2d, Item 10) • Briggs&Stratton: 14hp Emergency stationary SI RICE (Subpart ZZZZ, Table 2d, Item 5) If these engines end up being NSPS JJJJ, they'll obviously have different requirements, but I think all I need to know for NSPS JJJJ is the horsepower, which I've listed above for your review. I also wanted to touch base on a couple of things in the insignificant activities list: • Produced Water Tanks-These were previously exempted based on the 1% crude oil for wastewater impoundments,which has since been removed. Can I move these into the II.E.3.a. exemption for non-attainment pollutants< 1 tpy? In the insignificant activities list you provided via email on 5/31/2018, the VOC emissions from both of these tanks were listed as 0.49 tpy, so I think that exemption would work, but I wanted to make sure with you first before I moved them. This is correct, the produced water at Greeley is below 1 tpy and therefore continues to be APEN exempt. • Blowdowns- I looked at our new venting grouping policy and based on that same insig list provided 5/31/2018,the CIG blowdown and compressor blowdowns are cumulatively under 1 tpy VOC, so I'd leave them under the II.E.3.a exemption-does that make sense to you?This one I'm less concerned with because I think you have until October to get permit applications in (by which time this permit should be issued), but I thought I'd make sure with you that we don't need to change anything with these blowdowns just yet. We definitely need some additional time to address this policy change and will be looking at filing something by the end of the year after we have a chance to evaluate more closely. We will submit a TV mod when the permit issues to request that be rolled in. [Quoted text hidden] [Quoted text hidden] [Quoted text hidden] i � I Section , Unit Comment I I l I I Responsible Facility- The RO for this facility has changed as of 5/18 to Charles A.Job, General Official wide E Manager, North Area Operations, 303-605-1964 Done. Page 6,Summary C-116 Can you please reflect the serial number of this engine per a recent swing. of Emission Units This has been submitted as an addendum to the Title V modification submitted in April. Please see attached for an electronic version. Done. Page 9, P-130, EG Can you please add in an AOS for glycol pumps similar to what we have been Alternative Dehy,AIRS requesting on our construction permits? Please see Libsack Permit Operating 111 11WE1475.CP4(see attached) page 4. This will allow us to change out glycol Scenarios pumps without seeking a permit modification. Done. I i https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1668502203792395489&simpl=msg-f%3A16685022037... 2/5 6/10/2020 State.co.us Executive Branch Mail-Greeley Operating Permit for Source Review Page 21, NSPS JJJJ C-123 It was previously indicated that C-123 was subject to NSPS JJJJ. However upon I review, it appears this engine is subject to Reg 7 limits but not NSPS JJJJ. The engine overhaul did not trigger reconstruction and therefore this engine continues to be a non-JJJJ engine. Please find attached documentation on the cost of the overhaul with respect to cost of a new engine to demonstrate reconstruction was not triggered. Accordingly, please delete reference to NSPS JJJJ in several portions of this permit including:Condition 1.11.1, 1.13, 1.14 Thanks for the reconstruction analysis! Can you please provide a commenced construction date for this engine?The most recent APEN submitted does not have this date listed, only the incorrect reconstruction date. I just need that for the TRD and to verify I've got the correct MACT ZZZZ requirements in the permit. .3 _ - 3,3:P33311' 19 9 Page 62,Section P-132 It appears that NSPS Dc also applies to this heater, please add a condition II,4 similar to 3.8 if you agree. I'd determined this didn't apply based on the "commenced operation" date of 1987 on the most recent APEN for this unit. If that date is incorrect, I can definitely update the condition such that both heaters are subject. -3 - - -. Page 72, 5.1.2 P-133 Heavy liquid control percentages should match light liquid control percentages. This is because the LDAR program at the higher frequency monitoring will find and fix these leaks regardless of whether the composition is that of light or heavy liquid. If it's ok with you, I'd prefer to use the previously permitted control percentages of 75%and 30%, as opposed to the EPA-453 light liquid control percentages. I agree that an LDAR program would probably find both light liquid and heavy liquid leaks, however, EPA developed control percentages for only gas and light liquid services, and I'm not comfortable extending these control percentages to heavy liquid when there is not a clear basis for it.The 75%/30%control percentages were previously permitted,so I'd prefer to continue using these for the heavy liquid. 3 1 19� Page 77, 6.2 P-135 Please update as needed per the sig mod submitted 4/24. Was this just referring to the table entry? I've updated the permit limit to 55,718 and 100% condensate assumed as worst case, but was there something you saw in Condition 6.2 that needed to be changed? .._ _ , .s,.: _ .sab e Page 79, 6.3 P-135 We would like to request removal of an extended liquid analysis requirement for each of the products. Would it be acceptable to pull an extended analysis of the worst-case liquid (condensate)since the number of loads are also based on the worst-case liquid? I'd prefer to have samples for each of the species, since the VOC and HAP content will vary significantly between them, and when calculating actual emissions, species-specific emission factors are being used. Would it be ok if we went to sampling every 5 years as opposed to annually? E 1 https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1668502203792395489&simpl=msg-f%3A16685022037... 3/5 6/10/2020 State.co.us Executive Branch Mail-Greeley Operating Permit for Source Review • • 1 I l Page 87, 7.8 P-130 In Condition 7.8.1.1, can you please add "except during periods of permitted downtime" since VRU downtime is permitted? Done. In Condition 7.8.2.1, can you please add "except during periods of permitted downtime" since ECD downtime is permitted? Done. Page 95, Emission Flare I've been notified that the pilot rate is actually 100 scfh and purge rate is 20 &Throughput j scfh (instead of 150 scfh and 80 scfh respectively). Can we request these be table, Conditions l modified in this permit? The corresponding annual limit would be 0.876 8.3.2 and 8.3.3, ; MMscf/yr for pilot and 0.17 MMscf/yr for purge. No problem - I've updated to and 8.4 0.88 MMscf/yr for the pilot and 0.18 MMscf/yr for the purge (rounding). However, because the purge is not metered separately from the waste gas, I combined that limit (like Roggen)for a total of 56.09 MMscf/yr. t € Additionally, please combine 8.3.2 and 8.3.3 into a combined measurement of purge and waste gas. There is no separate meter that meters only purge,the purge and waste is measured together in the flare header. Done. It would also be great if,similar to Roggen,we can include wording to say a purge rate of 20 scfh will be assumed anytime the meter reads below detection limit. We've actually been trying to get away from the language that I put in Roggen because in some instances,the purge rate is actually lower than the lowest detectable limit on the flare meter,which would theoretically result in flow in addition to the purge rate but below the lower detection limit of the meter that we would not be capturing. We can take care of this a couple of ways- either you can provide me with the spec sheet for the flare meter that shows that the lower detectable limit of the meter is less than 20 scfh, or, alternatively, I can include a requirement that the lower detectable limit of the flowmeter be used for all instances during which the flare is operating, but the meter is unable to read the flowrate. Let me know which you'd prefer and we'll go that route. I 3 In Condition 8.4, it would be great if"waste gas" is reworded to"inlet gas" consistent with the Roggen permit.We are starting to see problems in other ( gas plants where the inlet gas is not a representative composition of the actual waste gas being routed to the flare. If you have the ability to sample the https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%a3A1668502203792395489&simpl=msg-f%3A16685022037... 4/5 6/10/2020 State.co.us Executive Branch Mail-Greeley Operating Permit for Source Review Greeley flare header, I can update this condition to require that an annual sample of the gas routed to the flare be taken, if that would help make the condition more clear. i E _ [Quoted text hidden] [Quoted text hidden] https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1668502203792395489&simpl=msg-f%3A16685022037... 5/5 dcpProject Cost Report Including AP and GL Transactions Midstream Project ID Project Description AP Process AP Operator ID APVCHR Vendor Long Name VAP Description AP Fiscal Monetary AP Year AP Amount AP 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC CONNECTOR,FLEX EXHAUST,VSG, 2018 1395.09 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC GASKET,OIL LINE 2018 4.97 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC GASKET,O-RING 2018 12.28 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC GASKET,OIL LINE 2018 4.97 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC GASKET,OIL LINE 2018 9.94 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC cplg,38 dress,3.5 pipe,ssea 2018 136.28 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC cplg,38 dress,3 pipe,seal( 2018 124.51 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC GASKET,UPPER WATER CONNECTION 2018 9.14 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC GASKET,VHP 2018 40.14 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC O RING,2.88X3.12X.11N,COMMON 2018 9.75 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC SCREW,HEX,HEAD,.62-18X,COM 2018 256.32 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC SEAL,COUPLING 2018 139.27 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC SEAL,VHP 2018 27.92 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC SEPARATOR,OIL,VGF 2018 442.77 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC WASHER,.656X1.187X.10,COMMON 2018 3.6 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC CPLG,38 DRESS,3.5 PIPE,SEAL 2018 136.28 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC CPLG,38 DRESS,3 PIPE,SEAL( 2018 124.51 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC GASKET,UPPER WATER CONNECTION 2018 9.14 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC GASKET,VHP 2018 7.65 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC O RING,2.88X3.12X.1IN,COMMON 2018 9.75 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC SEPARATOR,OIL,VGF 2018 442.78 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC WASHER,.656X1.187X.10,COMMON 2018 3.6 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC Total Direct Material(Include 2018 8696.98 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC Total Labor 2018 4403.61 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH BEMENL WAUKESHA-PEARCE INDUSTRIES LLC CONNECTOR,FLEX EXHAUST,VSG, 2018 -1395.09 710001751 2018-Overhaul Greeley 123 Wauk CBOVRH ES_WAUKESHAPE001 WAUKESHA-PEARCE INDUSTRIES LLC OVERHAUL KIT,SWING L7042G HIG 2018 121422 Total Overhaul Cost $154,887.24 Cost of New Waukesha L7042 GSI $711,685 Overhaul cost as fraction of purchase price 22% Trigger Reconstruction? NO &cap DCP Midstream De St.,Suite 2500 Denver,CO 80202 Midstream. ` ° '�4�2°z www.dcpmidstream.com December 18,2019 UPS Tracking No. IZ F46 915 02 9356 7936 Colorado Department of Public Health and Environment Air Pollution Control Division ATTN: Elie Schuchardt 4300 Cherry Creek Drive South Denver, CO 80246-1530 Re: Greeley Natural Gas Processing Plant Title V Modification: 95OPWE038 AIRS ID 123/0099 Dear Ms. Schuchardt: DCP Operating Company, LP(DCP)is submitting the attached minor modification application for the Greeley Natural Gas Processing Plant(Greeley), located at Section 25, Range 66W,Township 5N in Weld County, Colorado. This facility currently operates under Title V permit 95OPWE038 originally issued on May I, 1999 and last revised on September 6,2017. Summary of Changes 1. Fugitive Emissions(AIRS ID 114) Greeley is required to conduct periodic hard counts of components that may leak VOCs. The estimation of fugitive VOCs has been updated based on the most recent hard count plus a 20% buffer. All emission units at the facility are subject to the Leak Detection and Repair(LDAR)program in New Source Performance Standard (NSPS)Subpart OOOO,as required by Regulation No. 7, Section XII.G. The Division has specified control efficiencies that can be assumed for monthly monitoring in accordance with LDAR per Subpart OOOO,as enumerated in Section 7 of the Fugitive Component Leak Emissions APEN Form APCD-203 (Rev. 3/2019). These control efficiencies differ from those specified in 95OPWE038, Condition 5.1 for some types of components. DCP is requesting an update to Condition 5.1 to reflect the use of the control efficiencies associated with the required NSPS Subpart OOOO LDAR program, which is being performed across the Greeley facility. Where a specific type of component is not listed in Section 7 of Form APCD-203,the control efficiencies for similar components were used in recalculating plantwide fugitive VOC and organic HAP emissions from equipment leaks. DCP is also requesting a change in the allowable VOC emissions from this source based on the revised emission estimate. Finally,the most recent revision to the operating permit occurred prior to Regulation No. 7, Section XII.G being revised to specify that all natural gas processing plants in the 8-Hour Ozone Control Area would be subject to the LDAR program of NSPS Subpart OOOO. DCP is proposing changes to Condition 5 to add these requirements.The specific language of the suggested revisions has been taken from recent revisions to the operating permit for a similar gas plant. For a summary of these requested changes,please see the proposed revisions to Permit 95OPWE038 in Attachment F. 2. Waukesha L-7042 GSI Compressor Engines C116,Cl 17.C118,C120,C122(AIRS 103, 104, 105, 107, 110) DCP is requesting a decrease in the NO„emission limits and corresponding compliance emission factors for the above-listed five compressor engines. DCP has included summaries of all 2019 quarterly portable analyzer results in support of the requested emission limit decreases. DCP is requesting these reduced emission limits to ensure that NO,emissions from each unit are permitted below NA-NSR Major Modification significance levels,and that this facility can continue to perform permanent engine replacements under the Alternative Operating Scenarios (AOS)provisions detailed in Section 1.0,Condition 2.0 of Title V Operating Permit 95OPWE038 after the pending reclassification of the Colorado ozone non-attainment area from moderate to serious. Additionally, DCP is requesting that the serial numbers listed for engines C117 and C120(AIRS 104 and 107)be updated to reflect permanent engine replacements that occurred on May 8,2019 and November 19, 2018, respectively. 3. Pressurized Product Truck Loadout Rack P135 (AIRS 115) DCP has recalculated the VOC emission factors for the various products loaded and unloaded using this equipment,and determined that Y-Grade(rather than B-G Mix)provides more conservative VOC and HAP emission profiles. DCP is requesting redlines to the Title V permit reflecting this updated calculation methodology,as well as including speciated HAP emissions for this source. The above changes don't require any update to the underlying emission limits for this source. It will continue to operate under the current VOC emission limit of 43.15 tpy(uncontrolled).A review of actual rolling 12-month values indicate this existing limit is still representative of potential activity at this source. The revised calculation methodology has resulted in a slight increase in potential throughput. DCP is requesting that the limit be increased from 560 MMgal/yr to 564 MMga1/yr.Additionally,DCP is requesting that the units for this throughput limit be updated from MMgal/yr to loads/yr(at 10,000 gallons/load).These changes result in a final proposed throughput limit of 56,390 loads/yr. Regulatory Analysis There are no changes in regulatory applicability for the fugitive VOC emissions from the facility other than the addition of Regulation No. 7, Section XIC.G LDAR requirements(NSPS Subpart OOOO LDAR program). Subpart KKK still applies facility-wide but the Division has previously found that for most components, compliance with NSPS Subpart OOOO LDAR satisfies the LDAR requirements of Subpart KKK. The primary change will be to update the LDAR program control efficiencies to reflect the implementation of NSPS Subpart OOOO LDAR for all components at the facility and to revise the VOC permit limit from this source. There are no changes in regulatory applicability for the five compressor engines listed above based on the requested decreased emission limits. DCP will continue to comply with all applicable state and federal requirements for these engines. There are no changes in regulatory applicability for the pressurized product truck loadout rack based on the proposed updates to the emissions calculation methodology. DCP will continue to comply with all applicable state and federal requirements for this source. Attachments The following attachments needed to make the requested changes to operating permit 950PWE055 have been included: • Attachment A: Responsible Official Certification • Attachment B: APEN Fees • Attachment C: Updated APEN Forms • Attachment D: Emission Calculations and Supporting Documentation • Attachment E: Form APCD-102: Facility Emissions Inventory • Attachment F: Proposed Revisions to Permit 95WEOP038 If you have any questions or require any additional information about this submittal,please contact me at (303)605-2029 or MECameron@dcpmidstream.com. Sincerely, DCP Operating Company, LP Oget irnir-i/v2•2—/ Marie Cameron Senior Environmental Engineer I have reviewed this Minor Modification application supplied under authority of Regulation No. 3, Part C, Section X (5 CCR 1001-5) in its entirety and,based on information and belief formed after reasonable inquiry, I certify that the proposed modification meets the criteria for use of minor permit modification procedures and request that such procedures by used to process this application. This certification conforms with Regulation No. 3, Part C, Section X.D.3 (5 CCR 1001-5). Tauna Rignall General Manager, North Area Operations Printed or Typed Name Title fq Signature of R ble Official Date Fugitive VOC Emissions Greeley Gas Plant DCP Operating Company,LP Potential operation 8,760 hr/yr Uncontrolled Emissions Controlled Emissions _ Emission Control Total HC VOC Total HC VOC Equipment Factors Component Percent Factor Emission Emission Emission Emission Type (kg/hr/source) Count° VOC (Percent) Rate(lb/hr) Rate(lb/hr) Rate(tpy) Rate(tpy) Valves-Gas/Vapor 0.004500 1,260 29.52% 96.00% 12.500 3,690 2.190 0.647 Valves-Light Liquids 0.002500 2,555 100.00% 95.00% 14.081 _ 14.081 3.084 3.084 Valves-Heavy Liquids 0.000008 2 100.00% 95.00% 0.00004 0.00004 0.00001 0.00001 Relief Valves-Gas 0.008800 85 29.52% 75.00% 1.653 0.488 1.810 0.534 Relief Valves-Liquid 0.007500 68 100.00% 75.00% 1.131 1.131 1.238 1.238 Compressor Seals 0.008800 11 29.52% 75.00% 0.210 0.062 0.229 0.068 Pump Seals-Light Liquids 0.013000 42 100.00% 88.00% 1.204 1.204 0.633 0.633 Connectors-Gas/Vapor 0.000200 4,720 29.52% 81.00% 2.081 0.614 1.732 0.511 Connectors-Light Liquids 0.000210 7,842 100.00% 81.00% 3.631 3.631 3.021 3.021 Flanges-Gas/Vapor 0.000390 1,289 29.52% 81.00% 1.108 0.327 0.922 0.272 Flanges-Light Liquids 0.000110 1,638 100.00% 81.00% 0.397 0.397 0.331 0.331 Gas/Vapor Totals 17.55 5.18 6.88 2.03 Light Liquid Totals 20.44 20.44 8.31 8.31 Totals 19,512 38.00 25.62 15.19 10.34 a Emission Factors from.EPA-453-R-95-017,Table 2-4 Tons per year: 112.24 "June 2019 Component Count+20%buffer Greeley Gas Plant 11/19/2018 Corrected VOC Liquid HAP Speciation Constituent weight% for HC weight% weight% Helium 0 - - - Hydrogen 0 - - Carbon Dioxide 4.86 - - - Nitrogen 0.23 - Methane 50.5408 53.2513 - Ethane 16.3516 17.2285 - - Propane 10.8942 11.4785 11.48% - Isobutane 2.4497 2.5811 2.58% - n-Butane 5.4697 5.7630 5.76% - Isopentane 2.1729 2.2894 2.29% - n-Pentane 2.3529 2.4791 2.48% - Cyclopentane 0.1031 0.1086 0.11% - n-Hexane 0.8957 0.9437 0.94% 3.197% Cyclohexane 0.2293 0.2416 0.24% - Other Hexanes 1.4746 1.5537 1.55% - Heptanes 0.8508 0.8964 0.90% - Methylcyclohexane 0.2349 0.2475 0.25% - 2,2,4-Trimethylpentane 0.0015 0.0016 0.00% 0.005% Benzene 0.1687 0.1777 0.18% 0.602% Toluene 0.2256 0.2377 0.24% 0.805% Ethylbenzene 0.0059 0.0062 0.01% 0.021% Xylenes 0.0558 0.0588 0.06% 0.199% C8+Heavies 0.4312 0.4543 0.45% Oxygen/Argon 0 - - - Alcohols/Methanol 0.0011 0.0012 0.001% 0.004% Total 100 100 29.52% Total Component Count Actual Source Actual Source Equipment Type Count' Count+20% Valves-Inlet Gas 1,050 1..260 Valves-Light Liquid 2,129 2.555 Valves-Heavy Liquid 2 2 Relief Valves-Gas 71 85 Relief Valves-Liquid 57 68 Pump Seals-Light Liquid 35 42 Connectors-Inlet Gas 3,933 4,720 Connectors-Light Liquid 6,535 7,842 Flanges-Inlet Gas 1,074 1,289 Flanges-Light Liquid 1,365 1.638 Other-Inlet Gas 0 0 Other-Light Liquid 0 0 Open-Ended Lines 0 0 Compressor Seals 9 11 ' `June 2019 Component Count Greeley Gas Plant HAP Calculations-Gas Components Uncontrolled HAP Controlled HAP Uncontrolled HAP Controlled HAP Emissions Emissions Emissions Emissions Rate(lb/yr) Rate(ib/yr) (tpy) (tpy) Benzene 273.29 24.47 0.137 0.012 Toluene 365.47 32.72 0.183 0.016 Ethylbenzene 9.56 0.86 0.0048 0.00043 Xylene 90.40 8.09 0.045 0.0040 n-Hexane 1,451.03 129.92 0.726 0.065 2,2,4-Trimethylpentane 2.43 0.22 0.001 0.0001 Methanol 1.78 0.16 0.001 0.000 HAP Calculations-Liquid Components Uncontrolled HAP Controlled HAP Uncontrolled HAP Controlled HAP Emissions Emissions Emissions Emissions Rate(ib/yr) Rate(lb/yr) (tpy) (tpy) Benzene 1,078.31 100.03 0.539 0.050 Toluene 1442.00 133.77 0.721 0.067 Ethylbenzene 37.71 3.50 0.019 0.0017 Xylene 356.67 33.09 0.178 0.017 n-Hexane 5,725.19 531.12 2.863 0.266 2,2,4-Trimethylpentane 9.59 0.89 0.005 0.000 Methanol 7.03 0.65 0.004 0.000 HAP Calculations-Total Emissions Uncontrolled HAP Controlled HAP Uncontrolled HAP Controlled HAP Emissions Emissions Emissions Emissions Rate(Ib/yr) Rate(Ib/yr) (tpy) (tpy) Benzene 1,351.60 124.50 0.68 0.06 Toluene 1,807.47 166.50 0.90 0.08 Ethylbenzene 47.27 4.35 0.024 0.0022 Xylene 447.06 41.18 0.22 0.021 n-Hexane 7,176.21 661.04 3.59 0.33 2,2,4-Trimethylpentane 12.02 1.11 0.006 0.0006 Methanol 8.81 0.81 0.00 0.000 I � EMPACT EXTENDED NATURAL GAS ANALYSIS(*DHA), GLYCALC INFORMATION PROJECT NO. : 201811115 ANALYSIS NO. : 01 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: DECEMBER 02,2018 09:26 ACCOUNT NO. : PO 448261 RC CODE GO11 SAMPLE DATE : NOVEMBER 19,2018 09:15 PRODUCER : CYLINDER NO.: 1172 LEASE NO. : SAMPLED BY : KYLE ORR NAME/DESCRIP: GREELEY PLANT EG INLET "FIELD DATA*** SAMPLE TEMP.: SAMPLE PRES.: 780 AMBIENT TEMP.: COMMENTS SPOT,NO PROBE Componet Mole% Wt% Helium 0.01 0.00 Hydrogen 0.00 0.00 Carbon Dioxide 2.56 4.86 Nitrogen 0.19 0.23 Methane 73.08150 50.54080 Ethane 12.6146 16.3516 Propane 5.7310 10.8942 Isobutane 0.9777 2.4497 n-Butane 2.1830 5.4697 Isopentane 0.6986 2.1729 n-Pentane 0.7565 2.3529 Cyclopentane . 0.0341 0.1031 n-Hexane 0.2411 0.8957 Cyclohexane 0.0632 0.2293 Other Hexanes 0.3987 1.4746 Heptanes 0.1978 0.8508 Methycyclohexane 0.0555 0.2349 2,2,4 Trimethylpentane 0.0003 0.0015 Benzene 0.0501 0.1687 Toluene 0.0568 0.2256 Ethylbenzene 0.0013 0.0059 Xylenes 0.0122 0.0558 C8+Heavies 0.0856 0.4312 Subtotal 99.99960 99.99890 Oxygen/Argon 0.00 0.00 Alcohols 0.0004 0.0011 Total 100.00000 100.00000 The d lit procured berm ha,1 err argon-cc]i,a n<rruu of can a,,l urmPo(00/tethn;qurs and ro/1rr.car.the fa luurn<ennel.n n P31PAl T tra/pical.S'stems,Inc. Resttlta n;the ana/. ran he of/cried hr the-r,p/ngrot lfiuu,,therein r.are rnt/v •arr,uned fit rough proper lab protocol. EhtPA£l if srratec no rsp>a-sibibly for interpretation ar any eoatequence,from aylliranon a f the sported i tf annwaan wad a,the'ale lubilin of the liter. The reproduction in at,,,MCA,Ilium repotted inf rntaoon atav not br made.In portion nr res a Whole without the onacr p rtnin oat of 1 t/PA£T.t as/Shoal Svstrrns,late. • EMPACT Analytical Systems Inc. 365 S Main St Brighton,CO 80601 303-637-0150 Greeley Gas Plant - Topographic Site Map Go ogle Maps 40°21'51.2"N 104°43'49.6"W ware^ 7✓ e { p^ ..4,... traicSan 'a > �l s t r Eaton pp ) � w NW •);e &: 'rz; XY2) aa2 Wmdsar ~m;i ltx-ene Wiz'+) * s : sj i zn AYtln 07) " nr,wna 3a, Greeley (7-L, r, 'r :..Y4 " Loveland aa.. GarcJcn L!Yy % * c'', Kersey$?;' .l _ p "- � � Evans .. * p „,,,,,,,,j,1. .„,ps:: Auburn �, ��„ X.+ ;� Camplcm t,„&„. �`° �"y Johnstown �' '' .° S ' i Faax ``° Aslrn ` ' � � yt w � WelXY Malitken t,eiaj xi �y Ito ,' 'Y�yp . m t'",:1%:'''‘,, "g AAA i 'w G gIe PIaYYwviP%e Map data©2019 Google 2 mi r i Engine Emission Calculations Greeley Gas Plant DCP Operating Company,LP Waukesha 1 1042 GSI Engine G-116/P-122 123/0099/103 4 Stroke,Rich Bum Ur8t Ralm4 1.8,23 hp BSFT 4 490 81urnpN Memmun Meal Input 9.3 rmnblwbr Operating Schedule 8,-O tem) 1933 1 033 blued Menrnun fuel Use 73.7)mmsdtyr Year Fue4 Use Heat Value )MMsctlyr) telulac0 January 4.58 1120 93 febnwy 476 113028 March 5.14 111271 Apia 5.20 110535 May 5.02 1098.87 itine 4.94 1123.06 Jul_ 500 111964 Ague 4.96 111964 September 4.68 1086.41 October 482 108730 Nvwmbar 482 1102,62 December 4.84 110099 1f ,. '' 58.75 1109.82 Criteria Pollutant Emission Calculations uncontrolled Coniro0ed Pot lot Campll Emission Pactors Potential Erosions Cornp015, Paetors En,,,,,,,.,Factors Eelssions Paetars • Pollutant {toalyh gbJMMSIA) 10niY5 - {Ion/y5 , )Ib1MMBtu) ttooyrl.. Nos` 130 gab?phr 138,09 3.38 110.04 2.3 84866-hr 24.00 059 21.19 VIIC' 0.543:pfrr 5.31 0.13 4.24 053183 hr 9.31 013 4.24 C0' 90 8./bhp-hr 05.60 2.34 76.19 2.5 0.883688 26.55 065 21.19 PM' 1,3/46-021Nmm0t2 0.79 1.94E-02 0.63 1 940-02 6,883&u 0.79 154E-02 0.93 30; 5.88E-411o1mmBlu 0.024 598E-04 0.019 5.88E-04 IN-no-l10 0.024 5.88E-04 0.019 `M4nuk^a!ah.emssMm&ebrs Unmen6kl.1<O)Un hc10ry Pent 43084,,n<Abvm/450.9),,gaca Pmn 87-42.00,8?,,3 Tab&3,2.3.t1Nai. Non-Criteria Reportable Pollutant Calculations 3 15 3`5 Controlled Uncontrolled Potential Control Potential Emissions 'I r '<, Pinckney Emissions Pollutant HAP Emission Tamers' 0419 source )IMyr) 01.10 pb'yr) Pair) 1.12.2-Tavachkrcethane 253E-05161mmBN EPA J_ 2.07 1.65 50% 103 0 82 .!,2-Tnc1or ettm ae <153E-051Ghnmatu EPA 1.25 1,00 50% 063 0,50 1,1 L7ichlaoeihane a 1.13E-05 lb/86313th EPA 0.36 0.74 50% 018 0,37 1.2 Drano oeloaon <1.13E-05 Ib/mm01u EPA 038 0.74 80% 018 037 1.20ichb!oproce_ _ <1,30E-05ib/mmBtu EPA 0.41 085 5% 0.20 042 i.}Baad xn4 883E-41IWmmBlu EPA 54:24 43.2!------ 50% 27.12 21 61 1.}p 000104rapane <127E-0SlbJmmBN EPA 1,04 083 50% 0.52 0.41 Acetaldehlde 2.79E-03Ib/mm0tu EPA 2282'5 181.90 50% 114.12 9095 Auok0 2671.03 Ibfmmblu EPA 215.18 171.47 50% 10758 85.73 Ben688e 1 58E-03 Ib/mmtitu EPA 12926 103.01 - 50% 64.83 51 51 Carton TetzJ48881 <1.77E-041b'mmBN EPA 145 1.15 58.88 072 0.58 011ordben2,ne 41.29E-051b/mm81u EPA 105 0.44 50% 0.53 042 Cfdcro 8,,, <137E-05Iblmm8lu EPA 1.12 5.89 50% 0.56 045 Eihyiberzene <2.48E-05 IWmm8lu EPA 2.03 1,62 50% _ 1.01 0.81 11611.6100,8,14,, <213E-051b+mm8lu EPA 1.14 135 50% 0.97 069 Parmakteaktdit 2.680.02 itft.a. EPA 143410 10313.54 74% . 40290 129.33 Methanol 3.06E-03Ib/mm&u EPA 25034 199.5 50% 125.17 9975 Methylene 0914,tle 4.12E-051b/mm&u EPA 3,27 2.58 50% 1.69 1.34 NalAahalerta_ <971E-05MImm&u EPA 794 6.33 52% 3,97 317 PAH _--�—1.41E-04Ib/mmBtu EPA 11.54 919---- 50% 5.77 450 --- Styrene <119E-051b4mmytu EPA 0.97 0.78 50% 045 0.39 — Toluene 5.58E-04lblmm&u * EPA 45.65 36.38 50% 22.82 18,19 Vinyl Cbuo.iec <715E-0erofinmBtu EPA 0.59 047 60% 029 0.23 Xylenesim,Pa'' 1.35E-043/10812 EPA 19.95 12.71 50% 758 5.36 TOTAL — <2053 <2116 <091 <710 e80610,41040masan 4<1ce3Pam44 424 Bw9!eu.0I4608)4namas Pam AP<2 Chapter 3.0,9103.2-3.17,001. DCP Operabrt9 Company LP 12110/2019 Engine Emission Calculations Greeley Gas Plant DCP Operating Company,LP Waukesha L 7042 651 Engine C-117/P-123 123/0099/104 4 Stroke,Rich Bum Lint Rabrg: '130 hp BSFC 149501uephr „_- Ma0lmrsn Meat Input. 9 3 mmblu/hr Operat,n0 Schedule. 8'50 5r9r FHV 1 6,40 btu/scf Maumrm Fuel Utt TB.7)mnscityr Year FUN Ilse Heat Value IMMantlyr) fErtuls011 January 4.61 1120.93 February 473 1130 2B March 523 11127, Apnl 5.23 1105 35 May 5.00 109E 80 492 112306 July ... 494 111964 August 4.88 1119964 - Saoterroer 4.88 11616 41 OHcber 4 81 1087.38 november m 4 91 110-2.62 December ---�— --_ 4.85- 110095 Criteria Pollutant Emission Calculations Uncontrolled Controlled Potential Compliance Ends non Factors Potential Emissions Compliance Factors / 1 Emission Factors Emissions Exton Polka. (%oorI el Qb7MMmu) p55/y4 (10.3311 (15IMMBtu) WW1") f4O.e 13.0 gtbhp-co 130.09 338 110.62 2.3 g/bhp-hr 24.00 m 059 21.30 VOC• 0 ghhp-M 5.31 0.13 4.25 0.5_jIbhp-hr 5.31 013 4.26 GO a 90 g/bhp-nr 95.60 2.34 76.59 2.5 9r5nphr_ 26.55 0.65 21.30 PM` 194E-0215/mm8/u 0,79 1.94E-02 0.64 1.54E-02IblmmBIu v 0.75 1 946-02 0.84 50;° 5.88E-041o/mmUtu 0.024 5.88E-04 0,019 5.88E-041b/mmUlu 0.024 5.88E-04 0.013 a Manufacture',errottoor,factor Uncontrolled emission factor:from 4.5000,yo40unrn 145,1 0,.naves lrnm AP-47.C of er 1 Tab411-1.1100, Non-Criteria Reportable Pollutant Calculations ConfrNHd Uncontrolled Potential 1 1* ' r4/' Control Pate I Emissions 'I : Efficiency Emissions Pollutant HAP Emission factors' Data Soars. rib/yr) (ltyyt) X WA Ilbryrl 1.1.2.2-Tebac/4oroethane 2.53E-051blmmCtu EPA 207 1.66 50% 103 083 1.1.2-Tnchloroethane <153E-05ElmmBtu EPA 125 1,00 50% 053 0.50 1,1 Dichbroethane <1.13E-052ImnOtu EPA 0.36 -----_0.14 50% 0.18 0.37 1,20ichloroelhane <1.19E-051tMmm[u _ EPA 0.36 0.74 50% 0.18 037 1,213ichloropropane�-- <I.306.451b/mml§u EPA 0,41 0.85 50% 020 0.43 1.16u1aaene E.63E-0415,mm8tu EPA 54.24 43 45 50% 27.12 21 73 13.0,ehloiopropene 01.27E-051dmm81u EPA 104 083 50% 0.52 - 042 Acetaldehyde 270E-0315/mm81u EPA 228.25 182.85 50°.4 114.12 91.43 Auden 263E-0315/mm Btu EPA 215.16 172.37 50% 107.58 8519 Benzene 158E-031b/mm Btu EPA _ 129.26 10355 50% 54.03 51.78 Carbon TeuaoNa0de 0177E-051M'mmBw EPA 145 1.16 50% 0.72 0.58 Chlorobenzene a 1,29E-0515rmm81u EPA 108 0.85 50'4 053 042 :hrorobrm 0137E-051b/mmBtu EPA 1.12 090 50% 0.56 045 EOrllbenzene 0248E-05Idmm6lu EPA 203 163 50% 191 061 Ethylene Odomide <2.13E-0510/mm Btu EPA 1.74 1.40 50% 087 0.70 F'ofloWrttyda p... 508E-02 Mm+Btu EPA f47T,10 9343.97 ':.lfX IOtW ''222,4# Methanol 3.06E-03 lb/mm Eau EPA 250.34 200.55 50% 125.17 13028 Methylene Chloride 4,12Eff Idmnitu EPA 3.37 270 50% 1.69 135 Naapithalens <9.71E-05 IblmmAtu EPA 7.94 6.35 _ _50% 397 3.18 PAH 1.41E-0415/mm8w EPA 11.54 924 60% 577 4.62 Styrene 01.19605 IDImmVN EPA 097 078 50% 0.49 0.39 Toluene 558E-04INmm81u EPA 4565 3.57 50% '— 21 A2 1829 t'myl Cl4Orde <7.18E-061Wmm81u EPA 059 047 50% 025 0.24 Xyleneump o) 1.95E-04Idmm81u EPA 15.95 1278 50% 798 6.33 TOTAL — 02653 02121 4591 <714 0 Unconeo&d emsswn facto,Avon 4seaka.A0O.ourn 1400 8)engver from AP-42 Chapter 3 Tab/a 1.2-3.17901 078 Midstream 71, 12'102019 Engine Emission Calcutations Greeley Gas Plant DCP Operating Company,LP Waukesha L 7042 GSI Engine C-118IP-124 123/0099/105 4 Stroke,Rich Burn tint R4l,o I'7E hp 85FC _ 8 4.17 btu1p-hr Maximum Neat Input 9.3 mmbtukrr Opera6n9 Schedule 9 700 hrhyr FRO 1 Gtrt blu/sd Maximum Foal Use 78.71mm611lyr Year Fuel Use Neat Value IMMactlyh 18101501) 1anw1 4 74 1178.93 February 469 1130.28 MUM ---- 505 111271 April 523 110633 May 5.16 1098.87 June 4.94 1123,06 Jiiii 494 1119.64 1091.1 4.08 1119.6! September 4.87 1096.41 October 4.86 1087.38 No+ember 4.90 110262 De.:ember 4.84 1100.93 1109,82 Criteria Pollutant Emission Calculations Uncontrolled Controlled Potential Compliance EMsslon Factors Pden0al Emissions Compliance Factor Emission Factors Emissions Factors ' Pollutant Itorrlyrl gbiMMB1u) (Io5yrl (toNyr) IIbIMM&u) ItnrWr) N0<• 13.0 9/bhp-hr 138.09 336 110,73 2.3 9/bhp-hr 24.00 0.59 21.32 607• 0.26 (bhp-hr 5.01 0.13 4.34 0.5 9/bhp-hi 6.31 0.13 4.26 CO• 9.0 9/6hp-he 95.00 234 78.86 25 q/bhp-hr 28.55 0.65 21.32 PM° 1.94E-021Wmm81u 0.79 1,94E-02 0.84 194E-021WmmfAu 0.79 194E-02 0.64 50;° 5.88E-04lblmm&u 0.024 588E-04 0.019 588E-041Nmm6tu 0,024 588E-04 0.019 s ManuhcNrers an..racers unronhoM4.3,33.433 faeces from 49110,3,39,31145•BI 4,9•3.93 hom AP-32.Chapter 3 lade 3.3.3 1790,. Non-Criteria Reportable Pollutant Calculations Controlled Uncontrolled Potential , Control Potential Er issbns ..:'' ? .' ElliOd 0 Emissions Pollutant HAP Emission factor' Data Source OWN) Ilnry0 % IIWy41 110/091 11.22-Tetrachlorcetlaqe 2 5344IblmmBtu EPA 207 1.66 50% f 03 9.83 1,1.2'Tnchloroelhane <1,53E-05 lb/mral3tu EPA 1.25 1.00 50% 063 0.50^— 1,i Dichbroelhare <1.13E-05 IblmT,Btu EPA 0.36 0.'74 !i0% 1.18 9.3/ 12Drchlaoe:hane 41.13E-0516fmm8tu EPA 0.36 074 50% 018 037 72 Enchlmopropa2e 4130E-0SOJmmBtc EPA 04' 085 50% 029 043 1,1PutaMene 663E-04Ib/mm&u --�— EPA 54.24 ---�--4345 50% ----27.12 c 75 T30.c1kroPrope., <127E-051WmrnOtu EPA 1,04 083 50% 052 0.42 Acetaidehy9e 2.79E-031WmmBlu EPA 228.226 183.03 50% 114.'2 9151 4crolem 2,63E-03IWmmB9o EPA 215.'6 17257 50% 10758 86.27 -BBeene 1.58E-031WmmEnu EPA 129.26 10355 50% 54.63 5183 Carbon Tetrachl,de 0 t 775-051WmmBlu EPA 145 1.16 50% 072 0.58 C14orabenzene <1.23E-051b/mm8tu EPA 1.06 0.85 50% 053 042 Chloroform <137E-05161mmBtu EPA 1,12 090 50% 056 045 Ethyibenoene <2.45E-051b/mm81u EPA 203 1.63 50% 1.01 0.81 Ethylene D,5101<de <213E-051Wmm89u EPA 174 1,40 50% 0,87 ' 070 ' FornuM4hyde 2.04602Elmmela EPA 767740 - 138449 781: 40220 :022.74 Methanol 3.06E-03 lblmmUlu EPA 250,34 20014 50% 12517 10037 Methylene Chloride 4.12E-05IWmm6tu EPA 337 270 50% 169 135 Naplihalere <9.71E-05 Ib/mm66. EPA 794 6.37 50% 3,97 3.18 PAN 1.41E-04@/mm61u EPA 11.54 9.25 50% 577 4.62 Styrene <119E-051Wmmi6u EPA 0,97 0.78 50% 049 0.39 Toluene 558E-0410/mm0R EPA 45 E5 3691 50% 22,02 1830 1.93y,CN <on4e 7.108061Wmm94< EPA 0.59 047 50% 029 0.24 Xyleneslm p o) 1.95E-04Ib/1nm61u EPA 15.95 12.19 53% 7.96 640 TOTAL — 02653 42129 4891 4715 unaan0ek4 o,+nvon fa,/,,o 9.333 4.0404.F.c6.bum'45420 470045 from AP42°nearer 3.Table 3.2.3,1700). DOP M0srream LP 12/10/2019 Engine Emission Calculations Greeley Gas Plant DCP Operating Company,LP Waukesha L 7042 GSI Engine C-120/P-126 123/0099/107 4 Stroke,Rich Burn UM Paring !170 hp B5FC 5 Ale leulhiAbr Maermrm Heal Inp.3. 93 hay, hr OPerabrg 3£hOp 90584331 9' FIN. 1 040 brutecl 11u,m,m Fuel Use 747 n+mscoyr Year Fuel Use Heat Value (MMeeflyr) I0lulse5 January 4.57 112093 February 4.5E 113026 Manch 518 111271 April 522 1105.35 May 502 1058.87 Jame 452 1123.06 July 499 111964 aegest 490 1119.64 September 4.37 1096.41 0.0be, (1.50 1007.39 550.0031 423 110262 December *EA 1100,99 Criteria Pollutant Emission Calculations Uncontrolled Controlled Potential Compliance i Emission Factors Potential EndsMons Compliance Factor 1 /i,+ I+ Emission Factors EmIssiees Faeton Pollutant (10010 Bt,1 - (IbIMMul 1100174) Itonlyr) (Ib/MMBIu) palm')) No,' 13.0475hp411 118.09 338 108,24 2.3 g6tpAr 24.00 055 24.64 t13C' 0.5grthphr 631 0.13 4.16 0.5,g6hpre , 631 0.13 4.17 CC' 9.0 grthpfir 85.60 _ 2.34 74.94 25 gro"eAr 26.55 0600 20.84 _ PM' 15.4E-0215/mm81u 0.79 - 1940-02 _ 0.62 1.940.02 Ib/m:nBtu ' 079 194E-02 0.62 - 8707"-- 5.680.044btmmatu 9.024 589E-04 0.019 5.88E-04 Inlmm6tu 0.024 5.38E-04 0.019 l Malutantwart ernacere factory 'Uneonl,41.3,roann facets tram 4381,64 Rr7-bum ASP 8(animas Nun 4P-t2 Cheoter 3 Table 3.2-3(7:'001. Non.Crilerie Reportable Pollutant Calculations Controlk t Uncontrolled Potential Ii y Control Potential Endsabns I `' E11KIeney Emissions _ Pollutant HAP Emission factors Data source pwyr) 8040 Y. 0eryrl 16121 112.2.fetraellor0Hhane 2.53E.CMlbenen Btu EPA 2.07 162 50% 1033 081 I12Tnchc,oethane <1.53E-05 QNmm0lu EPA 125 0.98 50% 053 0.49 ',.1Cichbroemar. <113E-05Ib/mmBlu EPA 0.36 072 50% 0.19 0.36 12 Cichkmed.ane <1.13Et0<I6/mmftu EPA 0.36 0.72 50% 0.18 030 12thio rcpane <1.30E-05Ib/mmOtu - EPA 041 083 35% 0.20 042 1 3-8Jadiaro 6.63E-04 lbenm8lu EPA --- -Sd24 ---- 4252 50% 27.12 2126 13pnioropropeee <1.27E-05 lb/mint-8u EPA 1354 081 50`4 052 0.41 Acetaldehyde 2,79E-03R1mmBN EPA 228.25 17893 50% 114.12 8946 _ Acmmeet 263E-031F1mmBIu EPA 215.166 168.16 50°6 10758 8433 5an7n0e 1.58E-03lb/mmBlu EPA 129.26 101.33 503,E 64.63 5.66 Carbon Tetrachloride 81.77E-05 Ib/mm8tu EPA 1A5 1.14 50% 0.72 0.57 Cldornbeniene e 1.29E-05Ib/mmatu EPA 106 0P3 53°6 053 0.41 0W8+olone <137E-05M/mnl8tu EPA 1.12 088 50% 056 0.44 Ethylbeot 248E-05lb/mm&u EPA 203 159 50% 101 0.90 Ethylene 08,08. <2130f5ib/mmEttu EPA 174 137 50% 087 068 EorRWeehy4a 005E.02OsImnBI4 EPA 1677.10 1344.44 76% 402.36 315.62 Methanol 3.06E-03It/mmBiu EPA 2€5.34 196.24 50% 125.17 98.12 Methylene Chloride 412E-05Ib/mmBtu EPA 3.37 2.64 50^:, ---769 132 Naphthalene <9.71E.05161mm Btu EPA 7.94 6.23 50% 39 3.1, E-9 ....._... Pnit 141 ,4 Eimm6w EPA 0.97 904 50% 5 9 432 Styrene e 1.19NJ510/mmBlu EPA 0.97 0..5 50% 044 038 Toluene 55,3E-04 lb/mm Btu EPA 45.55 35.79 50% 22.82 17.09 Vmyl CWorde <7,18E-0Mbtmm0tu EPA 0.55 0.46 50% 029 023 Xyienes(m.pot 1.95E-041b/mmBtu EPA 15.95 12.51 50% 7.98 6.25 TOTAL — €2603 <2001 7 691 €690 3menbo9e4enss:u74040101ram 4smad 0,81,50.,143_,004101 nom AP-22.Chaps,3 Tate 8.2.3.179, 0CP 44511,am.LP 12/102019 Engine Emission Calculations Greeley Gas Plant DCP Operating Company,LP Waukesha L 7042 CSI Engine C-122/P-124 12310099/110 4 Stroke,Rich Bum Una Haur9 1 100 hp 8550 __ 8431 blwhp-hr _ Manmum Heat Ir-F1 93 mmw bhr i:per Wing Schedule 8-'50 rely, EM/. 1040 gWacf }Acorn.,Fuel tlse 78/immacliyr Year Fud Use Heel Value (MMsnlyr) (Moist/ Janw•y 457 1120.93 February 4.58 113028 March 5.22 1712.71 April 5.22 1105.35 ___ Mar 504 1098.B, June 4.90 1123 06 July 499 11196) lwgust—..__�..v. 4 79 1119 64 September 4.45 1096.41 October 483 1087,38 November 479 1102,62 December 4.80 1100.99 .... 58.28 1109.8 Criteria Pollutant Emission Calculations Uncontrolled Controlled Potential Compbnee Evisslon Factors Potential Emissions Compliance Factors /^' Emission Factors Emissions Faeton Pollutant (Iadyt) (PoIMMBtu) (lordyr) (ten/yt) (IbIMMetu) 1100126) NO,. 130 gibhph1 136.09 33$ 109.16 2.39.81phr 24.06 059 21.02 HOC• 0531bhP'ty 6.31 0.13 4.20 OS otho-hr 5.31 0.13 4.20 CO' 9 0 ybhyhr 95.60 2.34 75.97 2 5 ol.p.4 r 26.55 0,65 21.02 PM' ' 194E-02I0/mmUlu 0.79 154E-02 0.63 1.94E-02ldmm&u 6.79 , 1.94E-02 0.63 SO,' 5.88E-04tb/mmeIu 0.024 568E-04 0,019 583E-04lbtmm&u 0.024 588E-04 0.019 •Mameacho4rs am»anc 43010 •UnconUob4 anass.cn heron from 4.01,540 Rch-CVin:;4588,anymes from AP-42.Chatter 3.Ta W 0.1.3.77/00i Non-Criteria Reportable Pollutant Calculations Controlled Uncontrolled Potential Control Potential Evictions 1 . Efficiency Emsslons Iayr Pollutant HAP Emission tenors° Data Source ( ) 11 'a (1N 0/yWY," RNA 111122,TeoacNarcrthane 253E-051b/mmOtu EPA 207 1,64 500% 104 0,82 812-Tncl6oroethane 41.53E-0ti1blmmBlu EPA 1.25 __ 099 550%, 063 0.49 11 Dchlomelhane 5 1.13E-0O Ib/mmEllu EPA 036 0.73 50% O1B 037 12 Dchtcr000 are <1.13E-05Ib/mmBlu EPA 0.36 0.73 50% 0.18 0,37 1200shlor5isom1e_ _ <1.30E-05 lb/mmtku EPA 041 0.84 50% 0.20 042 4 1.3-094196 y/ 5.83E-041b/mmBtu EPA 5.4 S.34 _ 01242 88 00'12 05227 21 1 1.3Pchloropr_pe•= <1 270-05 lbmmetu EPA 1 Ua 0.82 50k 052 041 Acetaldehyde 279E931b/mm81u EPA 128.'7 190.44. 50% !14.14 90.23 Acrolen 263E-0310/mm6tu EPA 215.18 170.10 50% 107.59 6,06. Benzene 1:X86-03 ib/mmOtu EPA 129.27 102.19 `80% 04 64 51.10 Carbon Tele,Hwlde <t 77EdYlbrmm8tu EPA 1.45 1.14 50% 072 C57 Chlotober,0ene -__ 41.29E-05Iblmm0tu EPA 106 0.83 50'6 053 C,42 chloroform 4137E-051b/mmBtu EPA 112 0400 5082 0.56 0.44 Ethllhencene 4248E-05IbImmBtu EPA 203 1.50 50% 1.01 C.80 Ethylene abromide 0 213E-05lblmmBlu EPA 1.74 138 50% 0 87 0.69 HOnrWMkyne 2.09E420enno800 EPA 167729 4303.01 74% 402-59 .319.22 Methanol 3.06.03 lb/mm8tu EPA 250.36 19792 50% 125.18 99.96 Mnhtkne Chloride 412E-05WlmmBtu EPA 3.37 2.6E 50% 169 1.33 Naphthalene 09.71E-05)bImmBlu EPA 7.94 5.28 60% 3.97 1414___ PAH 1.41E-04Ib/mmetu EPA 11.54 9.12 5050 5.77 4.5E Styrene ' <1.19E-05 1871111668 EPA 0.97 0 77 50% 049 0.38 Toluene 5.58E-04IblmmBtu EPA 45.55 3609 50% 22.83 18.05 MnylCNonde <7.18E-06 leim0Btu EPA 0,58 0.46 50% 0.29 023 I 6ykrcs(m p 0, 1.95E-04IblmmBlu EPA 15.95 12.51 50% 7.98 6.31 TOTAL — 42654 42099 <191 <705 •Uoscohe44enassae,hews ham 4-ozone R<e-Mm,4SRP rot ,l,on,4G42.J.apto03.Table 12-3/T,W,. DCP 5Mdsheam LP 12002019 Supporting underlying portable analyzer test data available upon request. Portable Analyzer Test Results 4th QRT 2019 Greeley Gas Plant Exhaust Flow Rate scf/hr=8710 scf/MMBtu* Fuel Consumption MMBtu/hr* 20.95%/(20.95%-O2°%o) Fuel Consumption MMBtu/hr = Fuel Consumption(scfihr)* Fuel Heating Value(Btu/scf)/ 1,000,000(Btu/MN Emissions(lb/hr)=measured ppmv/ 1,000,000* Exhaust Flow(scfi'hr)* mot. wt. (Ib/Ibmol)* 1 (lbmol)/385.33 where: molecular weight CO = molecular weight NOx = Test Data Results(see attached): Title V 1D No. P-122 P-123 P-124 P-126 P-I29 Field ID No. C-I 16 C-117 C-118 C-120 C-122 Serial Number 368993 337569 286434 388531 260928 Engine Stack Test Date 10:18/2019 10!18/2019 10 18%2019 10./21!2019 10'21/2019 Meas. Conc.O2% = 1.01 2.02 0.81 1.25 0.7 Meas. Post-Converter CO ppmv = 33.227 86.043 284.96 189.364 173.636 Meas. Post-Convert.NOx ppmv = 116.545 45.652 24.62 93.091 230.045 Normal Fuel Heat Value Btu/scf = 1003.95625 1003 95625 1003 95625 1003.95625 1003,95625 Max. Fuel Consumption(scfihr) = 8984 8984 8984 8984 8984 Max. Fuel Consump.(MMBtu/hr)= 9.02 9.02 9.02 9.02 9.02 Max. Exhaust Flow Rate(scf/hr) = 82539.4 86943.3 - 81719.8 83545.0 81275.9 Max. Meas.CO Emiss. Rate(lb/hr)= 0.2 0.5 1.7 1.1 1.0 Permited CO Emiss. Limit(1b/hr) = 6.06 6.06 6.06 6.06 6.06 Compliance with Hrly CO Limit YES YES YES YES YES Max. Meas.CO Emiss. Rate(tpy) = 0.9 2.4 7.4 5.0 4.5 Permited CO Emiss. Limit(tpy) = 26.55 26.55 26.55 26.55 26.55 Compliance with Yrly CO Limit YES YES YES YES YES Max. Meas.NOx Emiss.Rate(Ib/hr)= 1.2 0.5 0.2 0.9 2.2 Permited NOx Emiss. Limit(lb/hr)= 6.06 6.06 6.06 6.06 6.06 Compliance with Hrly NOx Limit YES YES YES YES YES Max. Meas.NOx Emiss. Rate(tpy)= 5.0 2.1 1.1 4.1 9.8 Permited NOx Emiss. Limit(tpy) = 26.55 26.55 26.55 26.55 26.55 Compliance with Yrly NOx Limit YES YES YES YES YES Supporting underlying portable analyzer test data available upon request. Portable Analyzer Test Results 3rd QRT 2019 Greeley Gas Plant Exhaust Flow Rate scf/hr=8710 scf/MMBtu* Fuel Consumption MMBtu/hr*20.95%/(20.95%-02%) Fuel Consumption MMBtu./hr = Fuel Consumption(scf'hr) * Fuel Heating Value(Btu!scf),/ 1,000,000(Btu/MN Emissions(lb/hr)=measured ppmv/1,000,000 * Exhaust Flow(sct7hr)* mol. wt. (lb/lbmol) * 1 (lbmol)/385.33 where: molecular weight CO = molecular weight NOx = Test Data Results(see attached): Title V ID No. P-122 P-123 P-124 P-126 P-129 Field ID No. C-116 C-117 C-118 C-120 C-122 Serial Number 368993 337569 286434 388531 260928 Engine Stack Test Date 7/23/2019 7/23/2019 7%23,2019 7/24/2019 7/24/2019 Meas.Conc.02% = 0.46 2.05 0.77 0.9 0.41 Meas. Post-Converter CO ppmv = 74.727 28.773 49.09 48.318 183.955 Meas. Post-Convert.NOx ppmv = 9.864 93.364 99.96 261.818 91.5 Normal Fuel Heat Value Btu/scf = 1096.3981 1096 3981 1096.3981 1096.3981 1096.3981 Max. Fuel Consumption(scf/hr) = 8984 8984 8984 8984 8984 Max. Fuel Consump.(MMBtu/hr)= 9.85 9.85 9.85 9.85 9.85 Max. Exhaust Flow Rate(scf/hr) = 87719.9 95099.5 89067.5 89644.9 87506.4 Max.Meas. CO Emiss.Rate(Ib/hr)= 0.5 0.2 0.3 0.3 1.2 Permited CO Emiss. Limit(Ib/hr) = 6.06 6.06 6.06 6.06 6.06 Compliance with Hrly CO Limit YES YES YES YES YES Max. Meas.CO Emiss.Rate(tpy) = 2.1 0.9 1.4 1.4 5.1 Permited CO Emiss.Limit(tpy) = 26.55 26.55 26.55 26.55 26.55 Compliance with Yrly CO Limit YES YES YES YES YES Max. Meas. NOx Emiss.Rate(lb/hr)= 0.1 1.1 1.1 2.8 1.0 Permited NOx Emiss.Limit(Ib/hr)= 6.06 6.06 6.06 6.06 6.06 Compliance with Hrly NOx Limit YES YES YES YES YES Max. Meas.NOx Emiss.Rate(tpy)= 0.5 4.6 4.7 12.3 4.2 Permited NOx Emiss.Limit(tpy) = 26.55 26.55 26.55 26.55 26.55 Compliance with Yrly NOx Limit YES YES YES YES YES Supporting underlying portable analyzer test data available upon request. Portable Analyzer Test Results 2nd QRT 2019 Greeley Gas Plant Exhaust Flow Rate scf'hr=8710 scf/MMBtu* Fuel Consumption MMBtu./hr* 20.95%/(20.95%-O2%) Fuel Consumption MMBtu/hr = Fuel Consumption(scf/hr) * Fuel Heating Value(Btu/set)/ 1,000,000(Btu/MN Emissions(Ib/hr)=measured ppmv/ 1,000,000 * Exhaust Flow(scf'hr)* mot.wt. (lbllbmol)* 1 (lbmol)/385.33 where: molecular weight CO = molecular weight NOx = Test Data Results(see attached): Title V ID No. P-122 P-123 P-124 P-126 P-129 Field ID No. C-116 C-117 C-118 C-120 C-122 Serial Number 368993 337569 286434 388531 260928 Engine Stack Test Date 4/152019 4 15 2019 5/6.2019 5/7/2019 5'9 2019 Meas.Conc.O2% = 0.22 1.69 0.35 0.71 0.72 Meas. Post-Converter CO ppmv = 1 1.7 3 438.77 33.91 42.364 759.682 Meas.Post-Convert.NOx ppmv = 2.68 287.09 10.68 367.636 328.318 Normal Fuel Heat Value Btu/set= 1096.87 318 1096.87 318 1096.87'18 1096 87118 1096.87 318 Max. Fuel Consumption(scf,•'hr) = 8984 8984 8984 8984 8984 Max.Fuel Consump.(MMBtulhr)= 9.85 9.85 9.85 9.85 9.85 Max. Exhaust Flow Rate(scf/hr) = 86741.9 93362.4 87289.3 88841.9 88885.8 Max.Meas.CO Emiss. Rate(lb/hr)= 0.1 3.0 0.2 0.3 4.9 Permited CO Emiss. Limit(lb/hr) = 6.06 6.06 6.06 6.06 6.06 Compliance with Hrly CO Limit YES YES YES YES YES Max.Meas.CO Emiss.Rate(tpy) = 0.3 13.0 0.9 1.2 21.5 Permited CO Emiss. Limit(tpy) = 26.55 26.55 26.55 26.55 26.55 Compliance with Yrly CO Limit YES YES YES YES YES Max.Meas.NOx Emiss.Rate(lb/hr)= 0.0 3.2 0.1 3.9 3.5 Permited NOx Emiss. Limit(liar)= 6.06 6.06 6.06 6.06 6.06 Compliance with Hrly NOx Limit YES YES YES YES YES Max.Meas.NOx Emiss.Rate(tpy)= 0.1 14.0 0.5 17.1 15.3 Permited NOx Emiss.Limit(tpy) 26.55 26.55 26.55 26.55 26.55 Compliance with Yrly NOx Limit YES YES YES YES YES Supporting underlying portable analyzer test data ON ailable upon request. Portable Analyzer Test Results 1st QRT 2019 Greeley Gas Plant * * 20.95%/(20.95% 0- Exhaust Flow Rate scf/hr=8710 scf/MMBtu Fuel Consumption MMBtulhr -O2 ro) Fuel Consumption MMBtulhr = Fuel Consumption(scf'hr) * Fuel Heating Value(Btu/scf)11,000,000(Btu/MN Emissions(lb/hr)=measured ppmv/ 1,000,000*Exhaust Flow(scf/hr) * mol.wt, (Ib/Ibmol)* 1 (Ibmol)/385.33 where: molecular weight CO = molecular weight NOx = Test Data Results(see attached): Fitle V ID No. P-122 P-123 P-124 P-126 P-129 Field ID No. C-116 C-I 17 C-118 C-120 C-122 Serial Number 368993 898468 286434 337569 260928 Engine Stack Test Date 2/25 2019 2 25;'2019 2/25 2019 2 28 2019 2/28 2019 Meas.Conc.O2% = 0.67 1.06 0,41 0.74 0.1 Meas. Post-Converter CO ppmv = 18.5 287.18 25.59 30.32 381.09 Meas. Post-Convert.NOx ppmv = 5.09 276.09 50.82 381.73 133.41 Normal Fuel Heat Value Btu/scf - 1 100.13222 1 100.13222 1100.13222 1100 N222 1100 H222 Max. Fuel Consumption(scf/lu) = 8984 8984 8984 8984 8984 Max. Fuel Consump. (MMBtu/hr)= 9.88 9.88 9.88 9.88 9.88 Max. Exhaust Flow Rate(scf/hr) = 88930.1 90673.8 87804.4 89238.1 86498.9 Max. Meas.CO Emiss.Rate(Ib/hr)= 0.1 1.9 0.2 0.2 2.4 Permited CO Emiss.Limit(1b/hr) = 6.06 6.06 6.06 6.06 6.06 Compliance with Hrly CO Limit YES YES YES YES YES Max. Meas.CO Emiss.Rate(tpy) = 0.5 8.3 0.7 0.9 10.5 Permited CO Emiss.Limit(tpy) = 26.55 26.55 26.55 26.55 26.55 Compliance with Yrly CO Limit YES YES YES YES YES Max. Meas. NOx Emiss. Rate(lb/hr)= 0.1 3.0 0.5 4.1 1.4 Permited NOx Emiss.Limit(lb/hr)= 6.06 6.06 6.06 6.06 6.06 Compliance with Hrly NOx Limit YES YES YES YES YES Max. Meas.NOx Emiss. Rate(tpy)= 0.2 13.1 2.3 17.8 6.0 Permited NOx Emiss. Limit(tpy) = 26.55 26.55 26.55 26.55 26.55 Compliance with Yrly NOx Limit YES YES YES YES YES PRESSURIZED TRUCK LOADOUT EMISSIONS(P135) Greeley Natural Gas Plant DCP Operating Company,LP Calculation of Potential VOC Emissions from Propane,Butane,B-G Mix,Y-Grade,Isopentane,Natural Gasoline and Condensate Truck Loading Losses Assumptions: There are two hoses connected to each truck during loadout. Liquid Hose Diameter = 2.0 inches Vapor Hose Diameter = 2.0 inches Liquid Hose Length = 1.5 feet Vapor Hose Length = 2.0 feet Liquid Hose Volume = 0.0327 cubic feet Vapor Hose Volume = 0.0436 cubic feet Each truck is pressurized to storage tank pressure as listed below. Propane Tank Pressure= 204.4 psia Butane Tank Pressure = 57.4 psia B-G Mix Tank Pressure= 22.4 psia Y-Grade Tank Pressure= 212.4 psia Isopentane Tank Pressure= 22.4 psia Natural Gasoline Tank Pressure= 22.4 psia Condensate Tank Pressure= 52,4 psia Tot.volume of products loaded/year and tot.loadout events/year as listed below. Product loads/yr bbl/yr' gal/yr Propane Loaded Out 7,215 1,717,857 72,150,000 Butane Loaded Out 6,391 1,521,667 63,910,000 8-G Mix Loaded In 1,787 425,476 17,870,000 Y-Grade Loaded In 4,675 1,113,095 46,750,000 Isopentane Loaded Out 976 232,381 9,760,000 Natural Gasoline Loaded Out 2,908 692,381 29,080,000 Condensate Loaded Out 611 145,476 6,110,000 Total loads/yr(Max Annual)2 24,563 5,848,333 245,630,000 Current TV Limits 56,000 13,333,333 560,000,000 Potential loads/yra 56,390 13,426,175 563,899,338 Arsenal throughput Ibbl/yr)=loads/yr•10.000 gallons/load•1 gallon/42 bbl Mao annual product throughput(loads/yr)represent maximum rolling-12 throughput values for each product.starting 5/1/1999 3 Potential loads/yr represents maximum potential loadout events under retained VOC emission llm't of 43.15 tpy All liquid lines contain liquid products at individual specific gravity. All vapor return lines contain products that behave as Ideal Gases at 60 deg.f and storage tank press. P•V=n•R•T Where: P=pressure in hose at time of disconnect=storage tank pressure(psig) V=volume of hoses(cubic feet) n=number of lb-moles of product in hoses R=universal Gas Constant=10.73 cubic feet`psi/Ibmol`deg R T=axe loadout temp. = 60 deg F = 519.67 deg R Propane: n= 0.0367 Ibmol/ft"44 Ib/Ibmol = 1.6127 lb/ft' Butane: n= 0.0103 Ibmol/ft'•58 Ib/Ibmol = 0.5968 lb/ft' B-G Mix: n= 0.0040 Ibmol/ft'•58 Ib/Ibmol= 0.2328 lb/ft' Y-Grade: n= 0.0381 Ibmol/ft'"12.1 Ib/Ibmol= 0.4609 lb/ft' Isopentane: n= 0.0040 Ibmol/ft'•71.7 lb/lbmol= 0.2878 lb/ft' Natural Gasoline: n= 0.0040 Ibmol/ft'•73.5 lb/lbmol= 0.2950 lb/ft' • Condensate n= 0.0094 Ibmol/ft'•94.1 Ib/Ibmol= 0.8840 lb/ft' • Potential VOC Emissions(Loading and Unloading) Liquid Hoses Vapor Hoses Total Emission Annual Lig.Density Hose Vol. :mission Factor Vap.Density Hose Vol. Emission Factors Factors Emissions.' Product (lb/ft') (fta) lb/load (lb/ft) (ft') lb/load lb/load tpy Propane 31.78 0.0327 1.04 1.6127 0.0436 0.07 1.11 0.00 Butane 36.20 0.0327 1.18 0.5968 0.0436 0.03 1.21 0.00 B-G Mix 46.15 0.0327 1.51 0.2328 0.0436 0.01 1.52 0.00 Y-Grade 46.15 0.0327 1.51 0.4609 0.0436 0.02 1.53 43.15 Isopentane 38.97 0.0327 1.28 0.2878 0.0436 0.01 1.29 0.00 Natural Gasoline Liquids(NGL) 46.15 0.0327 1.51 0.2950 0.0436 0.01 1.52 0.00 Condensate 46.15 0.0327 1.51 0.8840 0.0436 0.04 1.55 0.00 Total: 43.15 a In order to provide the most conservative estimate of potential loadout emissions,all throughput was assumed to be Y-Grade in the above emission calculations.Y-Grade sees considerably more throughput at this source than condensate. Potential HAP Emissions(Loading and Unloading) Emission Factors Emissions HAP wt%s (lb/load) (Ib/yr) HAP Natural Gasoline n-Hexane 15.04% 2.30E-01 12981 Benzene 1.97% 3.01E-02 1699 Toluene 1.23% 1.88E-02 1060 Ethylbenzene 0.03% 4.85E-04 27 Xylene 0.16% 2.47E-03 139 • 2,2,4-Trimethylpentane 0.35% 5.39E-03 304 Methanol 0.001% 1.84E-0S 1.0 Total HAPs 0.29 16,212 s 1/15/2019 501 extended liquid analysis 1 • Colorado Department of Public Health and Environment Form APCU-IO2 Air Pollution Control Division A C D P H E LIFacility Wide Emissions Inventory Form CO Vet April,2015 (lonlpany Some:1)071'Oporannp('01nµ090.LP tet o source Name:Greeley Gat,Plant TOO S,oreo AIRS In:121/0049 Ilncunlralltd Poltnliul 19 Emil(Pm C'onlrulled Pureminl to 2 alit(PTY) Criteria 111'7) I 11A1'r 11600,,) criteria((P1'1 1 IIAP,(IOc/yrl AIRS 111 1 ly 1 .,,pl90 10)' 1 PSIIU 1 Paul 502 I SO, I VOL CO I 11C110 I .1culul 1 Airs 1 02 Tul E0 0yl 1 n-11,5 1 01,16 1224-1411' 7SY 1111 flSO ,' I 1181 CO 1116117 Atnu1 1 Itrra I 135, 761 Yn Syl n-Iles 1 51,3) 'TOP 1214- 023/0'099,303 E11t 0,1I6122 079 0,!. 079 J 602 11909 5:11 9500 1677 228 215 129 4,�. 16 0 250. 0 419 079 0 79 001 24 TI 531 2655. 403 14 0 a 0 4125 U 112/0090'104 Rayne C-1174-121 0.79 0.79 0.71 902. 13809 5'11 95.60 1677 218 21 129 46 . 2 I6 0 250 0 0.79 079 079. 0,02 2400 531 -'16551 403 II4 108. 95 1,l 5 0 125 0 123/0090/105 tape C-1124°-124 079 079 0 79 002 039.09 531 95.60 1.67' 228 215 129 44 2 IO 0 210 0 079 074 079. 002 24.00 531 2655 1 403 114 Inc 05 21 8 0 121 0 17178611(10n I (11-'1'175 0/1 179 1170 11172 13137 511 0/0, 1.077 02, 41, 10, 40 2 1/ 0 250 (r 0.79 099 079 002 21 74 571 44551 401 114 10/9 6i 23 8 0 125 0 123/0099:16') Enann<Ca-0,P-126 079 070 079 002 11s.09 531 9560 1677 228 215 129 46 2 16 0 250 0 079 079 070 002 24 613 5.11 26051 403 114 168 65 23 9 0 125 0 123/00400)10 tonne 0.12243.129 079 079 0.79 002 11809 501 90000 1,677 222 215 220 46 In 0 207 6 0.79 0 29 0.79 002 24.00 501 .26.551 403 114 109 65 23 8 0 115 0 171/M99/103 101.400 C-1211,127 9215 01.5 7 055 162 112 17 I II 7707 1 315 I4,, I;5 145 3 0 7 2 1'1 204 0 0.05 0 5 12 l 865 43_ .30 1 5_9 03 en 05 37 _ 13 •1/4 11120070,M 20,9( 1121 0.08 008 1108 [1761 950 1,2,1 1611 171 24 41 la 27 ,N 0B 01 10 4.2_ 1 41 32 II 7 2 t I3II 123,'49'109 1 I 1-128 07. 070 0 0.02 1181. 541 05(0 1077 720 215 43_ 10 0 251 r 1 7Y ,. 21'24 _31 55 401 114 05 0/ 1 10 0 125 0 7 7.111 II 10 1 1,41,642123,02 000 0 011 0 00 1100 110 045 r.e0 _0 U 0 n 413 2 12 4% ' 14 0 0, 100 000 0 041 014 0 02 0,1 I o , 101 5 11 4 2 n U 121, 9 3 11112111.4 210 1199(6( 1148 049 048 004 6 l 15 5'1 0 f1 0 207 0 0 04) 0.40 0.45 '04 2,32 030 53) 1 9 1l 0 0 227 0 0 12206049a 35 rse<4')vOL�wMn '000. 0.00 000 0011 0044 .4315 0 00 0 0 0 1:691 1,060. 27 I39. 12081 1 I 304 0 00 000 41.00 000.. 1060, 430115 0.00 ` 02. 0 0 1,6'/9 :1,0,60 2 1,.3. 110 11 ll O 1 tl'.de III III 1 I I 4/'l 11 0111 1 in 22 0 1 > 0 14"a)hh/7 i14".pus! 7 41 3,911 1. sI / Silgniyii a)'�la.d6e 3"60 ' ono^-ooa 1"ro� 112 0 0 0 0 0 1.352 1,467 97 11+1 7101, 9 12 6.0o- 000 :9.61 gob 0216 iv 14 ono I .0 0 .125 1621 4 01 Ghl 1 1 Iv,0.49Z2 blare 001 001 001 000 202 3.64. I3 33 0 0 0 2,379 1,049 31 - 11761 0 0 fl 01 001 - 001 one 262 111, II26, 0 0 0 119 1112 - 19 587 'I Permitted Sou.re.5400401-- 9.9 7.9 '.9 0.3 1112.2 6010 797.1 113.314 1,901 1,7114 7,408 5,373 027 1,117 37,706 1.992 316 7.9 7.4 7.9 U3 197.9 lin.R 131_I 13_2') 904 8.2 3,597 1.533 42 142 14.486 1,095 311. sec's Oply-Permit 2:5661'1 SOarce5 1 1 i 1 IIIIIIIII MIIMIIIIIII I I A1'1!74 Only Subtotal- 00 0.0 0.0 0.0 0.0 0.0 0,0 I 0 0 0 0 II 0 0 11 0 11 00 0.0 0.0 00 0.0 00 0.0 I n 0 0 0 0 n 0 11 0 0 /3112,,Exempt 1 Insignificant sources 1,1.89,1.00 Acnr1101 0u 00 110 011 ,, 129 00 9 0 u 21 0 G 15_ _71 0 00 ..0 0.0 00 3.8 100 52 0 11 0 31 0 0 2 /52 271 U ..-1luion15cnnl 5461401- 0.0 0.0 0.0 031 4.4 111.9 5.2 0 0 0 10 u 0 0 152 273 0 U 0 2 0.11 0.0 00 _64 10.9 0.2 U 11 0 11 0 41 0 252 273 0 1.01.411 766096a-1 7.9 I 7,9 1 7,9 1 03 I 1119,1 1612.5 1 017.3 1 13,314 I 1,400 1 1704 1 7,429 1 5.322 1 115 1 1.117 1 31,80'1 2,267 1 314 1 7.2 I 7.9 I 7.0 I 0,3 1 204.7 1127.7 1 242.4 1 3,21'4 I 904 I 852 11,570 I 1,533 I 42 I 244 119,134 I 1,368 I 405 1lecon0rnlled 333,1101600371 0,111 6.7 I 11.9 I 0.9 I 3.7 I 1.7 I 0.1 1 0.6 I 16.4 I 1.1 I 0.3 I Cost(olled'IAPN Summar,(TPl'1-I Co I 0,5 I 0.4 I 1.3 I 0.8 J 0.0 I 0.1 I 7.4 I 0.7 I 0.2 Uncunlro11e01.06I,A1111.6P,01012 I 33.1 I C'anlra6rd 2,181.All 11.103,I1111-1 13.1 I Footnotes: I This tbrm,hold he completed to include both exi»ing sources and all proposed new o1 nutd,I:0011on,10 existing C1111s,wn.110311400 - 2.lithe en16,4125/621/0100,1.5 new then enter 0110195004"under the Wood No.and AIRS II>data column, 3 I0AP abbreviations include: a%-00000ne 224-TMP=22 4-T rimethylpentane Tol-'Iolurnc Acetal-Acetaldehyde FR-t:thylbendenc :Acro=A0rleln X31-Xylem n-llea=n-I le9ant 11('110=Formaldehyde Meth-Mcllunol 4 A000 F:9cnlpt/In,9lyni iicant tinuru5 should he included uhcn o,orrantod PCP Operating Company,I.I. 17/18J2019 Page 1 of 1 1. Summary of Emission Units 1.1 The emissions units regulated by this permit are the following: AIRS Plant Description Size Pollution Construction Stack Identifier Control Permit Number Device 104 C-117 Waukesha Model L-7042 GSI Natural Gas Fired 1100 HP Non-Selective 85WE337-2 Internal Combustion Reciprocating Engine. 4-cycle, Catalytic Turbocharged. Standard Rich Burn w/ air/fuel ratio Reduction controller; Serial No. 898168337569; powering a natural gas compressor 107 C-120 Waukesha Model 1,-7042 GSI Natural Gas Fired 1100 I1 Non-Selective 87WE235-1 Internal Combustion Reciprocating Engine, 4-cycle, Catalytic Turbocharged, Standard Rich Burn w/ air/fuel ratio Reduction controller: Serial No. 337569388531: powering a natural gas compressor 115 P135 NGL, Propane, Butane and Y-Grade Truck Load-out 5x60- Block valves 90WE048-2 or Pressurized Product Truck Loadout Rack M-Mgallons5 6,390 loads per year Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: May 1, 2009 LAST REVISED: September 6, 2017 Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 26 SECTION II - Specific Permit Terms 1. Internal Combustion Engines—Subject to CAM C-116, C-117, C-118, C-119, C-120, C-152, C-122 —Waukesha L-7042GSI 1100 HP Compressor Engines NOTE: The following terms and conditions apply to each engine individually Parameter Permit Compliance Compliance Emission Monitoring Condition Limits Factor Number Method Interval C-116,C-117,C-118,C-120&C-122—Waukesha 1,-7042C:81 1100 IIP Compressor Engines NOx 1.1 26.5524 00 tons/year 0-€5059 Ih/MMBtu Record keeping Monthly and CO 26.55 tons/year 0.65 lb/MMBtu Calculation 12 month rolling total VOC 5.31 tons/year 0.13 lb/MMBtu Natural Gas 1.2 78.7 MMscf/year Plant Fuel Meter Consumption ti 12 month rolling total C-119&C-152—Waukesha L-7042GS1 1100 111'Compressor Engines NOx 1,l 21.24 tons/year 0.519 Ib.AIMBtn Record keeping Monthly and CO 26.55 tons/year 0.649 lb/MMBtu Calculation VOC 5.31 tons/year 0.130 lb/MMIltu 12 month rolling total Natural Gas 1.2 78.7 MMscf/year Plant Fuel Meter Consumption 12 month rolling total Btu Heat 1.3 ASTM or other Semi-Annually Content Division Opacity 1.4 Not to Fscecd Fuel Restriction only Natural Gas is 20°0 Used as Fuel • Operation & 1.5 #`er• Maintenance Operating 1.6 Recordkeeping Monthly Hours Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: May 1, 2009 LAST REVISED: September 6, 2017 Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 27 5. P133 —Fugitive VOC Emissions from Fractionation and Natural Gas Liquids (NGL)Processing Plants Parameter Permit Compliance Compliance Emission Factor Monitoring Condition Limits Number Method Interval VOC 5.1 10.437.3 By Component-EPA Protocol for Recordkeeping.and Ongoing Tally, tons per Equipment Leak Estimates Emission Calculations Annually year Gas EPA/l)iYisaw Approved Annual Anal)sis Methods Statexc ide 5-2 Complies by meeting 40 CFR 60 Subpart 0000 NSPS Controls of See Condition 5.2 Oil and(ias Operations 40 CFR 60. 553 3 Subpart KKK See Condition 5.3 NSPS 40 CFR 60. 5_4 See Condition 5.4, Subpart OOOO x: NSPS 40 CFR 60. 55 See Condition 5.5 Subpart A NSPS Per Subpart KKK Maintenance Plan {)eteceic-r+- and Repair 5.1 VOC emissions shall not exceed the limitations stated as set by Colorado Construction Permit 90WE048-1 and modified under the provisions of Section I, Condition 1.3. Emissions shall be calculated using the emission factors and equations listed below. An actual physical hard count of the existing components shall be performed at least once every five (5) calendar years. Records shall be kept of all component additions and deletions and a running tally maintained. The records shall be kept at the site and made available for Division review upon request. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: May 1, 2009 LAST REVISED: September 6, 2017 Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 28 Emission Factors for individual types of components in lbs/component-hr from the reference Protocol for Equipment Leak Emission Estimates, EPA, November 1995, EPA-453/R-95-017. These emission factors are fixed until changed by established permit modification procedures. The below factors are for gas service only. alves 0.00992 Connectors 0.00014 Relief Valves 0.01910 Open ended Lines... 0.00441 Compressor Seals 0 .01910 Pump Seals............ 0.00529 Flanges 0.00086 Emission Factors (lb/component-hr) Component Gas Service Light Liquid Heavy Liquid Connectors 4.41 x I0-a 4.63 x 10-4 1.65 x 10-' Flanges 8.60 x 10-4 2.43 x 10"4 8.60 x 10-' Open-Ends 4.41 x 10'3 3.09 x 10-3 3.09 x 10-4 Pump Seals 5.29 x 10-3 2.87 x 10.2 N/A Valves 9.92 x 10-3 5.51 x 103 1.85 x 10-' Other* 1.94 x 10.2 1.65 x 10' 7.05 x 10'' *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches.instrument meters,polish rods.and vents. Calculation of annual emissions of VOC per component: (Component count) X 8760 hr/year)X (Weight% VOC in organic portion of gas or liquid stream) X Emission Factor for component being evaluated) X (Control Factor) The total fugitive VOC emissions shall be the sum of emissions for each component. For determining compliance, the Division has accepted the following control factors: the Division accepted the use of a 75 percent (%) control factor for all components except the flanges/connectors. For the flanges/connectors the Division accepted the use of a 30 percent(%)control factor. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: May 1, 2009 LAST REVISED: September 6, 2017 Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 29 Component Gas Control Factor Liquid Control Factor Connectors 81% 8l% Flanges 81% 81% Open-Ends N/A N/A Pump Seals N/A 88% Valves 96% 95% Compressors/Relief Valves 75% 75% 5.1.1 A plant inlet gas analysis shall be performed according to appropriate ASTM approved methods, or equivalent if approved by the Division in advance, at least once a calendar year. The dates of the annual inlet gas analyses shall be separated by at least two (2) calendar months. The most recent inlet gas analysis shall be used to determine the appropriate %VOC to use in the above equation. 5.1.2 Records shall be kept of all component additions and deletions and running tally maintained and made available to the Division upon request. An actual physical hard count of the existing components shall be performed at least once every five years. 5.2 StatewideControlsforOilandGasOperations 5.2.1 Colorado Regulation No. 7, Section XILG Requirements: This facility is subject to the following State-Only Enforceable requirements for gas-processing plants located in the 8-hour Ozone Control Area of Colorado Regulation No. 7. Section XII. "Volatile Organic Compound Emissions from Oil and Gas Operations": Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: May 1, 2009 LAST REVISED: September 6, 2017 Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 30 5.2.1.1 For fugitive volatile organic compound emissions from leaking equipment, the leak detection and repair (LDAR) program as provided at 40 CFR Part 60. Subpart OOOO (July 1.. 2017: Condition 5.4) applies. regardless of the date of construction of the affected facility. unless subject to the LDAR program provided at 40 CFR Part 60. Subpart OOOOa (July I. 2017). (Colorado Regulation No. 7. Section XII.G.I.). 5.2.1.2 Natural gas processing plants within the 8-hour Ozone Control Area constructed before January 1. 2018 must comply with the requirements of Section XII.G. (Condition 5.4) beginning January I. 2019 (Colorado Regulation No. 7. Section XIl.G.3.). 5.3 40 CFR Part 60. Subpart KKK NSPS This source is subject to 40 CFR Part 60 Section 60.630, Subpart KKK, New Source Performance Standards (NSPS) (Adopted into Colorado Regulation No. 6, Subpart KKK): Standards of Performance for Equipment Leaks of VOC From Onshore Natural Gas Processing Plants. The following items apply: 5.3.1 For all equipment types. except for affected compressors only. compliance with NSPS KKK is presumed. provided the requirements of NSPS OOOO (Condition 5.4) are met. 5.3.2 Affected compressors only are subject to the following applicable requirements: 7.5.2.1 Standards. as required by §60.632 7.5.2.2 Exceptions, as required by §60.633 7.5.2.3 Recordkeeping Requirements. as required by §60.635 7.5.2.4 Reporting Requirements, as required by §60.636 5.2.1 Inspection and maintenance requirements as stated in Federal NSPS 40 CFR Part 60 §60.632. §60.633. and §60.631. 5.2.2 Record keeping requirements as stated in Federal NSPS 10 CFR Part 60 §60.635. 5.2.3 Reporting requirements as stated in Federal NSPS 10 CFR Part 60 `60.636. Reporting under this the Division. In addition. the document shall detain procedures for leak detection and leak repair for the equipment and piping subject to Subpart KKK. Any changes to the-decument required as a result of the Division review of the document shall be accomplished as directed in writing by the Division. The document shall be retained at the Operating Permit Number: 95OPWE038 ISSUED: May I, 1999 RENEWED: May 1, 2009 LAST REVISED: September 6, 2017 Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 31 plant and reviewed at least annually by the permittee and revised as necessary. The document shall be made available for Division inspection upon request. The document may be used in a compliance evaluation and determination. The requirements of Subpart KKK include a number of options and alternatives. As a Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: May 1, 2009 LAST REVISED: September 6, 2017 Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 31 alternatives and options to be followed, the procedures and equipment used for the testing, the instrumentation calibration and performance requirements. action levels, actions to be taken, time • might be needed to fully and completely demonstrate compliance with the Subpart KKK and Regulation No. 6, Part A. General Provisions. 5.4 40CFRPart60,SubpartOOOONSPS This facility is subject to the New Source Performance Standards requirements of Colorado Regulation No. 6. Part A. Subpart OOOO (40 CFR Part 60. Subpart OOOO) "Standards of Performance for Crude Oil and Natural Gas Production. Transmission and Distribution for which Construction. Modification or Reconstruction Commenced After August 23. 201 1. and on or before September 18. 2015.-This facility is subject to the following applicable requirements: 5.4.1 Equipment leak standards applicable to affected facilities at an onshore natural gas processing plant O60.54001 5.4.2 Exceptions to the equipment leak standards for affected facilities at an onshore natural gas processing plant (§60.5401) 5.4.3 Recordkeeping Requirements for affected facilities subject to VOC requirements for onshore natural gas processing plants (§60.5421) 5.53 Regulation No. 6. Part A, General Provisions applies as follows: 5.3.1 No article, machine, equipment or process shall be used to conceal an emission which would otherwise constitute a violation of an applicable standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based on the concentrations of a pollutant in the gasses discharged to the atmosphere (40 CFR Part 60 §60.12) 5.3.2 Records of startups, shutdowns, and malfunctions shall be maintained, as required under 40 CFR Part 60 §60.7. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: May 1, 2009 LAST REVISED: September 6, 2017 Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 31 6. P135—Pressurized Product Truck Loadout Rack Parameter Permit Compliance Limits Compliance Emission Factor Monitoring Condition Number Method Interval VOC 6.1 43.15 tons per year Propane Loading:1.11 lb/load Record keeping Monthly and calculation Butane Loading:1.21 lb/load B-G Mix Loading:1.52 lb/load 12 month rolling total Y-Grade Loading:1.53 lb/load Isopentane Loading:1.29 ib/load Natural Gas Liquids(NGL)Loading:1.52 Ib/load Condensate Loading:1.55 lb/load • Total NGL 6622 560 million gallons 100%8 G MixY-Grade used as worst- LoadedProduc per year56,390 case scenario t Throughput loads/yr Leak Detection 6.34 Maintenance Per Plan Plan 6.1 The emission limits were established by Colorado Construction Permit 90WE018 2, as modified under the provisions of Section IL Condition 1.3. The emissions of VOC. and the gallons ofNGL loaded on trucks for each calendar month shall be calculated by the end of the subsequent calendar month. A twelve month rolling total of emissions shall be maintained to verify compliance with the long term emission limitation. By-the end of the new calendar month, a total shall be calculated for the previous twelve (12) calendar months. and compliance determined and recorded. All calculations and compliance determinations shall be made available for Division review upon request. 6.1 VOC Emission Limitations & Compliance Monitoring Emissions of Volatile Organic Compounds (VOC) from pressurized liquids loading shall not exceed the limitation listed in Summary Table 6 above. Compliance with the emission limitations shall be monitored as follows: Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: May 1, 2009 LAST REVISED: September 6, 2017 Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 31 6.1.1 Monthly determination of VOC and HAP emissions shall be calculated by the end of the subsequent month using the above emission factors and the methodology specified below: 6.1.1.1 The following parameters shall be input to the equation below: a. The number of trucks loading/unloading each species (propane. butane. B-G Mix, Y- Grade. isopentane. natural gasoline liquids(NGL). condensate) b. The VOC or HAP content of each species loaded/unloaded. according to the table below: Species Transferred VOC Content HAP Content Propane 100% 0% Butane 100% 0% Isopentane 100% 00% B-G Mix 100% Y-Grade 100% Extended Liquids Analysis (Natural Gas Liquids)— Natural Gasoline 100% Dated 1/15/2019 Condensate 100% Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: May 1, 2009 LAST REVISED: September 6, 2017 Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 31 6.1.1.2 Monthly VOC and NAP emissions shall be calculated via the following equation: N (truck}} x EF (( lb x x //truck x EF lb x x ( tons ll = c,t (monthl c,' (truck) , lmonth� U, �truck � ' VOC or HAP Emissions lmonthl 2000 lb + (2000 lb sash Service Unit Conversion ton Each ServEce Unit Conversion ton Where: = Number of trucks loaded for each species,i,truck/month No,, = Number of trucks unloaded for each species,i,truck/month EFLJ =Loading Emission Factor for each species,i,lb/load EF0,r = Unloading Emission Factor for each species,i,lb/load xi = V0C or HAP content for each species,i,mass fraction i=Service designation(propane,butane,natural gasoline) .Monthly VOC emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be calculated using the previous twelve months' data. Records of calculations shall be maintained and made available to the Division upon request. 6.1.2 Facility-wide emissions of Hazardous Air Pollutants (HAP) shall not exceed 8.0 tons/yr of any single HAP or 20.0 tons/yr total HAP emissions. Monthly emissions of each HAP shall be calculated by the end of the subsequent month with the same method as indicated above for VOC and used in a twelve month rolling total to monitor compliance with the facility-wide HAP emission limitations. 6.2 Pressurized Loading Throughput Limitations & Compliance Monitoring The number of trucks loaded each month at the pressurized liquids loadout shall not exceed the limitation listed in Summary Table 6 above. Sales or haul tickets from each loading operation shall be used to monitor the number of trucks loaded each month. Additionally. the type of product species loaded (propane. butane. B-G Mix. Y-Grade, isopentane. natural gasoline or condensate) shall be recorded for each loading event, and shall be made available to the Division upon request. The number of trucks loaded each month shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month, a new twelve month total shall be made available to the Division upon request, Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: May 1, 2009 LAST REVISED: September 6, 2017 Air Pollution Control Division DCP Operating Company, LP Colorado Operating Permit Greeley Natural Gas Processing Plant Permit# 95OPWE038 Page 31 The truck traffic for each month shall be used to monitor compliance with the annual VOC and HAP emission limitations as required by Condition 6.I. 6.3 A maintenance plan shall be developed that outlines the procedures to locate and repair equipment leaks to minimize the fugitive volatile organic compound emissions. The maintenance plan shall be completed and in use within six (6) months of the issuance of this operating permit. The plan shall be kept on-site and made available for Division review upon request. Operating Permit Number: 95OPWE038 ISSUED: May 1, 1999 RENEWED: May 1, 2009 LAST REVISED: September 6, 2017 la DCP Midstream 370 1716 St.,Suite 2500 Denver,CO 80202 Midstream., (303)605-2029 www.dcpm idstream.com February 12, 2020 E-mail Delivery Colorado Department of Public Health and Environment Air Pollution Control Division ATTN: Elie Chavez x:13 am 4300 Cherry Creek Drive South f":"'D Denver, CO 80246-1530 ,t`iiiomary- Re: Greeley Natural Gas Processing Plant Title V Modification: 95OPWE038 AIRS ID 123/0099 Dear Mrs. Chavez: DCP Operating Company, LP(DCP)is submitting the attached minor modification application addendum for the Greeley Natural Gas Processing Plant(Greeley),located at Section 25,Range 66W,Township 5N in Weld County,Colorado.This facility currently operates under Title V permit 95OPWE038 originally issued on May 1, 1999 and last revised on September 6,2017. DCP is requesting that the changes to the emission limits for compressor engines C-116,C-117,C-118, C-120,and C-122(AIRS 103, 104, 105, 107, 110)and the changes to the pressurized loadout rack(AIRS 115)proposed as part of the original minor modification application submitted December 18, 2019 be rescinded. It has been determined that these proposed changes constitute a significant,rather than minor, modification to Title V permit 95OPWE038,and a separate significant modification application for these sources will be submitted. DCP requests that the proposed changes to facility fugitive emissions(AIRS 114)be processed as submitted. This addendum has been reviewed by DCP's Responsible Official Tauna Rignall, and the RO certification included as Attachment A to this addendum certifies that the proposed changes to facility fugitive emissions still meet the criteria for use of minor permit modification procedures under Colorado Regulation No. 3,Part C, Section X.D.3. If you have any questions or require any additional information about this submittal,please contact Marie Cameron at(303)605-2029 or MECameron@dcpmidstream.com. Sincerely, DCP Operating Company, LP SZie, Marie Cameron Senior Environmental Engineer ——. .. . . . . . .y: I \} \� \ Attachment A: Responsible Official Certification Greeley Natural Gas Processing Plant . \. \ d / � \ � }\ \ $� . � I have reviewed this Minor Modification application supplied under the Authority of Regulation No. 3, Part C, Section X(5 CCR 1001-5)in its entirety and, based on information and belief formed after reasonably inquiry, I certify that the proposed modification meets the criteria for use of minor permit modification procedures and request that such procedures be used to process this application.This certification is in conformance with Regulation No. 3,Part C, Section X.D.3(5 CCR 1001-5). Tauna Rignall General Manager, North Area Operations Printed or Typed Name Title c)2M/. -(:) Signature or-Res psi e Official Date C D P N E Fugitive Component Leak Emissions APEN Form APCD-203 DEC 2 2019 CO 1 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for fugitive component leak emissions only. If your emission source does not fall into this category, there may be a more specific APEN for your source(e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of alt available APEN forms can be found on the Air Pollution Control Division (APCD)website at: www.cotorado.gov/cdphe/apcd. This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type,etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 114 [Leave blank unless APCD has already assigned a permit#and AIRS ID Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Greeley Natural Gas Processing Plant Site Location: SW 1/4, Sec 25, T5N, R66W Site Location Weld County: 3489 49th Street, Evans CO NAICS or SIC Code: 1321 Mailing Address: dP c ss: 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 E-Mail Address: RShankaran@DCPMidstream.com Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any charges will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. 42352G COLORADO Form APCD-2O3 Fugitive Component Leak Emissions APEN Revision 3/2019 1 IAY COLORADO r.+an a somoamai Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 114 [Leave blank unless APCD has already assigned a permit t and MRS ID] Section 2 - Requested Action O NEW permit OR newly-reported emission source(check one below) -OR- ❑✓ MODIFICATION to existing permit(check each box below that applies) ❑ Change process or equipment ❑ Change company name3 ❑ Add point to existing permit El Change permit limit O Transfer of ownership4 ❑ Other(describe below) -OR- ❑ APEN submittal for update only(Note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info Et Notes: Lower VOC permit limit based on revised emission calculations._Note:2018 controlled VOC&HAP emissions are higher than PTE because 2018 emissions use permitted control efficiencies,requested limits use requested control efficiencies. 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106)must be submitted. 4 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. Section 3 - General Information Company equipment Identification No. (optional): P1 33 For existing sources, operation began on: 1/14/1986 For new or reconstructed sources, the projected start-up date is: ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source hours/day days/week weeks/year Operation: Facility Type: ❑Well Production Facility5 ❑Natural Gas Compressor Stations ✓❑Natural Gas Processing Plants ❑Other(describe): 5 When selecting the facility type,refer to definitions in Colorado Regulation No. 7,Section XVII. O D A R Form APCD-2O3 Fugitive Component Leak Emissions APEN - Revision 3/2019 2 I AV COLORADO Neallb berstol Dud]: Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/114 [Leave blank unless APCD has already assigned a permit=and A RS ID' Section 4 - Regulatory Information What is the date that the equipment commenced construction? 1 986 Will this equipment be operated in any NAAQS nonattainment area? 0 Yes O No Will this equipment be bated at a stationary source that is considered a Yes [✓ No Major Source of Hazardous Air Pollutant(HAP)emissions? Are there wet seal centrifugal compressors or reciprocating compressors �✓ Yes O No located at this facility? Is this equipment subject to 40 CFR Part 60, Subpart KKK? Yes O No Is this equipment subject to 40 CFR Part 60, Subpart OOOO? 0 Yes O No Is this equipment subject to 40 CFR Part 60, Subpart OOOOa? O Yes 0 No Is this equipment subject to 40 CFR Part 63, Subpart HH? O Yes (]No Is this equipment subject to Colorado Regulation No. 7,Section XII.G? 0 Yes O No Is this equipment subject to Colorado Regulation No. 7,Section XVII.F? O Yes (]✓ No Is this equipment subject to Colorado Regulation No. 7, Section XVII.B.3? O Yes ✓0 No Section 5 - Stream Constituents 0 The required representative gas and liquid extended analysis(including BTEX)to support the data below has been attached to this APEN form. Use the following table to report the VOC and HAP weight%content of each applicable stream. VOC Benzene Toluene Ethylbenzene Xylene n-Hexane 2'2'4 Stream %) Trimethylpentane (wt%) (wt%) (wt%) (wt (wt%) (wt%) (wt 94 Gas 29.52 0.18 0.24 0.01 0.06 0.94 0.001 Heavy Oil (or Heavy Liquid) 100 0.60 0.81 0.02 0.20 3.20 0.005 Light Oil (or Light Liquid) 100 0.60 0.81 0.02 0.20 3.20 0.005 Water/Oil NA NA NA NA NA NA NA Section 6 - Geographical Information Geographical Coordinates (Latitude/Longitude or UTM) 40.36422 / -104.73045 Attach a topographic site map showing location zAvr COLORADO Form APCD-203 Fugitive Component Leak Emissions APEN - Revision 3/2019 3 I ��w y, Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/114 [Leave blank unless APCD has already assigned a permit n and AIRS ID] Section 7 - Leak Detection and Repair (LDAR) and Control Information Check the appropriate boxes to identify the LDAR program conducted at this site: ❑LDAR per 40 CFR Part 60, Subpart KKK o Monthly Monitoring-Control: 88%gas valve, 76%light liquid valve, 68%light liquid pump ❑Quarterly Monitoring- Control: 70%gas valve, 61%light liquid valve, 45%tight liquid pump ❑✓ LDAR per 40 CFR Part 60, Subpart OOOO/OOOOa Monthly Monitoring- Control: 96%gas valve, 95%light liquid valve, 88%light liquid pump, 81% connectors ❑LDAR per Colorado Regulation No. 7, Section XVII.F ❑Other6: ❑No LDAR Program 6 Attach other supplemental plan to APEN form if needed, COLOR=D0 Form APCD-203 Fugitive Component Leak Emissions APEN - Revision 3/2019 4 I `""" N.aP F Env:.ntrn.n i Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/114 [Leave blank unless APCD has already assigned a permit=and AIRS ID] Section 8 - Emission Factor Information Select which emission factors were used to estimate emissions below. If none apply, use the table below to identify the emission factors used to estimate emissions. Include the units related to the emission factor. 0 Table 2-4 was used to estimate emissions7. ❑Table 2-8(< 10,000ppmv)was used to estimate emissions7. Use the following table to report the component count used to calculate emissions. The component counts listed in the following table are representative of: O Estimated Component Count 0 Actual Component Count conducted on the following date: 6/201 9 (+20% for PTE) Equipment Type Service Open-Ended 9 Connectors Flanges Lines Pump Seals Valves Other Gas Count8 4,720 1,289 0 0 1,260 96 Emission Factor 2.0E-04 3.9E-04 NA NA 4.5E-03 8.8E-03 Units kg/hr/source kg/hr/source NA NA kg/hr/source kg/hr/source Heavy Oil(or Heavy Liquid) Count8 0 0 0 0 2 0 Emission Factor NA NA NA NA 8.4E-06 NA Units NA NA NA NA kg/hr/source NA Light Oil(or Light Liquid) Counts 7,842 1,638 0 42 2,555 68 Emission Factor 2.1E-04 1.1E-04 NA 1.3E-02 2.5E-03 7.5E-03 Units kg/hr/source kg/hr/source NA kg/hr/source kg/hr/source kg/hr/source Water/Oil Count8 0 0 0 0 0 0 Emission Factor NA NA NA NA NA NA Units NA NA NA NA NA NA 7 Table 2-4 and Table 2.8 are found in U.S. EPA's 1995 Protocol for Equipment Leak Emission Estimates(Document EPA-453/R- (6-017). 8 The count shall be the actual or estimated number of components in each type of service that is used to calculate the"Actual Calendar Year Emissions"below. 9 The"Other"equipment type should be applied for any equipment other than connectors,flanges,open-ended lines,pump seals,or valves. Alpy COLOR Form APCD-203 Fugitive Component Leak Emissions APEN - Revision 3/2019 5 Irb `rh m.ADO, Permit Number: 95O PWE038 AIRS ID Number: 123 /0099/114 [Leave blank unless APCD has already assigned a permit r and AIRS ID] Section 9 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. From what year is the following reported actual annual emissions data? 2018 Use the following table to report the criteria pollutant emissions and non-criteria pollutant(HAP)emissions from source: (Use the data reported in Section 8 to calculate these emissions.) CAS Actual Annual Emissions Requested Annual L Permit Emission Limit(s)11 ( )" Chemical Name Number Uncontrolled Controlledt0 Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tons/year) VOC NA 84.3 26.6 112.2 10.4 Does the emissions source have any actual emissions of non-criteria pollutants ❑✓ Yes ❑No (e.g. HAP- hazardous air pollutant)equal to or greater than 250 lbs/year? If yes, use the following table to report the non-criteria pollutant (HAP)emissions from source: CAS Actual Annual Emissions Requested Annual Permit Emission Limit(s)11 O" Chemical Name Number io Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (lbs/year) (lbs/year) (lbs/year) Benzene 71432 NA NA 1,352 125 Toluene 108883 NA NA 1,807 166 Ethylbenzene 100414 NA NA 47 4 Xylene 1330207 NA NA 447 41 n-Hexane 110543 2,926 924 7,176 661 2,2,4 540841 Trimethylpentane NA NA 12 1 Other:Methanol 67561 NA NA 9 1 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. 11 Requested values will become permit limitations. Requested limit(s)should consider future process growth,component count variability,and gas composition variability. megCOLORADO Form APCD-203 Fugitive Component Leak Emissions APEN - Revision 3/2019 6 I 07.7.% !:,t Permit Number: 95OPWE038 AIRS ID Number: 123 /0099 1114 [Leave blank unless APCD has already assigned a permit c and AIRS iD Section 10 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. Signature of Legally Authorized Person (not a vendor or consultant) Date Marie Cameron Senior Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: ❑Draft permit prior to issuance ❑Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692.3175 or(303)692-3148 APCD-SS-B1 4300 Cherry Creek Drive South AP-CD Main Phone Number Denver,CO 80246-1530 (303)692-3150 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www.cotorado.gov/cdpheIapcd pp COLORADO Form APCD-2O3 Fugitive Component Leak Emissions APEN - Revision 3/2019 7 �]� `"OLO DCP Midstream 370 17th St.,Suite 2500 Denver,CO 80202 (303)605-2039 Midstream. www.dcpmidstream.com December 20, 2018 UPS Tracking No. 1ZF469150293513163 Colorado Department of Public Health and Environment Air Pollution Control Division ATTN: Elie Schuchardt 4300 Cherry Creek Drive South Denver, CO 80246-1530 DEC 2 1 2018 Re: Greeley Natural Gas Processing Plant Title V Minor Modification: 95OPWE038 Engine C123/P127 AIRS ID 123/0099/108 Dear Ms. Schuchardt: DCP Operating Company, LP("DCP") is submitting the attached operating permit minor modification application for the Greeley Natural Gas Processing Plant("Facility"), located at Section 25, Range 66W, Township 5N in Weld County,Colorado. This facility currently operates under Title V permit 95OPWE038 originally issued on May 1, 1999 and last renewed on May 1, 2009, and last revised on September 6,2017, with an expiration date of May 1,2014. A timely Title V permit renewal application was submitted in April 2013; however, a revised Title V permit has not yet been issued. DCP is requesting lower emission limitations and corresponding compliance emission factors for engine C123/P127,AIRS ID 123/0099/108, located at the Greeley Natural Gas Processing Plant in order to match the Colorado Air Quality Control Commission's Regulation Number 7 limits that were submitted on an AOS APENs on September 5,2018.1 A revised APEN requesting the lower limits,as well as supporting calculations, are provided in Appendix C.Note that the APEN submitted with the September 2018 AOS submittal listed the lower emission limitations. However, following discussion between DCP and the Division to clarify that out-of-state engine AOS's are still subject to previous emission limits until an official permit modification is filed, the APEN was redlined by the division in October 2018 to instead list the currently permitted emission limits. The division-redlined APEN is included in Appendix D. Please see Appendix E for the affected permit conditions as well as the updated emission limitations and compliance emission factors. Attachments Attached please find forms and attachments needed to make the requested changes to operating permit 95OPWE055, as well as the required certification signed by the Responsible Official, David M.Jost, Vice President of Northern Operations(formerly titled General Manager of Area Operations). This engine was swung in accordance with AOS provisions in the Title V permit, Section 1.2. Any engine that was relocated from outside Colorado is subject to Reg 7 Section XV1l.E limits. Greeley Title V Minor Modification 95OPWE038 Also included are: • Appendix A:RO Signature Page • Appendix B: APEN Filing Fee • Appendix C: Revised APEN and Supporting Calculations • Appendix D: October 2018 Redlined APEN • Appendix E:Title V Red-Line for Requested Engine Emission Limitation Updates • Appendix F: Updated Facility Wide Emissions Inventory Form 102 If you have any questions or require any additional information about this submittal, please contact me at (303)605-2039 or RShankaranndcpmidstream.com. Sincerely, DCP Operating Company,LP • Roshini Shankaran Senior Environmental Engineer APPENDIX A: RO SIGNATURE PAGE I have reviewed this Minor Modification application supplied under authority of Regulation No. 3, Part C. Section X (5 CCR 1001-5) in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the proposed modification meets the criteria for use of minor permit modification procedures and request that such procedures by used to process this application. This certification conforms with Regulation No. 3, Part C, Section X.D.3 (5 CCR 1001-5). David M. Jost Vice President of Northern Operations Printed or Typed Name Title Signature of Resp�hsible Official Date APPENDIX B: APEN FILING FEE APPENDIX C: REVISED APEN AND SUPPORTING CALCULATIONS Engine Emission Calculations Greeley Gas Plant DCP Operating Company,LP Waukesha I.7042 GU Engine C•123/P-127 12310099/100 ♦Stroke,Rich Bum _ Unit Rang 3;hp BSFC d 403 btu9sphr Munson Heel Input 7.6 mmbtdAr Operating SCMd* 7.;50 MA1 1'MV 170 bodsc 'Memnon Fuel Use 6464.0ImrnscfAT 7017 Actual Poemeters Tear Fuel Use Meat Vslue IMMsetlyr) 11310/3.41) January 4.42 110699 FNWary 3.57 1102.21 'Arch 421 1102.26 4prl 411 110443 May 410 1106.67 June 399 1108.96 July 3.56 1117.14 August 401 1117.14 September 3.67 1110.33 Octtter 4.17 112135 November 4.07 1112.02 December 4.15 1184.23 ' 2017 48.64 11163 Criteria Pollutant Emission Cakulationa Uncontrolled CerhWed Potential Compliance 2017 Actual Endsslan Factors Potential Emissions Compliance Factors 2017 Actual Emissions Emission Factors Emission Factors' Emissions Polkaant itc4V9t! PmMMetul IteMnl Payy,) Pe1MMetul I.0181/1 140,.'. 110 gtrp-4 112.41 3.38 91.74 1.0 gbtp-!1 5.55 0.52 11,11 97' 05yb!pts 4.33 0.13 3.53 0.53.o7p-t0 _ 4.31 0.13 3.53 CO." 903.17plr 77.17 2.34 13.51 2 0.07.6.1% 97.30 0.73 21.17 PM` 1.94E-02 10/77ndAu 0.65 1.94E-02 0.53 _ 1.94E-0209,7,1 a ____ 0.63 1.94E-02 0.33 __ SO/ 588E-7.461nm8'u 0,020 5.88E-04 0.016 5.88E-04bImm&u 0.020 ^ 5.89E-04 0.018 •Man,actuete a,naloni 4i ton • mYoM amts.,!aeon nom 40114.9.3.54,0 14085 a1P'ms•tom 0944 Chap.,3 Tae`3 2.3 r7.0C1. 04064e.I Em4apn 144402 ern Colpeacto 1a9enon 7 and 5445 545pan l.'J Emts:u,UmAatiern Pmamal 60,0,ens Cakt*t40 hem updated Pp 7'POPS,77)4 Emsa.0114340 •Curran<crrelanc414ct0rs,s.d to ca6l.8la 2017 Actual Ern pc•s fat the 48481.40 4nyna 1440110 P007 Non-Criteria Reportable Pollutant Calculations Controlled Controlled Actual Uncontrolled Potential Uncap riled Actual Control Potential Emission Endsakes Endselons Efficiency Emiubm PoeBent MAP Emission lectors. Data Soar.. 1164781 11647,} 55 (16470 116197: 1.12.2.Telrmliceoe1xx 253E-05b/mmetu EPA 1.68 1.37 50% 9.84 0.69 1.1.2-TncNov+Mhae <1.53E-05bfmm9tu EPA 1.02 0.63 WA 051 0.42 1.1 GcHoronhro <1.13E-05b',1:Bu EPA 0.36 0.^' `50% 0.18 0.31 1.2 D 7040868 .c1 13E-C6 113,8,690 EPA 0.36 061 50% 0'9 0.3' 1207Nyopruparc 141.30E-0kb' B8I EPA 0 1 0.71 50% 029 0.35 ____....'_...__....__...._ __ ._ _ u 1.}&Radon 663E-04 blme ku EPA 44.14 '1600 50% r.57 ._....1800 1 01chloopdpene 14 127E-05 b '4 0/mm6u EPA 0.85 0.73 5042 0.34 _____ Acetaldehyde 278E-03bfinm&u EPA 185.75 151.50 5.^% 928% 75.75 Acrdan 263E-03 tarnm.B'u EPA 175.09 14281 50% 8'.55 71411 y8eaere 1.50E-03 blmmBu EPA 105.19 85.80 50% 5269 42.95 Carbon TetracNorde <1.77E-05 Mamma, EPA 1.18 0.56 50% 659 0.48 C4dre8eroene <1.29E-05 1MrnmEmi EPA 0.96 7.70 50'4 943 0.35 CMaofam <1.376.05 lb/mrnEku EPA 091 074 54".5 046 0.37 Etlllberdene 1248505 bmlmEu EPA 1.55 1 35 50% 0.83 067 Ethylene DEranidn 14213E-0561mmEu EPA 142 1.15 . 50% 0.7' 058 60188044.4450* 2331.02 ayuane 9 EPA 1384.411 1183,38 ;4% 37743 287.15 Metnard 3.O6E-C3 bhrm81u EPA 20372 15616 56'°4 101.86 83.08 Methylene Cnkeee 4.12E-f6 67mmEu EPA 2.74 2.24 5C% 177 1.12 N_pa 847088 <9.71E-056/mm81u EPA 6.46 5.27 5370 3.23 264 PAM 1,41E-04b1mmE.u EPA 939 186 50% 4.09 3.83_ Styrene <119E-091118,84 EPA _ 0.79 0.65 30% 0.40 0.32 Toluene 5.58E-04b(mmBv EPA 3;.15 30.30 56% 18.57 15.15 +,1ny1 C9esdc 4718E-06 1787mau EPA 048 039 50% 0 24 9.19 Adenes-;m.Pd) 1.95E{Ab/moEu EPA 1298 1159 50% 6.49 5.29 TOTAL — <2159 0 <1762 <725 <192 '00,70714108 l4Y4lpn 044040 pan 41,448.665eurn(4588)engines from AP42.Chapter 3,Table 3.2-3 777001, SOP Mgstrml,LP 015/2018 I APPENDIX D: OCTOBER 2018 REDLINED APEN � Tw1FL� CDPHE Spark Ignition Engine APEN �Ee - 61°ra ►► Form. APCD-201 41r , Air Pollutant Emission Notice (APEN) and t ?"�` ¢ Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates.An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for spark ignition(e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e.g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source(e.g. compression ignition engine, mining operations, asphalt plant,crusher, screen, etc.). In addition, the General APEN(Form APCD-2OO)is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division(APCD)website at: c ph.e/aped. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made(significant emissions increase,increase production, new equipment,change in fuel type,etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE038 AIRS ID Number: 1 23 /0099/ 108 Section 1 -Administrative Information Company Name': DCP Operating Company, LP Site Name: Greeley Natural Gas Processing Plant Site Location Site Location: SW 1/4 Section 25, T5N, R66W County: Weld NAICS or SIC Code: 1311 Mailing Address: (Include zip code: 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 Portable Source E-Mail Address2: Home Base: RShankaranaDCPMidstream corn i Use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. 387337 Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 108 Section 2 - Requested Action ❑ NEW permit OR newly-reported emission source (check one below) ❑ STATIONARY source 0 PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023(Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of$1,875 must be submitted along with the APEN filing fee. -OR- MODIFICATION to existing permit(check each box below char opp(res) Add point to existing tAt 0 Change fuel or equipment 0 Change company name 0 permit Change permit limit ❑ Transfer of ownerships 0 Other(describe below) -OR- istd APEN submittal for update only(Blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- El APEN submittal for permit-exempt/grandfathered source ❑Q Notification of Alternate Operating Scenario(AOS)permanent replacements Additional Info Et Notes: AOS engine started on 8/24/2018 3 Only one engine may be reported per APEN for GP02 coverage.Coverage under GP02 is voluntary. For company name change,a completed Company Name Change Certification Form(Form APCD-106)must be submitted. S For transfer of ownership,a completed Transfer of Ownership Certification Form(Form APCD-104)must be submitted. 6 This does not apply to General Permit GP02,as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? Yes If yes,provide the Company Equipment Identification No. C-123 (P127) General description of equipment and purpose: Natural Gas Compression For existing sources,operation began on: 1986 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http:;iwww.cotor,ado. ov/cdphe/attainment) Yes ❑No Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec-Feb: 25% Mar-May: 250/6 June-Aug: 25% Sept-Nov: 25% 2i Permit Number: 95OPWEO38 AIRS ID Number: 123 /0099/ 108 Section 4 - Engine Information Engine Function: O Primary and/or Peaking Power O Emergency(max. 500 hrs/year) Q Compression Pump Jack ❑Water Pump ❑Other: What is the maximum number of hours this engine will be used for emergency backup power? 0 hours/year Engine Make: Waukesha Engine Model: L7042 GU Serial Number': 336485 What is the maximum designed horsepower rating? 896 hp What is the maximum manufacturer's site-rating? 896 hp kW What is the engine Brake Specific Fuel Consumption at 100%Load? 8,482 BTUfhp-hr Engine Features: Cycle Type: ❑2-Stroke El 4-Stroke Combustion: O Lean Burn 0 Rich Burn Aspiration: Q Natural ❑Turbocharged Is this engine equipped with an Air/Fuel ratio controller(AFRC)? Q Yes O No If yes,what type of AFRC is in use? J Oz Sensor(mV) ONOx Sensor(ppm) O Other: Is this engine equipped with a Low-NOr design? O Yes ONo Engine Dates: What is the manufactured date of this engine? 12/1979 What date was this engine ordered? 12/1979 What is the date this engine was first located to Colorado? 8/24/2018 What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? 8/2018 Is this APEN reporting an AOS replacement engine? 0 Yes O No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Waukesha Engine Model: L7042 GU Serial Number: 269013 'The serial number must be submitted if coverage under GPO2 is requested. II it Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 108 Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 4,468,151/522,877 Operator Discharge Height Temp. Flow Rate Velocity Stack ID No. Above Ground Level ('F) (ACFM) (f/sec) (feet) C-123 26.5 1,055 4,380 93.0 Indicate the direction of the Stack outlet: (check one) 0 Upward ❑Downward ❑Upward with obstructing raincap ❑Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) Q Circular Interior stack diameter(inches): 12 ❑Square/Rectangle Interior stack diameter(inches): Interior stack depth(inches): ❑Other(describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100%Load Actual Annual Fuel Use Requested Annual Permit Limits (SCF/hour) (MMSCF/year) (MMSCF/year) 7,308 48.6 64.2 whet)e-1 is the ccturi t 3 a cr'ou,,t 2017 Indicate the type of fuel used9: O Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ['Field Natural Gas Heating value: BTU/scf D Propane (assumed fuel heating value of 2,300 BTU/scf) ❑Landfill Gas Heating Value: BTU/scf El Other(describe): Residue Gas Heating Value(give units): 1116.3 Btu/scf 8 Requested values will become permit limitations. Requested limitlsi should consider future process growth. 9 If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. • 4 Permit Number: 95OPWE038 AIRS ID Number: 123 /0099) 108 Section 7 - Emissions Inventory Information Attach alt emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? 0 Yes C]No If yes,describe the control.equipment AND state the overall control efficiency(%reduction): Overall Requested Control Pollutant Primary Control Equipment Description Efficiency (%reduction in emissions) TSP(PM) PM 1c PM 2.5 Sox _ _ NOx Nsc 92:, VOC CO NSCR 791t Other: ;v5C° 76 {formalaenyde1 Use the following tables to report criteria and non-criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From v.h '. ,yea-is the rOl::. re ,cries cccU Grins ) enfissr s Cage. 2017 Criteria Pollutant Emissions Inventory Requested Annual Permit Emission Factor Actual Annual Emissions'° Emission Limit(s)8 Pollutant Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Basis Units (AP-42, Emissions Emissions Emissions Emissions Mfg.etc) (tons/year) (tons/year) (tonslyear) (tons/year) TSP(PM) 1.94E-02 Ibh4M9lu AP-42 0.53 0-53 065 ass - PM10 194E-02 IGMM , AP-42 053 0.53 085 065 PM2.s 1.94E-02 Ib4Meu AP-42 0.53 0.53 035 265 A-- SOx 5.88E-04 ID/AiMfiAL, AP-42 0016 3.016 0 020 0.020 �^J NOx 1309.11.1-3 Manufatt rer I 0174 14.11 112.48 waii5+ V�J.3 VOC 05 g o-tx Ma,v/acturcr 3.53 3.33 4.33 4,33 CO 9.3 — 901P-rt Mar,13cturer i 53.51 21.17 7717 ..+iC• 25-c14 Does the emissions source have any uncontrolled actual emissions of non-criteria ,Q j c, j 21t pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 0 Yes ❑No lbs/year? c5ki k'i-1G " If yes, please use the following table to report the non-criteria pollutant(HAP)emissions from source: WA-06 1 Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Ar1etual Emissionst° Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions Number Basis mfg.etc) (pounds/year) (pounds/year) Formaldehyde 50000 0.0205 IbrMM6tu AP-42 1 113 18 267.19 • Acetaldehyde 75070 j Acrolein 107028 Benzene 71432 Other: I _ - 8 Requested values will become permit limitations- Requested limitis)should consider future process growth. 7°Annual emissions fees will be based on actual controlled emissions reported. if source has not yet started operating, leave blank. Permit Number: 95OPWE038 AIRS ID Number: 123 100991 108 Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and wilt be operated in full compliance with each condition of General Permit GP02. Signature of Legally Authorized Person(not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name(please print) Title Check the appropriate box to request a copy of the: ❑Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made(significant emissions increase,increase production, new equipment,change in fuel type,etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with 5191.13 and the General Permit For more information or assistance call: registration fee of$1,875, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692-3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https_//www.colorado_gov/cdphelapcd 6 Zia, .,. II III APPENDIX E: TITLE V RED-LINE FOR REQUESTED ENGINE EMISSION LIMITATION UPDATES Ii C123—Waukesha L-7042G 896 HP Compressor Engine Compliance Compliance Permit Limits Emission Factor Monitoring Parameter Condition Method Interval NOx 8.65 47.30 0.26 0,52 TPY lb/MMBtu Record keeping 2.1 And Calculation Monthly CO 17.30 2S96 0.52 0,78 TPY Ih/MMBtu 12 month rolling total VOC 4.33 TPY 0.13 lb/MMBtu APPENDIX F: UPDATED FACILITY WIDE EMISSIONS INVENTORY FORM 102 Colorado Department of Public Health and Environment C D F H E Form AFCD-102 Air Pollution Control Division y y ` Facility Wide Emissions Inventory Form WI Ver Aptd,2019 CO 1 Company Name:DCP Op91.03 115 Company,I P Sonree Name:Glee)y c1,Plant r Source AIRS ID,123/0699 1,1onl,43304 Potential to Eton(PTE.) u ntrMled Potential to Emit(PPE)) Criteria(TPV) 0.AP,lib4;yr) ('riterlu(IP1'1 1042',llb,osll AIRS ID Ey0ipm,n5 pesrripl,on TSP PO10 0112.5 502 tips 1f)(' ('O I 11('11(1 Aretnl Arro 09 P 1 E0 Avl n-Ilea Meth 124-0110 TSP P.M IQ 05125 602 NOT VOC ('0 111(-140 Aerial Acr9 09 Tul Ell 1 All 0-Iles' Meth 224-TOP 121,09,17N F y 0-157.7P-175 5)71 0. 7379 1.02 .4 29 5.71 '5.60 I 1677 '23 7-; 129 ,6 0 '_00 5 079 079 03') 00 2124 5 1 27 55 7 423 114 100 65 2J 10 0 125 0 121,0099.100 E„3,,,C.1237Pi27 105 005 (1.05 2,62 111,43 433 77 47 1365 186 175 105 17 2 11 0 204 t 005 065 00 41.65 30I J_5 IS 53 39 2 1'3 204 0 06 ' 12 11,9'122 4ngin,:C-14479-12 f 008 000 0.08 2 00 958 301 1613 '8 24 21 14 3 0 2 0 27 010 OOP 08 2 00 t 02 0 5 l 41 11 Ii 7 2 I 1 11 I) I. 0 123/0009,107 Popov 57-12017-Eiti 0 79 0.'9 0 09 ( 2 118 00 ,31 :.00 14,77 219 215 12916 251 0 70 07 077 3 55 5 1 T I 401 114 108 5 23 0 115 0 2 6 121730029'10,3 (none 7110,1122 079 090 079 002 08 90 5.9' 95.60 1.677 218 20 129 „ , 079 079 079 002 —26 55 5l 24i55I 403 114 114 65 0 125 0 1230,34,04E- C.117 P-123 070 (. + 0." 1384(. 3 ' ( 16'7 728 2 5 1_2 916 2 6. (I i ,70 07 0.71 002 55 543) 1075 I 413 114 108 ,5 2' a 170 0 1230699'105 E C116,1 0.733 7 02 1180. 31 I,(2 1`8 21 129 4e 2 19 0 _ 0 1 1 9 7 ) 0( 055 5. 55 I 1 ):. 111 IOM 5 23 0 125 0 I /0099,'110 E gt C-12277-129 079 07. ' 002 I34t 531 ) 1 ',7 ,'70 1_ 1'9 46 16 0 0 079 1179 1 9 00 '15 5 11 26 5- 301) I,1,4 I 23 ti 115 0 11 0099,IM5 Eng,2 1 7-125 099 0 01 1750' 531 01500 1,173' '_26 .IS 129 46 2 In 11 _10 J,0 07: 9. 002 _4 5 5 I _ 110 5 23 0 I 2_ 11'1099 t'. Pi h(I 004 r 100 ,0 000 L 49 1.00 ' 3 _ 411 - 32 4k 0 I O.t- nl 0.10 410 ))3 I 0 7 10, 5 0 2 05 ,' 2 9,0929 13 P 11'0111'23 0oft '18 048 ( t ]1 5..1 4 7 ., 0 ", _ 0 4 �i 48 048 018 0( 3 1]S 5.11 ; v 0 t 0 O 221 0 (',210).20 P179,130 0,)lleoct III 111 111 002 1424 I6) 1_0; 22 2 1 i, . 0 0 52, 0 111 III 1 II 017 1431 On, 12101 22 3 o t 0 n 6 , 0 I.72,0097I II PI 55ePiennotee,l 0,0436,4;0) 0)50 )00 01,0 0(10 43.IS 02" u n 0 — 0 0 0 _ 000 0.00 0.00 0.(0 l0( 4315 0 1 (' 0 0 0 0 0 ,7 0 IU 0 lk I)01'4),1. E Fee 0nrt 002 ,400 0'0 01 1 , , 3 ll ei 6 4440 0 II o 1 0 00 001' 000 - earl li 05 1 0 o 0 0 o u u tau 1211202,122 IIa... OW OM I0: OW 2 02 )649 1,6 0 2.3'9 32 37;, 11:46 II 0 001 001 1101 0.00 262 19 32 I1.06,4... ! 7 0 110 102 _ I1 -87 0 Permitted Source,Solo,IoI- 7.9 '9 7.9 tl.l 1112.2 549,3 192,1 i 13,314 1,801 I l0! 2,357 2,456 51 531 16,389 1,983 11 9.4 70 3.9 0.3 11,6 130.6 237.1 I 3.219 904 052 734 307 11 100 2,684 11193 0 APS',D2l5-Permit Eno,.Sources ... - -- - I` - - - _ I a. I I i- 1 - 1 APT;5 Onit SO036343 1141 11.0 11.0 301 1,1 0.13 1,0 1 u 0 0 0 0 0 0 0 o an 11.9 0.4 u.0 11,6 53.9 0,0 I 1 0 0 0 d 0 0 n 0 0 MIEN Exempt I lnrlxni0ennl sources m:le ' IA.maw 00 0.0 110 1,,0 08 w9 5.1 f n _ n 1 21 n ,1 153 00 0o a:,3 00 06 lug 51 1 0 1 0 21 n 0 0 -152 '1 - 1 _ _ i J - - - _ I Insignificant S961,110= a 0.9 0,0 0.0 6.8 10.9 5.2 9 9 0 21 0 0 0 152 273 II 00 9.4 0.0 0.0 6,6 10.9 5.2 I 0 0 0 21 11 0 4 152 273 0 Total,All 5m,raes-1 7,9 1 7,9 I ',9 I 03 1 1119,1 190(1.21 197.2 I 13,314 1 1,6110 11,7141 4,398 I Liss 1 51 1531 1,7.1401 2,259 I 0 179 1 7.9 1 7,9 1 03 1217.51141.41142,3! 32191 904 1 852 1 79.4 1 347 111 i 1011 I2,636I 1,360 1 0 r:neontroiled YAPS Suomare(TP11-I 6.' I 0.9 I 0.9 I 2.2 I ,,2 I 0.0 I 0.3 I 0.6 1 1.1 I 0.0 I Controlled o404 Summary(TP9)-1 1.6 1 0.5 1 0,4 I 11.4 1 0.2 1 0,0 I 0.0 I 1,4 1 0.7 1 0.0 (ntoo0m11e00411,1.All HAM,11'11)4 21.0 I Coniru11cil9,141,All 11.41',(TM l d 5.2 I Footnotes, 1 Ihls Corm should be 10mpleted to include both existing'0050es and ell 67060061 new or mndllicav8105 to eSIsling enussmns 00019 2 If the emisslons source Is new then enter"proposed"01,20 the Penn))Nn and 4111S II)01,i),103)3)3,909 3 ((Al'abbreviations Include 8S Benzene 224-TMP_:2?4-I:1melhsItte997c Tot's'(0160,0 /Metal Acetaldehyde ED-E4h)ibenzene Arno is Actnleo4 Xyl=Xylene n-flex n-11062)10 [WHO=143,an ldehyde Meth-Methanol 4 AKIN EaemptInsigniticunt Sources should he included olun warranted DCP MidsVeam 12/13(2018 Pagel of 1 CDPHE A Spark Ignition Engine APEN DEC ' °'8 CO r Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for spark ignition(e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e.g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source(e.g.compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200)is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at:www.colorado.gov/cdphelapcd. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.).See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 108 . i4 mss.t<`'`Cr _. ... .` 7,a$s!42.,:d t p 'T'i 5'iU r+R Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Greeley Natural Gas Processing Plant Site Location Site Location: SW 1/4 Section 25, T5N R66W County: Weld NAICS or sic Code: 1311 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 Portable Source Home Base: E-Mail Address2: RShankaran@DCPMidstream.com 1 Use the full,legal company name registered with the Colorado Secretary of State.This is the company name that wilt appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. 391418 Cato RADO Form t pc 23 Soal- E mee APEN - Revrsiop 7/2018 1 IknolICV �" „k..n....F•. r e • Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 108 [Leave blank unless APCD has alreCd i assRLned a perrrit µ and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly-reported emission source(check one below) O STATIONARY source ❑ PORTABLE source ❑ Request coverage under a Construction Permit O Request coverage under General Permit GPO23(Natural Gas Only) If General Permit coverage is requested,the General Permit registration fee of$1,875 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit(check each box below that applies) Add point to existing O Change fuel or equipment ❑ Change company name ❑ permit ❑ Change permit limit ❑ Transfer of ownerships ❑ Other(describe below) -OR- ❑ APEN submittal for update only(Blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ▪ APEN submittal for permit-exempt/grandfathered source • Notification of Alternate Operating Scenario(AOS)permanent replacement6 Additional Info Et Notes: AOS engine started on 8/24/2018 3 Only one engine may be reported per APEN for GP02 coverage.Coverage under GP02 is voluntary. 4 For company name change,a completed Company Name Change Certification Form(Form APCD-106)must be submitted. 5 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. 6 This does not apply to General Permit GP02,as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? Yes If yes, provide the Company Equipment Identification No. C-123 (P127) General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 1986 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? El (http://www.cotorado.gov/cdphe/attainment) Yes El No Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec-Feb: 25% Mar-May: 25% June-Aug: 25% Sept-Nov: 25% COLORADO Form:SPCC-201 Spark I nPi{on Engine APEN - Revision % 20l8 2 I ,L$1. V=711,=`,, Permit Number: 95OPWE038 AIRS ID Number: 123 10099/ 108 eav_ ,.a K u -s_t P D has adre z.i/aasagred .had not and AP,S ti7) Section 4 - Engine Information Engine Function: D Primary and/or Peaking Power ❑Emergency(max. 500 hrs/year) El Compression O Pump Jack O Water Pump ❑Other: What is the maximum number of hours this engine wilt be used for emergency back-up power? 0 hours/year Engine Make: Waukesha Engine Model: L7042 GU Serial Number': 336485 What is the maximum designed horsepower rating? 896 hp What is the maximum manufacturer's site-rating? 896 hp kW What is the engine Brake Specific Fuel Consumption at 100%Load? 8,482 BTU/hp-hr Engine Features: Cycle Type: ❑2-Stroke ❑✓ 4-Stroke Combustion: O Lean Burn Q Rich Burn Aspiration: 0 Natural O Turbocharged Is this engine equipped with an Air/Fuel ratio controller(AFRC)? El Yes ❑No If yes, what type of AFRC is in use? ❑✓ OZ Sensor(mV) ❑NOx Sensor(ppm) ❑Other: Is this engine equipped with a Low-NOx design? ❑Yes El No Engine Dates: What is the manufactured date of this engine? 12/1979 What date was this engine ordered? 12/1979 What is the date this engine was first located to Colorado? 8/24/2018 What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? 8/2018 Is this APEN reporting an AOS replacement engine? El Yes O No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Waukesha Engine Model: L7042 GU Serial Number: 269013 'The serial number must be submitted if coverage under GP02 is requested. I cola RADO Form:PCD 201 Sparc I 2 t Engine APEN - Revision 7/20:8 3 Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 108 (Li'av bl r; t I ;s APCD has a!re,y dsslg ed 3 Berm t and AIRS ID) Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 4,468,151/522,877 Discharge Height Operator Temp. Flow Rate Velocity Above Ground Level Stack 1D No: (feet) Co {ACFm) . eft/sec) C-123 26.5 1,055 4,380 93.0 Indicate the direction of the Stack outlet: (check one) ✓❑Upward ❑Downward O Upward with obstructing raincap O Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) Q Circular Interior stack diameter(inches): 12 ❑Square/Rectangle Interior stack diameter(inches): Interior stack depth(inches): ❑Other(describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100%Load Actual Annual Fuel Use Requested Annual Permit Limit8 (SCF/hour) (MMSCF/year) (MMSCF/year) 7,308 48.6 64.2 From what year is the actual annual amount? 2017 Indicate the type of fuel used9: ❑Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑Field Natural Gas Heating value: BTU/scf ❑Propane (assumed fuel heating value of 2,300 BTU/scf) ❑Landfill Gas Heating Value: BTU/scf 0 Other(describe): Residue Gas Heating Value(give units): 1116.3 Btu/scf 8 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 9 If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. COLORADO Form^PCD 201 Spark. ignition Engme APEN Re,lsio 7 2018 4 I """ Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 108 .,s. Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ✓0 Yes ❑No If yes, describe the control equipment AND state the overall control efficiency(%reduction): Overall Requested Control Pollutant Primary Control Equipment Description Efficiency (%reduction in emissions) TSP(PM) PM10 PM2.5 SOx NOx NSCR 92% VOC CO NSCR 78% Other: NSCR 76%(formaldehyde) Use the following tables to report criteria and non-criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Criteria Pollutant Emissions Inventory Emission Factor Actual Annual Emissionst0 Requested Annual Permit Pollutant Emission Limit(s)8 Uncontrolled Source Uncontrolled Controlled Uncontrolled • Controlled Basis Units (AP-42, Emissions Emissions Emissions Emissions Mfg.etc) (tons/year) (tons/year) (tons/year) (tons/year) TSP(PM) 1.94E-02 lb/MMBtu AP-42 0.53 0.53 0.65 065 PMio 1.94E-02 Ib/MMBtu AP-42 0.53 0.53 0.65 065 PM2.5 1.94E-02 Ib/MMBtu AP-42 0.53 0.53 0.65 0.65 SOx 5.88E-04 Ib/MMBtu AP-42 0.016 0.016 0.020 0.020 NOx 13.0 g/hp-hr Manufacturer 91.74 14.11 112.48 865 VOC 0.5 g/hp-hr Manufacturer 3.53 3.53 4.33 4.33 CO 9.0 g/hp-hr Manufacturer 63 51 21 17 77.87 17.30 Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 0✓ Yes 0 No lbs/year? If yes, please use the following table to report the non-criteria pollutant (HAP)emissions from source: Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions" Abstract Chemical Name Source Uncontrolled Controlled Service(CAS) Uncontrolled Units Emissions Emissions Basis (AP-42, Number Mfg.etc) (pounds/year) (pounds/year) Formaldehyde 50000 0.0205 Ib/MMBtu AP-42 1.113.18 267.16 Acetaldehyde 75070 Acrolein 107028 Benzene 71432 Other: 8 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. VIW COLORADO Fot n AP/_G 201 Spark Ignition Engine APEN - Revision 7?2018 5 MZs ,tP,` , Permit Number: 95OPWE038 AIRS ID Number: 123 /0099/ 108 [Leave hla:k unle s APCD has a['e11/ Led a permit:aid AIRS ID] Section 8 -Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP02. 12420(201g Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Senior Environmental Engineer Name(please print) Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance ❑Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type,etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of$1,875, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692-3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www.colorado.gov/cdphetapcd Low COLORADO Form APCD 201 Spark Ignition Engine AaEN Rev/>ion 72018 6 I m@ Hello