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Home My WebLink About20122051.tiff WELD COUNTY DCP Midstream, LPCOIIIMISSIONERS 1011 AUG -2 P 12: 52 RECEIVED Midstream., Marla Compressor Station Title V Operating Permit Renewal Application Submitted To: Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South APCD-SS-B1 Denver,CO 80246-1530 April 2011 Prepared By: Olsson Associates 4690 Table Mountain Drive,Suite 200 Golden,Colorado 80403 OLSSON ASSOCaAI Ss -TL,JA,c ResliQb03 <C PL 41-1- le-1 a - -1 a 2012-2051 • STATE OF COLORADO John W. Hickenlooper,Governor of cot\ Christopher E. Urbina, MD,MPH �, ,� ,p Executive Director and Chief Medical Officer re a,-m:7 'b o Dedicated to protecting and improving the health and environment of the people of Colorado .« �. 4300 Cherry Creek Dr.S. Laboratory Services Division /876 Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health http://www.cdphe.state.co.us and Environment July 26, 2012 Steve Moreno Weld County Clerk 1402 N. 17th Ave. Greeley, CO 80631 Dear Mr. Moreno: On July 30, 2012, the Air Pollution Control Division will publish a public notice for DCP Midstream, LP, in the Greeley Tribune. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies �f these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty(30) days from the date the public notice is published. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health & Environment APCD-SS-B 1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Ellen Evans Regards, Ellen Evans Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure • NOTICE OF A PROPOSED RENEWAL TITLE V OPERATING PERMIT WARRANTING PUBLIC COMMENT 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 Stollution: Applicant: DCP Midstream, LP 370 17th Street, Suite 2500 Denver, CO 80217 Facility: Marla Compressor Station SESE Section 28, T4N, R64W Kersey, CO 80644 DCP Midstream, LP has applied for a Renewal Operating Permit for their facility in Weld County, CO. The facility is a natural gas compressor station. A copy of the applications, including supplemental information,the Division analysis, and a draft of the Renewal Operating Permit 95OPWE020 has been filed with the Weld County Clerk's office. Based on the information submitted by the applicant, the Division has prepared the draft renewal operating permit for approval. Any interested person may contact Bailey Kai Smith at the Division at 303-691-4961 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). If requested, the hearing will be held before the Commission at their regularly scheduled meeting within 60 days of its 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: I) 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. RE sED TO: The Greeley Tribune on PUBLISHED: July 26, 2012 July 30, 2012 • COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION OPERATING PERMIT RENEWAL SUMMARY EMIT NUMBER: 95OPWE020 AIRS ID#: 1230243 DATE: July 26, 2012 APPLICANT: DCP Midstream, LP—Marla Compressor Station REVIEW ENGINEER: Bailey Kai Smith SOURCE DESCRIPTION DCP, Midstream, LP has applied for renewal of their Operating Permit issued for the Marla Compressor Station located in SESE Section 28 T3N R63W, south of the town of Kersey, Weld County. The Marla Compressor Station consists of six engines, two glycol dehydrators equipped with flares, and fugitive emissions from equipment leaks, and is classified under SIC 1311. The area in which the facility operates is classified as attainment for all pollutants except ozone. It is classified as non-attainment for ozone and is part of the 8-hr Ozone Control Area as defined in Regulation No. 7, Section II.A.16. There are no other Operating Permits associated with this facility for purposes of determining applicability of Prevention of Significant Deterioration regulations. Wyoming is an affected states within 50 miles of the plant. The following Federal Class I designated areas are within 100 kilometers of the plant: Rocky Mountain National Park. This facility is categorized as a NANSR major stationary source and is not categorized as a PSD major stationary source. The emission units covered under this permit are not subject to the Accidental Release provisions of section 112(r) of the Federal Clean Air Act. Six engines and two dehydrators are subject to the Compliance Assurance Monitoring (CAM) requirements in 40 CFR Part 64. FACILITY EMISSION SUMMARY POTENTIAL TO EMIT(TONS/YEAR) NOx CO VOC One Waukesha 7042 GSI 1478 HP Engine 42.8 42.8 14.3 • One Waukesha 7042 GSI 1478 HP Engine 28.5 42.8 14.3 One Waukesha 7042 GSI 1478 HP Engine 14.3 28.5 10.0 Three Waukesha 7044 GSI 1680 HP Engines 97.2 97.2 48.6 Two TEG Dehydrators 5.6 Fugitive Emissions 36.0 Insignificant Activities 1.2 2.2 2.2 Totals 184.2 213.7 131.0 EMISSION SOURCES The following discussion identifies the changes that were made in the renewal permit. Engines —The fuel consumption and emission limitations of the engines were adjusted in accordance with the revised natural gas heating value and brake specific fuel consumption submitted. Dehydrator — The monthly emission limits for the dehys were removed. The annual emission limitation and glycol recirculation rate limit were adjusted so the limits are the same for each unit. The combined emissions from both dehydrators were unchanged. The reboiler rating was corrected. Equipment Leaks — The emission limitations for the fugitive emissions from equipment leaks were revised to account for changes in the piping configuration at the facility. The two, previously separate, fugitive sources were combined into a single point. ALTERNATIVE OPERATING SCENARIOS The most recent version of the engine replacement alternative operations scenarios was included in the operating permit. INSIGNIFICANT ACTIVITIES • An updated list of insignificant activities was included in the operating permit. PERMIT SHIELD No changes were made to the permit shield. TECHNICAL REVIEW DOCUMENT For • RENEWAL OF OPERATING PERMIT 95OPWE020 DCP Midstream, LP — Marla Compressor Station Weld County Source ID 1230243 Prepared by Bailey Kai Smith January - February 2012 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 Marla Compressor Station. The previous Operating Permit for this facility was issued on May 1, 2007 and expired on May 1, 2012. 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. 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 renewal application submitted on April 28, 2011, additional information submitted on July 29, 2008, August 7, 2009, April 1, 2010, April 12, 2010, April 28, 2011, and May 11, 2011, previous inspection reports, and various email correspondence 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 http://www.cdphe.state.co.us/ap/Titlev.html. 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 Marla Compressor Station uses six (6) gas-fired internal combustion engines to • drive compressors to transmit natural gas gathered from gas field laterals to a primary pipeline. These engines are controlled through non-selective catalytic reduction (NSCR). 123/0243 Page 1 of 8 DCP Midstream, LP—Marla Compressor Station Operating Permit No. 95OPWE020 Technical Review Document—Renewal 2 The station also includes two (2) triethylene glycol dehydrator units that contact "dry" • triethylene glycol with the natural gas stream to remove moisture. The "wet" glycol mixture is regenerated in a still for reuse in the process. These units are equipped with a condenser and flare for VOC control. The plant is located west of the intersection of Weld County Road (WCR) 55 and WCR 40 on the north side of WCR 40, approximately 13 miles southeast of Greeley. This facility is located in an Area classified as attainment for all pollutants except ozone. It is classified as non-attainment for ozone and is part of the 8-hr Ozone Control Area as defined in Regulation No. 7, Section II.A.1. This facility is categorized as a NAN$R major stationary source (Potential to Emit of VOC and NOx > 100 Tons/Year). Future modifications at this facility resulting in a significant net emissions increase (see Reg 3, Part D, Sections II.A.26 and 42) for VOC or NOx or a modification which is major by itself(i.e. a Potential to Emit of > 100 TPY of either VOC or NOx) may result in the application of the NANSR review requirements. Based on the information provided by the applicant, this source is categorized as a minor stationary source for PSD as of the issue date of this permit. Any future modification which is major by itself (Potential to Emit of > 250 TPY) for any pollutant listed in Regulation No. 3, Part D, Section II.A.42 for which the area is in attainment or attainment/maintenance may result in the application of the PSD review requirements. Emissions (in tons/yr) at the facility are as follows: • POTENTIAL TO EMIT (TONS/YEAR) 5STMse- ,. if F„Tu t . 4- : NOx CO VOC _wa. -$ • ter_ One Waukesha 7042 GSI 1478 HP Engine 42.8 42.8 14.3 One Waukesha 7042 GSI 1478 HP Engine 28.5 42.8 14.3 One Waukesha 7042 GSI 1478 HP Engine 14.3 28.5 10.0 Three Waukesha 7044 GSI 1680 HP Engines 97.2 97.2 48.6 Two TEG Dehydrators 5.6 Fugitive Emissions 36.0 Insignificant Activities 1.2 2.2 2.2 Totals 184.2 213.7 131.0 • 123/0243 Page 2 of 8 DCP Midstream, LP—Marla Compressor Station Operating Permit No. 95OPWE020 Technical Review Document—Renewal 2 • HAP EMISSIONS (LB PER YEAR) HCHO Acetaldehyde Benzene Acrolein Toluene Total (tpy) One Waukesha 7042 GSI 498.8 141.4 80.1 133.3 0.43 1478 HP Engine One Waukesha 7042 GSI 498.8 141.4 80.1 133.3 - 0.43 1478 HP Engine One Waukesha 7042 GSI 498.8 141.4 80.1 133.3 0.43 1478 HP Engine Three Waukesha 7044 1707.3 484.2 274.2 456.3 1.46 GSI 1680 HP Engines Two TEG Dehydrators 1240.0 2040.0 1.64 Totals (tpy) 1.60 0.45 0.88 0.43 1.02 4.38 Applicable Requirements NSPS Subpart KKK The requirements of 40 CFR Part 60 Subpart KKK apply to VOC emissions from equipment leaks at onshore natural gas processing plants. The fuel conditioning skid • unit previously at this facility has been disconnected and is now out of service. NSPS Subpart JJJJ All engines at this facility were manufactured prior to the applicability date of NSPS Subpart JJJJ and are therefore not subject to its provisions. NESHAP Subpart HH The final rule for 40 CFR Part 63 Subpart HH was revised on January 3, 2007 to address area sources for HAPs. An affected source under this subpart includes each triethylene glycol (TEG) dehydration unit located at a facility that processes hydrocarbon liquids. Marla has two TEG dehydrators that are subject to the area source provisions of Subpart HH. Glycol dehydrators with actual benzene emissions less than 1984 lb/year or actual annual average gas flowrate less than 3 MMscf/day are exempt from the requirement of Subpart HH with exception of recordkeeping. The dehydrations units at the facility currently qualify for this exemption, as such, the exemption criterion were included in the operating permit. • 123/0243 Page 3 of 8 DCP Midstream, LP—Marla Compressor Station Operating Permit No. 95OPWE020 Technical Review Document—Renewal 2 NESHAP Subpart ZZZZ • Subpart ZZZZ, also known as the RICE MACT, applies to both new and existing engines of all size located at area sources of HAPs. Under the rule, engines located at area sources are considered existing if construction commenced prior to June 12, 2006. All engines commenced construction prior to June 12, 2006 and are considered existing. These existing engines are subject to emission standards for formaldehyde. Regulation No. 7 Engines Since the last issuance of the operating permit, new Reg 7 rules have come into effect. The engines are now subject to Section XVII which includes state-wide control requirements and emissions standards. Engines C-148, C-166, C-174, and C-176 are considered existing engines and are required to install controls pursuant to Section XVII.E.3.b.(i). This state only requirement has been streamlined from the permit, as the engines are also subject to the control requirements in Section XVI. Engines C-135 and C-151 are replacement units that have been relocated from outside the state of Colorado and are therefore subject to the emission standards for new engines constructed after July 1, 2007 but prior to July 1, 2010, which are 2.0 g/hp-hr for NOx, 4.0 g/hp-hr for CO, and 1.0 g/hp-hr for VOC. These emission standards are embedded in the annual emission limitations of these engines and therefore the standards have been streamlined from the permit. Each of the engines subject to these standards has demonstrated compliance during a performance test. . While Reg 7 Section XVII.B.4 exempts units that are subject to NSPS or MACT control requirements from the provisions of Section XVII.E, the engines at this facility are not required to comply with the MACT Subpart ZZZZ limitations until October 19, 2013. Until the MACT requirements become effective the engines are subject the requirements in Reg 7, Section XVII.E as discussed above. Dehydration Units The glycol dehydrator control requirements listed in the first renewal permit incorrectly cited requirement for condensate storage tanks. The dehydrators are subject to the ozone nonattainment area requirements to control VOC emissions in Reg 7 Section XII.H. The dehydrators are also subject to similar state-only statewide requirements to control emissions in Section XVII.D. Since the SIP-approved XII requirements are federally enforceable, the state-only requirement to control VOC emissions from XVII was streamlined from the permit. Section XVII includes additional requirements regarding the operation and maintenance of the dehydration units. These conditions have been included in the body of the operating permit. Flare The first renewal operating permit included 20%/30% opacity standards for the combustion device controlling the dehydration units from Colorado Regulation No. 1, Section II.A.1 and II.A.4. The combustion of waste gases is excepted from the Reg 1, Section II.A.1 requirements and subject to a 30% standard in Section II.A.5 of Reg 1. . However, Reg 7 Section XVII requires no visible emission for control devices used to comply with the XVII control requirements. The more stringent requirements from Reg 123/0243 Page 4 of 8 DCP Midstream, LP—Marla Compressor Station Operating Permit No. 95OPWE020 Technical Review Document— Renewal 2 • 7, Section XVII were included in the specific conditions of the operating permit and the Reg 1 30% standard was added to the streamlined conditions in Section III of the operating permit. Greenhouse Gases The potential greenhouse gas emissions at this facility are less than 100,000 TPY CO2e. Future modifications at this facility that exceed 100,000 TPY CO2e may be subject to regulation. Source Determination With this permit action, the Division revisited the source determination in regards to natural gas operations in the area surrounding the Marla facility to verify that the proper pollutant emitting activities are included in this permit as part of the Marla Compressor Station facility. DCP did not identify any other pollutant emitting activities in the Marla vicinity that are dependent upon the Marla Compressor Station to maintain operation. The Division considers the current determination for the facility to be accurate. III. Discussion of Modifications Made Source Requested Modifications The renewal application and additional information received requested the following modifications: • Modification Application on July 29, 2008 • Revise the emission limits for two fugitive VOC sources (P106 and P114) to account for piping configuration changes. Modification Application on August 7, 2009 • Combine two fugitive VOC sources (P106 and P114) into one point (under P106). • Revise emission limit for single fugitive VOC source based on most recent gas analysis and component count. Modification Application on April 1, 2010 • Replace the CAM plan language for a thermocouple with a flame monitoring system. Modification Application on April 12, 2010 • Remove monthly limits from dehydrators (P112 and P113). • Adjust glycol recirculation rate limits to 6.25 gallons per minute for both • dehydration units. • Adjust annual emission limits to 2.82 tons per year for each dehydrator. 123/0243 Page 5 of 8 DCP Midstream, LP—Marla Compressor Station Operating Permit No. 95OPWE020 Technical Review Document—Renewal 2 Modification Application on April 28, 2011 • • Revise the natural gas heating value and brake specific fuel consumption for each of the engines. • Include new fuel consumption limitations and emission factors for the engines as provided with the application. Renewal Application on April 28, 2011 • Incorporate past modification requests. • Incorporate two AOS executions for which the replacement engines are now subject to the emissions standards in Regulation No. 7. Renewal Application Revisions on May 11, 2011 • Revise reboiler ratings, which were listed incorrectly on the renewal application. • Revise the reported facility-wide emissions to correct a calculation error. • Revise the insignificant activities emission calculation spreadsheet that was submitted with the renewal application. The source's requested modifications were addressed as follows: Page following cover page • • Updated the responsible official and permit contact information in accordance with the renewal application. Section I — General Activities and Summary • Updated the engine's serial numbers in the summary of emission units in Condition 6 in accordance with AOS executions and to correct an error. Section II — Specific Permit Terms • The two fugitive emission sources were combined into one point and the emission limitation increased as requested. • The monthly emission limits for the dehys were removed. The annual emission limitation and glycol recirculation rate limit were adjusted as requested. The combined emissions from both dehydrators were unchanged. • The annual natural gas consumption limitations for the engines were adjusted as requested. Appendices • The dehydrator CAM plan language for monitoring the presence of a flame was • changed to accommodate alternative monitoring systems. 123/0243 Page 6 of 8 DCP Midstream, LP—Marla Compressor Station Operating Permit No. 95OPWE020 Technical Review Document—Renewal 2 • 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: Section I — General Activities and Summary • Added dehydrator permit 05WE0579 to Condition 1.3. • Revised the language in Condition 1.4 include current conditions that are state- only enforceable. • Updated the AOS in Condition 2 with the most current version (10/1/2011). The applicability reports for engine replacement were also included in Appendix J. Note the AOS cannot be used for permanent replacement of engines with permitted emissions limits above the NANSR significance level. • Updated Condition 3.1 (status of source with respect to PSD requirements) to reflect Division's current standard language and current Regulation No. 3 citations. • Section II — Specific Permit Terms • Replaced the requirement to record fuel consumption within seven days with language specifying natural gas consumption shall be recorded monthly. This language is consistent with other recently issued DCP permits. A requirement to record on a monthly basis the hours of operation for each engine was also added to the permit. This parameter is necessary to allocate natural gas consumption for each engine and calculate emissions. To accurately determine natural gas consumption, it is essential that the hours of operation and total plant fuel usage be recorded on the same day. • The opacity requirement language for the engines was modified to more closely reflect the underlying construction permit and Reg 1 requirements. • The engine and dehy requirements to follow an external O&M plan were removed from the permit. The appropriate conditions from the plan were incorporated into the permit. • Added the NESHAP Subpart ZZZZ and Subpart A requirements to the engine conditions. • Removed insignificant activity tracking since NOx is now major due to the nonattainment designation and CO is no longer within 10% of the PSD threshold. • • The requirement to conduct a compliance test on the dehydrators was removed from the operating permit, as the one-time test has already been conducted. 123/0243 Page 7 of 8 DCP Midstream, LP—Marla Compressor Station Operating Permit No. 95OPWE020 Technical Review Document— Renewal 2 • The Reg 7 control requirements listed in the permit have been altered. The • original requirements listed in the permit were inaccurate. Additionally, the less stringent requirements from Reg 7 Section XVII have been streamlined from the permit, as discussed above. • The NESHAP Subpart HH area source requirements were added to the permit. • The opacity standard for the flare used to control the glycol dehydration units was corrected, as discussed above. Section III — Permit Shield • Applicable requirements were removed from the permit shield. Section IV— General Permit Conditions • Updated the general permit conditions to the current version (5/22/2012). • • 123/0243 Page 8 of 8 • )s Colo w SrNp Nu" * 1876 Colorado Department • of Public Health and Environment OPERATING PERMIT DCP Midstream, LP — Marla Compressor Station First Issued: June 1 , 1999 Renewed: DRAFT • AIR POLLUTION CONTROL DIVISION COLORADO OPERATING PERMIT FACILITY NAME: Marla Compressor OPERATING PERMIT NUMBER Station FACILITY ID: 1230243 95OPWE020 RENEWED: DRAFT EXPIRATION DATE: DRAFT MODIFICATIONS: See Appendix F of Permit Issued in accordance with the provisions of Colorado Air Pollution Prevention and Control Act, 25-7-101 et ue. and applicable rules and regulations. ISSUED TO: PLANT SITE LOCATION: DCP Midstream, LP 370 17th Street, Suite 2500 SESE, Section 28, T4N, R64W Denver, CO 80202 South of Kersey (Kersey, CO 80644) Weld County FORMATION RELIED UPON Operating Permit Renewal Application Received: April 28, 2011 And Additional Information Received: July 29, 2008, August 7, 2009, April 1, 2010, April 12, 2010, April 28, 2011, and May 11, 2011 Nature of Business: Natural gas liquids gathering Primary SIC: 1311 RESPONSIBLE OFFICIAL FACILITY CONTACT PERSON Name: Joe Kuchinski Name: Wesley Hill Title: Vice President, Area Title: Senior Environmental Specialist Operations North Phone: 970-378-6345 Phone: 303-605-1716 SUBMITTAL DEADLINES Semi-Annual Monitoring Period: January 1 —June 30, July 1 —December 31 Semi-Annual Monitoring Report: August 1, 2007 & February 1, 2008 and subsequent years Annual Compliance Period: January 1 —December 31 Annual Compliance Certification: February 1, 2008 and subsequent years Note that the Semi-Annual Monitoring Reports and Annual Compliance Certifications must be received at the Division office by 5:00 p.m. on the due date. Postmarked dates will not be accepted for the •rposes of determining the timely receipt of those reports/certifications. TABLE OF CONTENTS: WCTION I - General Activities and Summary 1 . Permitted Activities 1 2. Alternative Operating Scenarios (ver 10/1/2011) 2 3. Prevention of Significant Deterioration 8 4. Accidental Release Prevention Program (112(r)) 8 5. Compliance Assurance Monitoring (CAM) 9 6. Summary of Emission Units 10 SECTION II - Specific Permit Terms 11 1. Three Waukesha L-7042 GSI, 1478 hp engines (C-148, C-135, C-151) with NSCR; 11 Three Waukesha L-7044 GSI, 1680 hp engines (C-166, C-174, C-176) with NSCR 11 2. P-106 - Fugitive Emissions of VOCs from Equipment Leaks; 18 3. P-112 Triethylene Glycol Dehydration Unit with condenser and flare; 19 P-113 Triethylene Glycol Dehydration Unit with condenser and flare; 19 4. Compliance Assurance Monitoring 22 SECTION III - Permit Shield 28 1. Specific Non-Applicable Requirements 28 2. General Conditions 28 3. Stream-lined Conditions 29 SECTION IV - General Permit Conditions (5/22/2012) 30 1. Administrative Changes 30 2. Certification Requirements 30 Common Provisions 30 4. Compliance Requirements 34 5. Emergency Provisions 35 6. Emission Controls for Asbestos 35 7. Emissions Trading, Marketable Permits, Economic Incentives 35 8. Fee Payment 35 9. Fugitive Particulate Emissions 36 10. Inspection and Entry 36 11. Minor Permit Modifications 36 12. New Source Review 36 13. No Property Rights Conveyed 36 14. Odor 36 15. Off-Permit Changes to the Source 37 16. Opacity 37 17. Open Burning 37 18. Ozone Depleting Compounds 37 19. Permit Expiration and Renewal 37 20. Portable Sources 37 21. Prompt Deviation Reporting 37 22. Record Keeping and Reporting Requirements 38 23. Reopenings for Cause 39 24. Section 502(b)(10) Changes 39 .5. Severability Clause 40 6. Significant Permit Modifications 40 TABLE OF CONTENTS: 27. Special Provisions Concerning the Acid Rain Program 4. 28. Transfer or Assignment of Ownership 4 29. Volatile Organic Compounds 40 30. Wood Stoves and Wood burning Appliances 41 APPENDIX A 1 Inspection Information 1 APPENDIX B 1 Monitoring and Permit Deviation Report 1 APPENDIX C 1 Required Format for Annual Compliance Certification Reports 1 APPENDIX D I Notification Addresses 1 APPENDIX E 1 Permit Acronyms 1 APPENDIX F 1 Permit Modifications 1 APPENDIX G 1 Compliance Assurance Monitoring Plan - Engines 1 APPENDIX II 1 Compliance Assurance Monitoring Plan - Dehydrators III APPENDIX J Applicability Reports 1 • Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 1 • SECTION I - General Activities and Summary 1. Permitted Activities 1.1 The Marla Compressor Station uses six (6) gas-fired internal combustion engines to drive compressors to transmit natural gas gathered from gas field laterals to a primary pipeline. These engines are controlled through non-selective catalytic reduction (NSCR). The station also includes two (2) triethylene glycol dehydrator units that contact "dry" triethylene glycol with the natural gas stream to remove moisture. The "wet" glycol mixture is regenerated in a still for reuse in the process. These units are equipped with a condenser and flare for VOC control. The plant is located west of the intersection of Weld County Road (WCR) 55 and WCR 40 on the north side of WCR 40, approximately 13 miles southeast of Greeley. This facility is located in an Area classified as attainment for all pollutants except ozone. It is classified as non- attainment for ozone and is part of the 8-hr Ozone Control Area as defined in Regulation No. 7, Section II.A.1. Wyoming is an affected state within 50 miles of the Station. Rocky Mountain National Park is a Federal Class I designated area within 100 kilometers of the Station. I. 1.2 Until such time as this permit expires or is modified or revoked, the permittee is allowed to discharge air pollutants from this facility in accordance with the requirements, limitations, and conditions of this permit. 1.3 The 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 of Part B. Any revisions made using the provisions of Regulation No. 3, Part C shall become new applicable requirements for purposes of this Operating Permit and shall survive reissuance. This permit incorporates the applicable requirements (except as noted in Section II) from the following construction permits: 01WE0499, 01 WE0500, 01 WE0501, 01WE0502, 01WE0503, 01WE0504, 01WE0505, 01WE0506, and 05WE0579 1.4 All conditions in this permit are enforceable by US Environmental Protection Agency, Colorado Air Pollution Control Division (hereinafter Division) and its agents, and citizens unless otherwise specified. State-only enforceable conditions are: Permit Condition Number(s): Section II—Conditions 3.4 and 3.6.1, Section IV - Conditions 3.g (last paragraph), 14 and 18. 1.5 All information gathered pursuant to the requirements of this permit is subject to the Recordkeeping and Reporting requirements listed under Condition 22 of the General Conditions • in Section IV of this permit. Either electronic or hard copy records are acceptable. Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 2 2. Alternative Operating Scenarios (ver 10/1/2011) • 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. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90-day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliancia 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, 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 2.1.2 and make them available to the Division upon request. 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 requirement. Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 3 • applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 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 NO, and CO from the temporary replacement engine must be less than or equal to the potential annual emissions of NO„ 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) 2.1.2 The permittee may permanently replace the existing compressor engine for the emission points specified in Table 1 with the manufacturer, model, and 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. 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.42. 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 A. 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 Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit/4 95OPWE020 Page 4 requirement. Additionally, in the event that any permanent engine replacement(sID 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. 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). 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 (lb/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. 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. • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 5 • Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOx or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOx and CO emission limitations or until the engine is taken offline 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOx are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PKo at any level of emissions and to NOx and SO2, as precursors to PM10, if the potential to emit of NOx or SO2 exceeds 40 tons/yr. • For purposes of this AOS, the following shall be considered RACT for natural- gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOx: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E(State-Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an • oxidation catalyst to reduce emissions. Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit # 95OPWE020 Page 6 The above emission control equipment shall be appropriately sized for the engine an0 shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVII.E—State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: 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 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 7 • However, as of October 1, 2011 the Division has not yet adopted NSPS Jill 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, § IB (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources • The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS-approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit # 95OPWE020 Page 8 • Table 1 Internal Combustion Engine Information For AOS C-148 Waukesha Model L-7042 GSI,natural gas fired internal Portable Monitoring Yes combustion reciprocating engine,4-cycle,standard rich burn, Quarterly 1478 HP;with AFR&NSCR C-135 Waukesha Model L-7042 GSI,natural gas fired internal Portable Monitoring Yes combustion reciprocating engine,4-cycle,standard rich burn, Quarterly 1478 HP;with AFR&NSCR C-151 Waukesha Model L-7042 GSI,natural gas fired internal Portable Monitoring Yes combustion reciprocating engine,4-cycle,standard rich burn, Quarterly 1478 HP;with AFR&NSCR C-I66 Waukesha Model L-7044 GSI,natural gas fired internal Portable Monitoring Yes combustion reciprocating engine,4-cycle,standard rich burn, Quarterly 1680 HP;with AFR&NSCR C-174 Waukesha Model L-7044 GSI Natural Gas Fired Internal Portable Monitoring Yes Combustion Reciprocating Engine,4-cycle, Standard Rich Quarterly Burn, 1680 HP;with AFR&NSCR C-176 Waukesha Model L-7044 GSI Natural Gas Fired Internal Portable Monitoring Yes Combustion Reciprocating Engine,4-cycle,Standard Rich Quarterly Burn, 1680 HP;with AFR&NSCR • 3. Prevention of Significant Deterioration 3.1 This facility is categorized as a NANSR major stationary source (Potential to Emit of VOC and NOx > 100 Tons/Year). Future modifications at this facility resulting in a significant net emissions increase (see Reg 3, Part D, Sections II.A.26 and 42) for VOC or NOx or a modification which is major by itself (i.e. a Potential to Emit of> 100 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.42 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 facility for purposes of determining applicability of Prevention of Significant Deterioration regulations. 4. Accidental Release Prevention Program (112(r)) 4.1 Based upon the information provided by the applicant, this facility is not subject to the provisions of the Accidental Release Prevention Program (Section 112(r) of the Federal Clean Air Act). • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 9 • 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: C-148, C-135, C-151 —Waukesha Model L-7042 ICE C-166, C-174 & C-176-- Waukesha Model L-7044 ICE P-112—Natural Gas Dehydration System P-113 —Natural Gas Dehydration System • • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 10 6. Summary of Emission Units 6.1 The emissions units regulated by this permit are the following: AIRS Point Facility Description Pollution Control Number Identifier Device 052 C-148 Waukesha Model L-7042 GSI Natural Gas Fired Internal Non-Selective Catalytic (P-102) Combustion Reciprocating Engine,4-cycle, Standard Rich Burn, Reduction&Air/Fuel Serial No.383730, 1478 HP;powering a natural gas compressor ratio controller 053 C-135 Waukesha Model L-7042 GSI Natural Gas Fired Internal Non-Selective Catalytic (P-103) Combustion Reciprocating Engine,4-cycle,Standard Rich Burn, Reduction&Air/Fuel Serial No. 317310, 1478 HP;powering a natural gas compressor ratio controller 054 C-151 Waukesha Model L-7042 GSI Natural Gas Fired Internal Non-Selective Catalytic (P-104) Combustion Reciprocating Engine,4-cycle, Standard Rich Burn. Reduction&Air/Fuel Serial No.C-12843/1. 1478 HP;powering a natural gas ratio controller compressor 056 P-106 Equipment Fugitive Leak VOC Emissions None 059 C-I66 Waukesha Model L-7044 GSI Natural Gas Fired Internal Non-Selective Catalytic (P-109) Combustion Reciprocating Engine,4-cycle, Standard Rich Burn, Reduction&Air/Fuel Serial No.C-13857/1, 1680 HP;powering a natural gas ratio controller compressor 060 C-174 Waukesha Model L-7044 GSI Natural Gas Fired Internal Non-Selective Catalytic (P-110) Combustion Reciprocating Engine,4-cycle,Standard Rich Burn, Reduction&Air/Fuel • Serial No.C-13848/1, 1680 HP;powering a natural gas ratio controller compressor 061 C-176 Waukesha Model L-7044 GSI Natural Gas Fired Internal Non-Selective Catalytic (P-Ill) Combustion Reciprocating Engine,4-cycle, Standard Rich Burn, Reduction&Air/Fuel Serial No.C-13858/1, 1680 HP;powering a natural gas ratio controller compressor 062 P-I 12 Natural Gas Dehydration System using triethylene glycol; Condenser&Enclosed maximum glycol recirculation rate of 6.25 gallons/minute Flare 063 P-I13 Natural Gas Dehydration System using triethylene glycol; Condenser&Enclosed maximum glycol recirculation rate of 6.25 gallons/minute Flare All horsepower(HP)values are site rated values as reported in the Title V application • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 11 • SECTION II - Specific Permit Terms 1. Three Waukesha L-7042 GSI, 1478 hp engines(C-148,C-135,C-151)with NSCR; Three Waukesha L-7044 GSI, 1680 hp engines(C-166,C-174, C-176)with NSCR Note:These limitations apply to each engine individually. Pertnll Y" Comp? ce M ortn Parameter Condition Limitations Emission Method Interval 0.* ._- Factor Number NO\ I.1 _ C-148:42.82 ton/yr 0.84 lb/MMBtu Record keeping Monthly C-135:28.54 ton/yr 0.56 lb/MMBtu and calculation C-151: 14.27 ton/yr 0.28 lb/MMBtu 12 month rolling C-166,C-174,C-176:32.45 ton/yr 0.56 lb/MMBtu CO C-148,C-135:42.82 ton/yr 0.84 lb/MMBtu C-151:28.54 ton/yr 0.56 lb/MMBtu C-166,C-174,C-176:32.45 ton/yr 0.56 lb/MMBtu VOC C-148,C-135: 14.27 ton/yr 0.28 lb/MMBtu C-151:9.99 ton/yr 0.201b/MMBtu C-166,C-174,C-176: 16.22 ton/yr 0.28 lb/MMBtu HAP Emissions Facility wide: Individual HAP: 8.0 tons/yr Total HAPs: 20.0 ton/yr Patural Gas1.2 C-148,C-I35,C-151: 84.5 MMscf/yr onsumption C-166,C-174,C-176:96.4 MMscf/yr Opacity 1.3 Not to Exceed 20%Except as Provided for == Fuel Restriction Only Below . :.`'_ Natural Gas is For Startup—Not to Exceed 30%,for a _ -- Used as Period or Periods Aggregating More than = .:::.77!;:=,:,...• Fuel Six(6)Min in any 60 Consecutive Min Portable 1.4 Flue Gas Analyzer Quarterly Monitoring -.. Hours of 1.5 Recordkeeping Monthly Operation Btu Content of 1.6 - ASTM or other Semi- Natural Gas _te Division Approved Annually e rr - _ S._ = Method CAM 1.7 V See Condition 4 Emissions 1.8 Non-selective catalyst reduction and an air See Condition 1.8 I, Control fuel controller required. NESHAP 1.9 Limit Formaldehyde concentrations to 2.7 See Condition 1.9 Subpart ZZZZ ppmvd @ 15%O2 or Reduce Formaldehyde by 76% 1 NESHAP 1.10 - :-:...2.:.:-;;;- -;--r See Condition 1.10 Subart A • p ter,,..,::-: ; ._ • ..;..,...444,2.1;3E— Operating —- Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit # 95OPWE020 Page 12 1.1 Nitrogen Oxide (NOx), Carbon Monoxide (CO), Volatile Organic Compound (VOC), an. Hazardous Air Pollutant (HAP) emissions from each engine shall not exceed the limitations stated in the table above (Colorado Construction Permit 01WE0499, 01 WE0500, 01 WE0501, 01 WE0503, 01WE0504 & 01WE0505, 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: Monthly emissions of each pollutant shall be calculated by the end of the subsequent month using the above emission factors, the monthly natural gas consumption and the lower heating value of the fuel in the equation below: Tons/mo=Emission Factor(lbs/MMBtu)x Monthly Fuel Use(MMscf/mo)x Heat Content(MMBTU/MMscf) 2000 lbs/ton A twelve month rolling total of emissions will be maintained in order to monitor compliance with the annual emission limitation. Each month, a new twelve month total shall be calculated using the previous twelve months data. If the results of the portable analyzer testing conducted under the provisions of condition 1.4 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 Natural gas consumption for each engine shall not exceed the limitations shown in the table above. (Construction Permit 01WE0499, 01 WE0500, 01WE0501, 01WE0503, 01 WE0504 & 01WE0505, as modified under the provisions of Section I, Condition 1.3 of this Operating Permit). Facility-wide natural gas consumption shall be recorded using the existing fuel meter on a monthly basis. The natural gas use shall be measured on the same day that run time hours have been recorded in accordance with Condition 1.5. Allocation of natural gas to each engine will be calculated using the following calculation: (Design Heat Rate x Hours of Operation x Site Rated Horse well engine Fuel Consumption= x Total Engine Fuel Use (Design Heat Rate x Hours of Operation x Site Rated Horsepower)Lach engine Records of calculations shall be kept in a log to be made available to the Division upon request. Monthly natural gas consumption from 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. 1.3 Visible emissions shall not exceed 20% opacity (Colorado Construction Permit 01WE0499, 01 WE0500, 01 WE0501, 01 WE0503, 01 WE0504 & 01 WE0505 and Colorado Regulation No. 1, Section II.A.1) except during periods of startup when visible emissions shall not exceed 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). This opacity standard applies Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 13 • to each engine. 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. 1.4 Portable Monitoring (ver 6/1/2006): 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: http://www.cdphe.state.co.us/ap/down/portanalyzeproto.pdf 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. 1.5 Hours of operation of each engine shall be recorded monthly. Records shall be made available for Division review upon request. S Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 14 1.6 The Btu content of the natural gas used to fuel this engine shall be verified semi-annually usingg the appropriate ASTM Methods or equivalent, if approved in advance by the Division. The Btu content of the natural gas shall be based on the lower heating value of the fuel. Calculations of monthly emissions shall be made using the heat content derived from the most recent required analysis. 1.7 The source shall follow the Compliance Assurance Monitoring (CAM) requirements as outlined in Section II, Condition 4 of this permit. 1.8 Each engine shall be equipped with both a non-selective catalytic reduction system and an air fuel controller (Colorado Regulation No. 7 Section XVI.B.1). The emission control equipment required by this Condition 1.8 shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. (Colorado Regulation No. 7, Section XVI.B.3). 1.8.1 The millivolt reading (AFR) for each engine will 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 shall be monitored and recorded during the portable monitoring event. Recording of the millivolt reading shall be used to verify that the AFR controlled is operated in accordance with the manufacturer's recommendations. 1.8.2 The oxygen concentration in the engine exhaust gas shall be measured and recorded fo. each engine during each portable monitoring event required by Condition 1.4 1.8.3 This engine shall be operated and maintained in accordance with internal operating and maintenance standards, which shall consider manufacturer's recommendations and good engineering practices, at all times, including periods of start-up, shut-down and malfunction. 1.9 [Federal-Only] These engines are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ, "National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines", as follows: Note that as of the issuance date of this permit [DATE], the provisions in 40 CFR Part 63 Subpart ZZZZ (those provisions published in the August 20, 2010 Federal Register) have not been adopted in Colorado Regulation No. 6, Part A and Colorado Regulation No. 8, Part E by the Division and are therefore not state-enforceable. In the event that the Division adopts these requirements, these requirements will become both state and federally enforceable. Note: If there is a change in federal law which renders ineffective or alters the applicable requirements of this Subpart ZZZZ, the source shall follow the effective federal rules. 1.9.1 This facility must comply with the applicable limitations no later than October 19, 2013. (§63.6595(a)(1)) • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit ft 95OPWE020 Page 15 1.9.2 Formaldehyde emission from these engines shall be limited to 2.7 ppmvd at 15% O2 or reduced by 76 percent or more (Table 2d of Subpart ZZZZ, Item 10). 1.9.3 For the non-selective catalytic reduction device installed to meet the requirement in Condition 1.9.2, the following operating requirements shall apply: (Table lb of Subpart ZZZZ, Item 1) 1.9.3.1 Maintain each catalyst so that the pressure drop across the catalyst does not change by more than 2 inches of water at 100 percent load plus or minus 10 percent from the pressure drop across the catalyst measured during the initial performance test and 1.9.3.2 Maintain the temperature of each engine's exhaust so the catalyst inlet temperature is greater than or equal to 750°F and less than or equal to 1250°F. Performance Tests 1.9.4 Initial performance tests must be conducted within 180 days after the compliance date specified in Condition 1.9.1 according to the provisions of§63.7(a)(2). (§63.6612(a)) 1.9.4.1 An initial performance test is not required on a unit which a performance test has previously been conducted, provided the test meets the conditions described in §63.6612(b)(1) through (4). (§63.6612(b)) • 1.9.5 Performance tests must be conducted using the appropriate ASTM methods or equivalent, if approved in advance by the EPA, as described in Table 4 to Subpart ZZZZ, according to the following protocol: 1.9.5.1 Select the sampling port location and the number of traverse points a. Sampling sites must be located at the inlet and outlet of the control device 1.9.5.2 Measure O2 at the inlet and outlet of the control device a. Measurements to determine O2 concentration must be made at the same time as the measurements for formaldehyde concentration 1.9.5.3 Measure moisture content at the inlet and outlet of the control device a. Measurements to determine moisture content must be made at the same time and location as the measurements for formaldehyde concentration 1.9.5.4 Measure formaldehyde at the inlet and the outlet of the control device a. Formaldehyde concentration must be at 15 percent O2, dry basis. Results of this test consist of the average of the three 1-hour or longer runs Demonstrating Compliance 1.9.6 Initial compliance with the requirement to limit concentration or reduce formaldehyde • emissions in Condition 1.9.2 is demonstrated by achieving the following: Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit # 95OPWE020 Page 16 1.9.6.1 The average reduction of emissions of formaldehyde determined from the initia performance test is equal to or greater than the required formaldehyde percent reduction or the average formaldehyde concentration, corrected to 15% O2, dry basis, from the initial performance test is less than or equal to the emission limitation; (Table 5 of Subpart ZZZZ, Item 7.a.i or 10.a.i) and 1.9.6.2 A CPMS has been installed to continuously monitor catalyst inlet temperature according to the requirements in §63.6625(b); (Table 5 of Subpart ZZZZ, Item 7.a.ii or 10.a.ii) and 1.9.6.3 The catalyst pressure drop and catalyst inlet temperature have been recorded during the initial performance test. (Table 5 of Subpart ZZZZ, Item 7.a.iii or 10.a.iii) 1.9.7 Demonstrate continuous compliance with the limitations in Condition 1.9.2 using the following methods described in Table 6 of Subpart ZZZZ. (§63.6640(a)): 1.9.7.1 Conduct performance tests according to Condition 1.9.5 every 8,760 hours or 3 years, whichever comes first, to demonstrate that the required formaldehyde concentration or percent reduction is achieved; (Table 6 of Subpart ZZZZ, Item 10.a.i) and 1.9.7.2 Collect the catalyst inlet temperature data according to §63.6625(b); (Table 6 of Subpart ZZZZ, Item 10.a.ii) and 1.9.7.3 Reduce these data to 4-hour rolling averages; (Table 6 of Subpart ZZZZ, Item 10.a.iii) and 1.9.7.4 Maintain the 4-hour rolling averages within the operating limitations for the catalyst inlet temperature; (Table 6 of Subpart ZZZZ, Item 10.a.iv) and 1.9.7.5 Measure the pressure drop across the catalyst once per month and demonstrating that the pressure drop across the catalyst is within the operating limitation established during the performance test. (Table 6 of Subpart ZZZZ, Item 10.a.v) Notification and Reporting Requirements 1.9.8 Submit compliance reports semiannually according to the requirements in §63.6650(b). The report must contain the following: 1.9.8.1 If there are no deviations from any emission limitations or operating limitations, include a statement that there were no deviations from the emission limitations or operating limitations during the reporting period. If there were no periods during which the CMS, including CEMS and CPMS, was out-of-control, as specified in §63.8(c)(7), include a statement that there were not periods during which the CMS was out-of-control during the reporting period. (Table 7 of Subpart ZZZZ, Item l.a) 1.9.8.2 If there is a deviation from any emission limitation or operating limitation durin the reporting period, include the information in §63.6650(d). If there we Operating Permit 95OPWE020 First Issued: June I, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 17 • periods during which the CMS, including CEMS and CPMS, was out-of-control, as specified in §63.8(c)(7), include the information in §63.6650(e). (Table 7 of Subpart ZZZZ, Item 1.b) 1.9.8.3 If there was a malfunction during the reporting period, include the information in §63.6650(c)(4). (Table 7, Item 1.c) 1.9.9 Submit a Notification of Compliance Status according to §63.6645(h). 1.9.10 Submit all notifications that are applicable in §§63.7(b) and (c), 63.8(e), (O(4) and (t)(6), 63.9(b)through (e), (g) and (h). (§63.6645(a)) 1.9.11 Keep records of the maintenance conducted on the engine in order to demonstrate that the engine was operated and maintained according to the maintenance plan. (§66.6655(e)). General Requirements 1.9.12 Compliance with the emission limitations and operating limitations in this subpart must be achieved at all times. (§63.6605(a)) 1.9.13 At all times the engines must be operated and maintained in a manner consistent with safety and good air pollution control practices for minimizing emissions. The general duty to minimize emissions does not require 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 Division 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)) Maintenance Requirements 1.9.14 Comply with the monitoring, installation, collection, and maintenance requirements in §63.6625. 1.9.15 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. (§63.6625(h)) 1.10 [Federal-Only] These engines are subject to the requirements in 40 CFR Part 63 Subpart A "General Provisions", Section I as specified in 40 CFR Part 63 Subpart ZZZZ § 63.6665. These requirements include, but are not limited to the following: 1.10.1 Prohibited activities and circumvention in §63.4. 1.10.2 Performance testing in §63.7. • 1.10.3 Monitoring in §63.8. Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 18 •1.10.4 Notification in §63.9. 2. P-106 - Fugitive Emissions of VOCs from Equipment Leaks; Permit-etif Factor Fo J' f on Limitati d` 7 I VOC 2.1 36.02 tpy By Component Type-EPA Component Count, Ongoing Tally, Protocol for Equipment Leak Recordkeeping, and Annually Estimates Emission Calculations 2.1 VOC emissions from equipment leaks shall not exceed the limitations stated above (as provided for under the provisions of Section I, Condition 1.3 and Colorado Regulation No. 3, Part A, Section I.B.36.h and Part C, Section III.B.7, based on maximum production rate identified in an APEN filed by the source dated 11/28/2011). Emissions shall be calculated using the emission factors and equations listed below. 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-95-01 7. These emission factors are fixed until changed by established permit modification procedures. Campor ens i Factors b/compost s hry Light:1g • Valves 9.92 x 10-3 5.51 x 10"3 Connectors 4.41 x 10-4 4.63 x 10-4 Flanges 8.60 x 10-4 2.43 x 10-4 Pump Seals 5.29 x 10-3 2.87 x 10.2 Other* 1.94 x 10-2 1.65 x 10-2 *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters,polish rods,and vents. Emissions of VOC per component: Component count x 8760 hrs/year x VOC content (wt%) x Emission Factor x Control Factor The total fugitive VOC emissions shall be the sum of emissions for each component. 2.1.1 The most recent gas analysis as required under Condition 3.1.2 of this Permit shall be used to determine the appropriate VOC content to use in the above equation. 2.1.2 Records shall be kept of all component additions and deletions and a running tally maintained. An actual physical hard count of the existing components shall be performed at least once every five calendar years. • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit # 95OPWE020 Page 19 0 P-112 Triethylene Glycol Dehydration Unit with condenser and flare; P-113 Triethylene Glycol Dehydration Unit with condenser and flare; Note: These limitations apply to each dehydration unit individually. .w k if - - t v t§ ,,' .. •-m. omp7fanc6 'wa -`...�. s>s _�w r i e ...,a,e eter 'Condition , 1 i tions Emission F 44 4 1 B VOC Emissions 3.1 2.82 tons/yr Based on GRI Parametric Daily HAP Emissions Facility wide: Each individual GlyCalc Model, HAP: 8.0 tons per year Version 4.0 or Higher Total HAPs: 20.0 tons per year Extended Gas EPA Reference Quarterly Analysis - Methods Gas Processed 3.2 16,425 million scf per year ' Recordkeeping Monthly Hours of 3.3 Recordkeeping Monthly Operation Flare Opacity 3.4 No visible emissions EPA Method 22 Daily Compliance 3.5 See Condition 4 Assurance Monitoring Volatile Organic 3.6 See Condition 3.6 Ipound ssions from Oil and Gas Operations Lean Glycol 3.7 6.25 gallons/minute . Recordkeeping Weekly Recirculation Rate NESHAP Subpart 3.8 < 1984 lb/yr benzene or See Condition 3.8 HH <3MMscf/day 3.1 Emissions of air pollutants from each dehydrator shall not exceed the limitations listed in the Summary Table 4 above. Compliance with the annual limits shall be determined on a rolling 12- month total. By the end of each month a new twelve month total is calculated based on the previous twelve months data. Monthly records of the actual emissions shall be maintained by the applicant and made available to the Division for inspection upon request. (Construction Permits 01WE0506 and 05WE0579, as modified under the provisions of Section I, Condition 1.3). 3.1.1 VOC and HAP emissions shall be calculated monthly using the Gas Research Institute's GLYCaIc Model, Version 4.0 or higher. Monitoring of the following parameters to be entered into the GLYCaIc Model shall be monitored weekly: triethylene glycol circulation rate, flash tank temperature and pressure, and inlet (wet) gas pressure and temperature. Monitoring of the following parameters to be entered into the GLYCaIc Model shall be monitored daily: condenser outlet temperature. • The condenser outlet temperature recorded shall be the highest temperature reading Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 20 recorded on the strip chart for any calendar day (midnight to midnight). Values o0 parameters shall be representative of the unit's operation during the month. 3.1.2 Samples of inlet gas shall be collected and analyzed (extended gas analysis) annually to determine CI to C5, n-hexane, benzene, toluene, ethyl benzene and total xylene (BTEX) composition. If any of the analyses indicates the BTEX constituent concentrations exceed the values listed in the table below, frequency of extended gas analyses will revert to quarterly. The first quarterly sample shall be taken three months after the sample that indicated a BTEX constituent exceeded the parameters in the table was taken. Frequency of sampling and analysis will move to semi- annually after four (4) subsequent analyses and to annually after two (2) subsequent semi-annual analyses indicate that the BTEX constituents remain at or below the values in the table below. Component Value Criteria Benzene Content of Gas 234.0 ppm At or Below Toluene Content of Gas 360.0 ppm At or Below Ethyl Benzene Content of Gas 20.0 ppm At or Below Xylene Content of Gas 270.0 ppm At or Below 3.1.3 Flash gas emissions shall be vented back into the process at all times, resulting in zer• emissions from the flash tank. 3.2 The gas processed by the glycol dehydration unit shall not exceed the limitations listed in Summary Table 3 above (Construction Permits 01WE0506 and 05WE0579, as modified under the provisions of Section I, Condition 1.3). The gas throughput to the dehydration unit shall be recorded monthly using existing flow meters. A twelve month rolling total will be maintained to monitor compliance with annual limitations. An average daily gas throughput rate shall be determined by dividing the monthly gas throughput by the number of operating days in the previous month. This average daily gas throughput rate shall be used in the monthly GLYCalc runs required by Condition 3.1. 3.3 The Hours/Days of Operation shall be monitored monthly and recorded and maintained to be made available to the Division upon request. The days of operation shall be used to calculate an average daily gas throughput to be used in the GLYCalc model runs as required by Condition 3.1. 3.4 [State-only] The flare shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the division, determine whether it is operating properly. (Colorado Regulation No. 7, Section XVII.B.1.c) • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 21 • Compliance shall be monitored by conducting EPA Method 22 observations for one minute daily. The result(s) of the visual observations shall be kept on file and made available for Division review upon request. 3.5 The source shall follow the Compliance Assurance Monitoring (CAM) requirements as outlined in Section II, Condition 4 of this permit. 3.6 Any still vent and flash separator or flash tank shall reduce uncontrolled actual emissions of VOCs by an average of at least 90 percent through the use of air pollution control equipment. (Colorado Regulation No. 7, Section XII.H) 3.6.1 [State-only] All air pollution control equipment shall be operated and maintained pursuant to manufacturer specifications or equivalent to the extent practicable, and consistent with technological limitations and good engineering and maintenance practices. The owner or operator shall keep manufacturer specifications or equivalent on file. In addition, all such air pollution control equipment shall be adequately designed and sized to achieve the required control efficiency rates and to handle reasonably foreseeable fluctuations in emissions of volatile organic compounds. (Colorado Regulation No. 7, Section XVII.B.1.a) 3.7 The maximum pumping rate of lean glycol shall not exceed 6.25 gallons per minute. The actual • pumping rate shall be recorded on a weekly basis. Records shall be made available for Division review upon request. (Construction Permits 01WE0506 and 05WE0579, as modified under the provisions of Section I, Condition 1.3) 3.8 This source is subject to 40 CFR Part 63 Subpart HH - National Emission Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities. The following requirements apply: 3.8.1 These dehydrators are exempt from all requirements, save recordkeeping in §63.774(d)(1), provided the criterion in Condition 3.8.1.1 or 3.8.1.2 below is met: (§63.764(e)(1)) 3.8.1.1 The actual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere shall be less than 0.90 megagram per year, or 1984 lbs per year, as determined by the procedures specified in Condition 3.8.3 (§63.764 (e)(1)(ii)). OR 3.8.1.2 The actual annual average flowrate of natural gas to the glycol dehydration unit is less than 85 thousand standard cubic meters per day (3.0 MMSCF/day), as determined by the procedures specified in Condition 3.8.4 (§63.764(e)(1)(i).) 3.8.2 Records shall be kept of the actual average benzene emissions (in terms of benzene emissions per year) as determined in accordance with Condition 3.8.3 §63.772(b)(2) (§63.774(d)(1)(ii)). • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit # 95OPWE020 Page 22 3.8.3 The determination of actual average benzene emissions from this glycol dehydration uni shall be made using the procedure described in Condition 3.8.3.1 below. Emissions shall be determined with federally enforceable controls in place. 3.8.3.1 The actual average benzene emissions shall be determined using the model GRI- GLYCalc, Version 3.0 or higher, and the procedures presented in the associated GRI-GLYCalc, Technical Reference Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit and may be determined using the procedures documented in the Gas Research Institute (GRI) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI-95/0368.1) (§63.772(b)(2)(i)). 3.8.4 The determination of actual flowrate of natural gas to the glycol dehydration unit shall be made using the procedure described in Condition 3.8.4.1 below. 3.8.4.1 The facility shall install and operate a monitoring instrument that directly measures natural gas flowrate to the glycol dehydration unit with an accuracy of plus or minus 2 percent or better. The source shall convert annual natural gas flowrate to a daily average by dividing the annual flowrate by the number of days per year the glycol dehydration unit processed natural gas. (§63.722(b)(1)(i)) 4. Compliance Assurance Monitoring 4.1 The Compliance Assurance Monitoring (CAM) requirements in 40 CFR Part 64, as adopted b. reference in Colorado Regulation No. 3, Part C, Section XIV, apply to the three Waukesha Model L-7042 GSI and the three Model L-7044 GSI engines with respect to the NOx and CO limitations identified in Section II, Condition 1.1, and the two glycol dehydration units with respect to VOC and HAP limitations identified in Section II, Condition 3.1 as follows: 4.1.1 For the engines, the permittee shall follow the CAM Plan provided in Appendix G of this permit. Excursions, for purposes of reporting, are any time the thermocouple temperature indicates a temperature less than 750° F or greater than 1250° F, or a pressure drop across the catalyst of more than 3 inches of water from the pressure drop measured during the performance test. Excursions shall be reported as required by Section IV, Conditions 21 and 22.d of this permit. 4.1.2 For the glycol dehydration units, the permittee shall follow the CAM Plan provided in Appendix H of this permit. Excursions, for purposes of reporting are any calendar day (midnight to midnight) in which the average condenser outlet temperature exceeds 140° F, or the absence of a flame within the flare. Excursions shall be reported as required by Section IV, Conditions 21 and 22.d of this permit. 4.1.3 Operation of Approved Monitoring 4.1.3.1 At all times, the owner or operator shall maintain the monitoring, including but not limited to, maintaining necessary parts for routi repairs of the monitoring equipment (40 CFR Part 64 § 64.7(b), as adopt Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 23 • by reference in Colorado Regulation No. 3, Part C, Section XIV). 4.1.3.2 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 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). 4.1.3.3 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). Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 24 4.1.3.4 After approval of the monitoring required under the CAM requirements, 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). 4.1.4 Quality Improvement Plan (QIP) Requirements 4.1.4.1 Based on the results of a determination made under the provisions of Condition 4.1.3.3.b, 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). 4.1.4.2 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 bis reference in Colorado Regulation No. 3, Part C, Section XIV). 4.1.4.3 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 4.1.4.3.a through d above) (40 CFR Part 64 § 64.8(b)(2)(v), as adopted by reference in Colorad. Regulation No. 3, Part C, Section XIV). Operating Permit 95OPWE020 First Issued: June I, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 25 • 4.1.4.4 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). 4.1.4.5 Following implementation of a QIP, upon any subsequent determination pursuant to Condition 4.1.3.3.b, the Division or the U.S. EPA may require that an owner or 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). 4.1.4.6 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). 4.1.5 Reporting and Recordkeeping Requirements 4.1.5.1 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 4.1.3 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 Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit # 95OPWE020 Page 26 exceedances occurring (40 CFR Part 64 § 64.9(a)(2)(iii), as adopted b}. reference in Colorado Regulation No. 3, Part C, Section XIV). 4.1.5.2 General Recordkeeping Requirements: In addition to the recordkeeping requirements in Section IV, Condition 22.a through c. a. The owner or operator shall maintain records of any written QIP required pursuant to Condition 4.1.3 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). 4.1.6 Savings Provisions • 4.1.6.1 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). 4.1.6.2 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, applicable (40 CFR Part 64 § 64.10(a)(2), as adopted by reference • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 27 • Colorado Regulation No. 3, Part C, Section XIV). 4.1.6.3 Nothing in these CAM requirements shall restrict or abrogate the authority of the 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 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 28 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 on 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 modifications or reconstruction on which construction commenced prior to permit issuance. Emission Unit Description& Applicable Requirement Justification Number C-148 Waukesha L-7042 GSI Reg I.III.A.I.b- Internal combustion engines are not considered fuel burning 1478 HP Particulate emissions from equipment for the applicable requirements of Regulation 1. C-135 Waukesha L-7042 GSI fuel-burning equipment 1478 HP Reg I.VI.B.5.a-Sulfur C-151 Waukesha L-7042 GSI dioxide emissions from 1478 HP fuel-burning equipment C-166 Waukesha L-7044 O51 1680 HP C-174 Waukesha L-7044 O51 1680 HP • C-176 Waukesha L-7044 GSI 1680 HP Station-wide Reg 4-Wood Burning This Station does not include any wood burning stoves or wood Stoves burning appliances,or advertise,or sell such devices. Reg 6 Part A-Adoption None of these provisions currently apply to any of the sources at of Federal NSPS the Station. Requirements Reg 6 Part B-State Only None of these State-only provisions currently apply to any of the NSPS Requirements sources at the Station. Reg 7 V.C The Station is not a gasoline terminal,bulk gasoline Station or the type of gasoline dispensing Station subject to the provisions. Station-wide Reg 7 VI.B.1 These provisions apply to the storage of petroleum liquids in tanks Reg 7 V1.B.2 with greater than 40,000 gallons capacity. Storage of Petroleum Distillates Reg 7 V II.C-Crude Oil These provision apply to the storage of crude oil in tanks with Storage greater than 40,000 gallons capacity. Reg 10-SIP Rules Conformity of federal actions to SIPS and FlPs 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 n� applicable to the source. This permit shield shall not alter or affect the following: Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 29 • 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)O), 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. Stream-lined Conditions 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,Condition I.I Colorado Regulation No. 7, Section XVIl.E.2.b [emission standards] — State Only Requirement—for engines C-135 and C-151 only until compliance with Condition 1.9 Section II, Condition 1.9 Colorado Regulation No. 7, Section XVIl.E.3.b.(i) [control requirements] — State Only Requirement —for engines C-148, C-166, C-174, and C-176 only until compliance with Condition 1.9 Section II, Condition 3.5 Colorado Regulation No. 1, Section 11.A.5 [opacity limit] Section II, Condition 3,7 Colorado Regulation No. 7, Section XVII.D [dehy control requirements]—State-only • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit # 95OPWE020 Page 30 SECTION IV - General Permit Conditions (5/22/2012) • 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, § 1.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.I7. 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 § 1 I2(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 §§ ILA., 11.B., ILC., ILE., ILF., 11.1, and Ili a. To Control Emissions Leaving Colorado 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. • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit # 95OPWE020 Page 31 • 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 (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. Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 32 Nothing in this section shall abrogate the Division's authority to conduct its own performance test(s)if so warrantecl i 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 (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. • Operating Permit 95OPWE020 First Issued: June I, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 33 • 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; (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. Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit # 95OPWE020 Page 34 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.I 1. & I6.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 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. • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 35 • 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, 5 VII.E 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: 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. • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 36 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.I. 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. I, § III.D.I. 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, &6 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, Part B 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, Part B,without first receiving a construction permit. 13. No Property Rights Conveyed Regulation No.3, 5 CCR 1001-5, Part C, § V.C.I I.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. • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 37 • 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 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 1001-17 • The permittee shall comply with the provisions of Regulation No, 15 concerning emissions of ozone depleting compounds. Sections I., II.C., lID., Ill. 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. • "Prompt" is defined as follows: Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 38 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 specify 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. 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. Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit ft 95OPWE020 Page 39 • 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. 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. 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, § Ill., 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 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. 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. • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 40 25. Severability Clause • Regulation No. 3, 5 CCR 1001-5, Part C, G 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. 26. 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 I 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. 27. Special Provisions Concerning the Acid Rain Program Regulation No. 3, 5 CCR 1001-5, Part C, $$ V.C.I.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. 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. • 28. 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. 29. Volatile Organic Compounds Regulation No. 7, 5 CCR 1001-9, $$ III & V. The requirements in paragraphs a,b and e apply to sources located in an ozone non-attainment area or the Denver I-hour ozone attainment/maintenance area. 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, Section VIII.C.3. b. Except when 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 b� Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Marla Compressor Station Permit# 95OPWE020 Page 41 • 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. The permittee shall not 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, Section VI,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. 30. 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 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendices • 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 - CAM PLAN - ENGINES H - CAM PLAN - DEHYS I - AOS APPLICABILITY REPORTS *DISCLAIMER: None of the information found in these Appendices shall be considered to be State oift Federally enforceable, except as otherwise provided in the permit, and is presented to assie the source, permitting authority, inspectors, and citizens. • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix A Inspection Information Page 1 • APPENDIX A Inspection Information Directions to Plant: The station is in the southeast quarter of Section 28, Township 4 North, Range 64 West in Weld County. The station is located west of the intersection of Weld County Road (WCR) 55 and WCR 40 on the north side of WCR 40. The Marla Station is located south of Kersey, Colorado. Safety Equipment Required: Hard Hat, Safety Shoes, Ear Protection, Eye Protection with Side Shield, Fire Retardant Clothing Facility Plot Plan: Figure 1 shows the plot plan as submitted on April 28, 2011 with the source's Title V Operating Permit Renewal Application. List of Insignificant Activities: 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. 1,000 gallon Methanol tank 100 bbl Methanol tank 1,000 gallon Lube Oil tank 210 bbl Lube Oil tank 1,000 gallon TEG glycol tank 1,000 gallon Norkool glycol tank 20 bbl slop oil tank Two 30,000 gallon pressurized condensate storage tanks Pressurized Condensate Truck Loadout Two Dehy Reboilers 20 bbl stormwater tank Five 80 bbl stormwater tanks Six 80 bbl produced water tanks Condenser combustor Six engine blowdown vents • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix A Inspection Information Pa 2 I i.,.- - i • �t ' :Ir .1 ' I !I I ;;, ;st — ,.. II i i i. I: - :. `:i}� I) 0� r'-t't �`1 �� I O F ` . Olli 4 1;71 tf�°\ t t 1 ! -- . il • • • d __.. ti iI o o ' i I --i to, �g 1 i i .`,X7.:5-1. :o- -_ ID t ! a, -4! i 0a:e J `i} 1� I l mlhl • Fg ii i ':r. N a tat i COUNTY RD sa s o z iip4Iii o i• 6 : isn :'..iii ? = s - ; 9 i a.mmp 0 I�.•. 3 1„ t- 5 _., II .+: i n; Z ' z4 21 i 5 - ' ! 3z 4 IIII Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 1 0 APPENDIX B Monitoring and Permit Deviation Report Reporting Requirements and Definitions with codes ver 6/1/06 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. permittee must comply with all conditions of this operating permit. Any permit noncompliance constitutes iolation 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. 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 lipuirements, including those attributable to upset conditions and malfunctions as defined in this Appendix, the obable cause of such deviations, and any corrective actions or preventive measures taken. All deviations from Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 2 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, "upset" shall refer to both emergency conditions and upsets. 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 Complianc. 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 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. • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 3 SPmpliance 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. 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. 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. Further, periods of excess emissions during startup, shutdown and malfunction may not be found to be a violation of an emission limitation or standard where the source adequately shows that any potential deviations as a result of these infrequent periods ere minimized to the extent practicable and could not have been prevented through careful planning, design, or were unavoidable to prevent loss of life, personal injury, or severe property damage. Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 4 Startup, Shutdown, Malfunctions, Emergencies, and Upsets Understanding the application of Startup, Shutdown, Malfunctions, Emergency provisions, and the Upset 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 Division 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. Emergencies and Upsets Under the Emergency provisions of Part 70 and the Upset provisions of the State regulations, certain operational conditions may act as an affirmative defense against enforcement action if they are properly reported. DEFINITIONS S 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. Upset means an unpredictable failure of air pollution control or process equipment which results in the violation of emission control regulations and which is not due to poor maintenance, improper or careless operations, or is otherwise preventable through exercise of reasonable care. • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 5 • 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 upset 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 Upsets) may be referenced and the form need not be filled out in its entirety. FACILITY NAME: DCP Midstream, LP —Marla Compressor Station OPERATING PERMIT NO: 95OPWE020 REPORTING PERIOD: (see first page of the permit for specific reporting period and dates) Deviations noted Upset/Emergency During Period?' Deviation Code 2 Condition Reported During Period? Operating Permit Unit ID Unit Description YES NO YES NO • C-I48 Waukesha Model L-7042 GSI Natural Gas Fired Internal Combustion Reciprocating Engine,4-cycle,Standard Rich Burn, 1478 HP;powering a natural gas compressor C-135 Waukesha Model L-7042 GSI Natural Gas Fired Internal Combustion Reciprocating Engine,4-cycle, Standard Rich Burn, 1478 HP;powering a natural gas compressor C-151 Waukesha Model L-7042 O51 Natural Gas Fired Internal Combustion Reciprocating Engine,4-cycle, Standard Rich Burn, 1478 HP:powering a natural gas compressor P-106 Equipment Fugitive Leak VOC Emissions C-166 Waukesha Model L-7044 651 Natural Gas Fired Internal Combustion Reciprocating Engine,4-cycle, Standard Rich Burn, 1680 HP;powering a natural gas compressor C-174 Waukesha Model L-7044 GSI Natural Gas Fired Internal Combustion Reciprocating Engine,4-cycle, Standard Rich Burn, 1680 HP;powering a natural gas compressor C-176 Waukesha Model L-7044 GSI Natural Gas Fired Internal Combustion Reciprocating Engine.4-cycle,Standard Rich Burn, 1680 HP;powering a natural gas compressor • P-I12 Natural Gas Dehydration System using triethylene glycol Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 6 Deviations noted Upset/Emergency During Period?' Deviation Code 2 Condition Reported Operating Permit Unit During Period? ID Unit Description YES NO YES NO P-1 13 Natural Gas Dehydration System using triethylene glycol 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 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 7 • APPENDIX B Monitoring and Permit Deviation Report-Part II FACILITY NAME: DCP Midstream, LP —Marla Compressor Station OPERATING PERMIT NO: 95OPWE020 REPORTING PERIOD: Is the deviation being claimed as an: Emergency Upset 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 Upsets/Emergencies Reported (if applicable) Deviation Code Division Code QA: • SEE EXAMPLE ON THE NEXT PAGE Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 8 EXAMPLE • FACILITY NAME: Acme Corp. OPERATING PERMIT NO: 96OPZZXXX REPORTING PERIOD: 1/1/04 - 6/30/04 Is the deviation being claimed as an: Emergency Upset 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 4/10/96 END- 1800 4/10/96 Action Taken to Correct the Problem Line Blown Out Measures Taken to Prevent Reoccurrence of the Problem Replaced Line Filter Dates of Upsets/Emergencies Reported (if applicable) 5/30/04 to A. Einstein, APCD Deviation Code Division Code QA: • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Monitoring and Permit Deviation Report Page 9 APPENDIX B Monitoring and Permit Deviation Report- Part III REPORT CERTIFICATION SOURCE NAME: DCP Midstream, LP — Marla Compressor Station FACILITY IDENTIFICATION NUMBER: 1230243 PERMIT NUMBER: 95OPWE020 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.38. 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 • 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 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix C Compliance Certification Report Page 1 • APPENDIX C Required Format for Annual Compliance Certification Reports 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 Midstream, LP—Marla Compressor Station OPERATING PERMIT NO: 95OPWE020 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 f each term and condition is the method specified in the Permit, unless otherwise indicated and described in th deviation report(s). Note that not all deviations are considered violations. Operating Deviations Monitoring Was compliance continuous or Method per Permit Unit Unit Description Reported Permit'. intermittent?' ID Previous I Current YES I NO Continuous I Intermittent C-148 Waukesha Model L-7042 GSI Natural Gas Fired Internal Combustion Reciprocating Engine,4- cycle,Standard Rich Burn, 1478 HP;powering a natural gas compressor C-135 Waukesha Model L-7042 GSI Natural Gas Fired Internal Combustion Reciprocating Engine,4- cycle,Standard Rich Burn, 1478 HP;powering a natural gas compressor C-I51 Waukesha Model L-7042 GSI Natural Gas Fired Internal Combustion Reciprocating Engine,4- cycle, Standard Rich Burn, • 1478 HP;powering a Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix C Compliance Certification Report Page 2 • Monitoring Operating Deviations Was compliance continuous or P g Method per intermittent?' Permit Unit Unit Description Reported ' Permit? ID Previous Current YES I NO Continuous I Intermittent natural gas compressor P-I06 Equipment Fugitive Leak VOC Emissions C-I66 Waukesha Model L-7044 GSI Natural Gas Fired Internal Combustion Reciprocating Engine,4- cycle,Standard Rich Burn, 1680 HP;powering a natural gas compressor C-174 Waukesha Model L-7044 GSI Natural Gas Fired Internal Combustion Reciprocating Engine,4- cycle,Standard Rich Burn, 1680 HP;powering a natural gas compressor C-176 Waukesha Model L-7044 GSI Natural Gas Fired Internal Combustion • Reciprocating Engine,4- cycle, Standard Rich Burn 1680 HP;powering a natural gas compressor P-I 12 Natural Gas Dehydration System using triethylene glycol P-I 13 Natural Gas Dehydration System using triethylene glycol General Conditions Insignificant Activities 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. 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. } 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. •TE: Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix C Compliance Certification Report Page 3 •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 I) 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. "Compliance status for these sources shall be based on a reasonable inquiry using readily available information. • • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix C Compliance Certification Report Page 4 • 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.38. 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), .S., makes any false material statement, representation, or certification in this document is guilty of a llfisdemeanor 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 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 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix D Notification Addresses Page 1 APPENDIX D • Notification Addresses I. 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: Matt Burgett 2. United States Environmental Protection Agency Compliance Notifications: Office of Enforcement, Compliance and Environmental Justice Mail Code 8ENF-T • U.S. Environmental Protection Agency, Region VIII 1595 Wynkoop Street Denver, CO 80202-1129 Permit Modifications, Off Permit Changes: Office of Partnerships and Regulatory Assistance Air and Radiation Programs, 8P-AR U.S. Environmental Protection Agency, Region VIII 1595 Wynkoop Street Denver, CO 80202-1129 • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix E Permit Acronyms Page 1 1111 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 • EF - Emission Factor EPA - Environmental Protection Agency FI - Fuel Input Rate in MMBtu/hr FR - Federal Register G - Grams Gal - Gallon GPM - Gallons per Minute 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 P - Process Weight Rate in Tons/Hr PE - Particulate Emissions PM - Particulate Matter • PMi0 - Particulate Matter Under 10 Microns Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix E Permit Acronyms Page 2 PSD - Prevention of Significant Deterioration • PTE - Potential To Emit RACT - Reasonably Available Control Technology SCC - Source Classification Code SCF - Standard Cubic Feet SIC - Standard Industrial Classification SO2 - Sulfur Dioxide TPY - Tons Per Year TSP - Total Suspended Particulate VOC - Volatile Organic Compounds • • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT • Air Pollution Control Division Colorado Operating Permit Appendix F Permit Modifications Page 1 • APPENDIX F Permit Modifications DATE OF SECTION NUMBER, DESCRIPTION OF REVISION REVISION CONDITION NUMBER 11 • 0 Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix G Compliance Assurance Monitoring Plan - Engines Page 1 APPENDIX G • Compliance Assurance Monitoring Plan - Engines I. Background a. Emission Unit Description: C-148, C-135, and C-151: Three Waukesha Model L-7042 GSI Internal Combustion Engines, 1478 HP each C-166, C-174, and C-176: Three Waukesha Model L-7044 GSI Internal Combustion Engines, 1680 HP each b. Applicable Regulation, Emission Limit, Monitoring Requirements: Regulation: Operating Permit Section Il., Condition 1.1, Colorado Regulation No. 7, Section XVII.E.2.b (until compliance with Section II, Condition 1.9) Emission Limitations: C-148: NOx 42.82 tons/yr CO 42.82 tons/yr C-135: NOx 28.54 tons/yr 2.0 o / • CO 42.2.822 tons/yr 3.0 g/hp-hr C-151: NOx 14.27 tons/yr 1.0 g/hp-hr CO 28.54 tons/yr 2.0 g/hp-hr C-166, C-174, C-176 (each): NOx 32.45 tons/yr CO 32.45 tons/yr c. Control Technology: Non-Selective Catalytic Reduction Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix G Compliance Assurance Monitoring Plan - Engines Page 2 • Monitoring Approach Indicator No. I Indicator No. 2 1. Indicator Temperature of exhaust gas into catalyst Pressure drop across the catalyst Measurement Approach Thermocouple Measured in inches of water II. Indicator Range The indicator range is a temperature between The indicator range is a pressure drop across the 750°F and 1250°F. catalyst that is within three inches of water from Excursions above 1250°F trigger engine the pressure drop across the catalyst measured shutdown. Excursions below 750°F trigger during the initial performance test(or within notification of excursion. Excursions trigger the three inches of the manufacturer's specified permittee to investigate the engine performance range if the pressure drop was not determined and make any repairs or adjustments necessary. during an initial performance test). Any adjustments or repairs shall be recorded in Excursions trigger the permittee to investigate a log, to be made available to the Division upon the catalyst performance and make any repairs request. or adjustments necessary. Any adjustments or repairs shall be recorded in a log,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 across the catalyst catalyst. The minimum accuracy is+/- 5 °F. while the engine is operating. b. Verification of Operational Thermocouple manufacturer guarantee. Manometer manufacturer guarantee. I. QA/QC Practices/Criteria Calibration annually. Per manufacturer's recommendation. d. Monitoring Frequency Daily. Monthly f. Data Collection Procedures Temperature data will be automatically or Pressure drop will be recorded once per month. manually recorded on days that the engine is operating. e. Averaging Time None None. Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H Compliance Assurance Monitoring Plan- Dehys Page 1 APPENDIX H i Compliance Assurance Monitoring Plan - Dehydrators I. Background a. Emission Unit Description: Natural Gas Dehydration Systems using triethylene glycol (P-112, P-113); b. Applicable Regulation, Emission Limit, Monitoring Requirements: Regulations: Operating Permit Section II, Condition 3.1 Emission Limitations: VOC (each dehy) 2.82 TPY Any Individual HAP (facility-wide) 8.0 TPY Total HAP (facility-wide) 20.0 TPY c. Control Technology: Condenser(one for both units) Flare (one for both units) • • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H Compliance Assurance Monitoring Plan - Dehys Page 2 • Monitoring Approach Indicator No. 1 Indicator No. 2 I. Indicator Condenser Outlet Temperature Flare Measurement Approach The outlet temperature is monitored with a Presence of a flame is continuously monitored thermocouple. with thermocouple or equivalent temperature sensing device. Device senses heat and when there is an absence of a flame, then an alarm is sent to the control room. II. Indicator Range An excursion is any calendar day(midnight to Any absence of a flame will trigger an midnight)in which an average temperature above investigation to determine the problem and to 140°F is recorded. Excursions trigger an inspection perform corrective action, record keeping and corrective action. relating to the problem,and reporting of the problem when necessary. III. Performance Criteria a. Data Representativeness Temperature is measured at the outlet of the Device sensing heat will determine the presence condenser. or absence of the flame. b. Verification of Thermocouple manufacturer guarantee. The observation of the presence of a flame will Operational Status indicate that the device is operational. c. QA/QC Annual calibration. Sensor will be calibrated and maintained. tices/Criteria . Monitoring Frequency Daily. Heat sensor will be monitored continuously. f. Data Collection Outlet temperature automatically or manually Excursions and any adjustments or repairs made Procedures recorded daily if operating. to the flare following an excursion shall be recorded in a log. e. Averaging Time Daily average. Readings representative of the day Heat sensor will operate continuously and (24-hour period)will be collected (i.e., a minimum averaging will not be necessary. of 4 readings will be taken throughout the day at approximately 6 hour intervals). • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix J AOS Applicability Reports Page 1 • APPENDIX J Applicability Reports ver 10/1/11 Note: A MS Word version of this Appendix can be found at: http://www.cdphe.state.co.us/ap/oilgaspermitting.html DISCLAIMER: These are only example reports and do not cover all possible requirements. • • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix J AOS Applicability Reports Page 2 Sgine 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.38. or 2) 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, 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. linted or Typed Name Title Signature Date Signed Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix J AOS Applicability Reports Page 3 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: 999/1234/001 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, 200* ❑ 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 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 • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix J AOS Applicability Reports Page 4 • NSPS JJJJ Example Report Format DISCLAIMER: This is only an example report and does not cover all possible JJJJ requirements. 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: Acme Gas Processing Source ID: 999/1234/001 Permit#: 93OPXX999 Date: October 1, 2008 Manufacturer: BestEngineCompany Model: 777 LowNox Nameplate HP: 1340 me Type: 2 Stroke Rich Burn anufacture 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. ❑ NSPS JJJJ does not apply to this engine. ❑ 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 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix J AOS Applicability Reports Page 5 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@l5% 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 60.4230. 60.4237 N/A - Emergency Engines. 60.4238 - 60.4242 Compliance Requirements for Manufacturers—(Not Applicable) i 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 (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. • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix J AOS Applicability Reports Page 6 • (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 NON, 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 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix J AOS Applicability Reports Page 7 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: 999/1234/001 Permit#: 93OPXX999 Date: October 1, 2008 Manufacturer: BestEngineCompany Model: 777 LowNox Nameplate HP: 1340 Engine Type: 2 Stroke Rich 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. ❑ MACT ZZZZ does not apply to this engine. • n 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 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 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? (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 • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix J AOS Applicability Reports Page 8 • (a) The engine is subject to the emission limits in table la and the operating limits in table lb. 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 200 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. .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 (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 • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix J AOS Applicability Reports Page 9 (b) a continuous parameter monitoring system (CPMS) shall be installed to measure t. 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 rollin averages to within the operating limitation and measuring the pressure drop across t� 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. 63.6645 Notifications (a) Submit notifications in §§ 63.7(b) & (c), 63.8(e), (O(4) and (f)(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(1) 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 • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix J AOS Applicability Reports Page 10 • (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. (f) 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. 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 mi-annual compliance reports. Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix J AOS Applicability Reports Page 11 • • • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix J AOS Applicability Reports Page 1 • • • Operating Permit 95OPWE020 First Issued: June 1, 1999 Renewed: DRAFT we amp &c DCP Midstream a 370 17th Street,Suite 2500 �Ap � Denver,CO 80202 {p M am. y i ry 303-595-3331 • tsio 11 � May 10, 2011 (6)Cs UPS Tracking No: 1ZF4691502 96285459 Qcpar! b•oo Mr. Matt Burgett $0 Colorado Department of Public Health and Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 SUBJECT: Marla Compressor Station Operating Permit 95OPWE020 TV Renewal Corrections Mr. Burgett: DCP Midstream, LP (DCP) submitted at Title V renewal application for Title V Operating Permit 95OPWE020. It has come to our attention that we had a few small errors in that application. Please find attached the following corrected forms: 1) Revised form 307s for the two dehydrators. The reboiler rating on these units was incorrectly . listed in the old application. Unit P-112 has a 0.85 MMBTU/hr heater and Unit P-113 has a 1.0 MMBTU/hr heater. 2) Revised form 602 Facility-wide HAPs. On the facility-wide emission summary sheet, the dehydrator controlled HAP emissions were incorrectly linked to the summary sheet without changing the ton/yr numbers to lb/yr. We have also attached the revised emission summary sheet for the facility. 3) Lastly, a revised insignificant emission calculation spreadsheet for the condensate loadout and insignificant emission summary sheet. The condensate loadout was incorrectly labeled as 2.8 MMgal/yr. The correct throughput is 5.2 MMgal/yr. The actual calculations did not change, just the note was incorrect. Please replace these sheets in the aforementioned submittal. Should you have any questions regarding this request, please contact me at (303) 605-1716 or wdhill@dcpmidstream.com. Sincerely, DCP Midstream,LP Wesley Hill Senior Environmental Specialist • Attachments ;a-!`-spy • Operating Pennit 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: Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code:P-112 4. Dehydrator(Unit)code: 5. Unit description:Triethylene glycol dehydrator for dehydration of inlet wet gas stream 6. Indicate the dehydrator control technology status. I Uncontrolled X Controlled If the dehydrator is controlled,enter the control device number(s)from the appropriate forms: 2000-400 2000-403 X 7. Manufacturer: unknown 9. Regenerator heater design rate or maximum continuous rating (mmBTU/hr): 0.85 8. Model&serial number: TBD O10. Date first placed in service: November 2005 Date of last modification: 11. Flash Tank:X Yes •No Flash tank vented to: .. atmosphere x recycled 12. Glycol Circulation rate: 6.25 gallons per minute(maximum) gallon per pound of H2O OR 13. Pipeline Capacity:(mmscf/day):45.0 14. Glycol Type: x Triethylene Glycol Ethylene Glycol Other(specify) 15. Glycol Make-up Rate(gallons/year): 16. Computer model input&output printout attached x Glycalc 4.0 results 17, Gas Pressure(psi):900 18. Gas Temperature(—F):80 19. Gas composition test results VOC BTEX HEXANE Test date:02/2009 value units value units value units 8.89 Volume% 0.08 Volume% 0.107 Volume • • Operating Pennit 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:Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code:P-113 4. Dehydrator(Unit)code: 5. Unit description:Triethylene glycol dehydrator for dehydration of inlet wet gas stream 6. Indicate the dehydrator control technology status. Uncontrolled X Controlled If the dehydrator is controlled,enter the control device number(s)from the appropriate forms: 2000-400 2000-403 X 7. Manufacturer: unknown 9. Regenerator heater design rate or maximum continuous rating (mmBTU/hr): 1.0 8. Model&serial number:TBD •10. Date first placed in service: November 2005 Date of last modification: 1 I. Flash Tank:X Yes No Flash tank vented to: atmosphere x recycled 12. Glycol Circulation rate: 6.25 gallons per minute(maximum) gallon per pound of H2O OR 13. Pipeline Capacity: (mmscf/day):45.0 14. Glycol Type: X Triethylene Glycol Ethylene Glycol Other(specify) 15. Glycol Make-up Rate(gallons/year): 16. Computer model input&output printout attached X Glycalc 4.0 results 17. Gas Pressure(psi): 900 18. Gas Temperature(I TF):80 19. Gas composition test results VOC BTEX HEXANE Test date: 02/2009 value units value units value units 8.89 Volume% 0.08 Volume% 0.107 Volume S 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 i. Facility name:Marla Compressor Station 2. Facility identification code:CO 1230243 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 X Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name !Quantity'. Units '. Quantity Units 50-00-0 Formaldehyde 1.60 TPY 67-56-1 Methanol 0.50 TPY 75-07-0 Acetaldehyde 0.45 TPY 107-02-8 Acrolein 0.43 TPY 71-43-2 Benzene 0.90 TPY 108-88-3 Toluene ,"j, 1.13 TPY 1330-20-7 Xylene 0.53 TPY 100-41-4 Ethylbenzene 0.04 TPY 110-54-3 n-Hexane ,fi j t `+in „ 0.12 TPY 1,kw r F 540-84-1 224-TMP , 0.00 TPY • ., .., TPY r ,fi ,z ,4, „ li TPY .frrr1 ''r� y 4 f M� ,, TPY q S 5a*f` a,it,Aty, + . , TPY 4 ( l , i r TPY L l ' TPY TPY iiiiid r » t , �Yi IT , .. - TPY hilt rcca l Tr cl- "fa` i, , . ' s. -+�uyINITIa+ati` .n a Du.i�'`+ TPY 3Ir S,,h1} p,tf"`r�Y'i ll lr' r TPY iSin"`. �va '.,'i a, a' , r TPY 3 ' TPY " TPY •`+a:$ 4Irt 4.N ttti a; TPY TPY • NOTE: If there is a permit for this unit, the permit limits are the same as the potential to emit. a Y4 • Ian 00000eo = o - - 0 8 1111111900111110 = . �d"'it 1989969110111110 e o z ,1��s_ a�V. e 111111106611111 e e = I111116666111IH e o a =1111111811111111 - - 198961618011111u - , ' e e 1998966 111III0 - 0 111111166911111u e a 7 U !Hhi - I1 o n ..ry I t a 691111199911111® _ E 4 E '161111199911111® _ e 1 i w X0066600009111118 t 0 1960966699111110 1989996999111118 1999698999111110 e � 0. :� a T. X699696699111111 W r; 0001111666111119 - 3 1909999116111111 1111966660111111 e ,. 1111111661111111 , - . - 1666111990111111 0 X111111111011111O - . a 109899609111111® - o e o 111Oli1II111IMIMI! 9 1 c F < ry g.��t 661166669611111® g .E i 1116661696111111 T 1 ,. ry.4.x . f 198669666911111® e o e , a 0 1966669699111119 e 2 o U_ 1666699666111119 0 2 o 1969999999111111 i " _ i e Z% 66'6 V Q 1.. 3: $ LI - aas = d € 3 v " € f ti ti U Ci .2 2 n u 2 = 1, - g 9 f�tm.1 X S • • • Insignificant Emissions • Marla Compressor Station DCP Midstream,LP NOx CO CC Description Insignificant Per ftpy)' (fay) (Wry) - EF Spumy 1 000 gal,Methanol lank Regulation No.3,Pad A.Section 110.1.a — — 0 02 TANKS 4.0.9d 300 bbl Methanol lank Regulation No.3,Pad A,Section 11.0.1 a — — 0.20 TANKS 4.0.9d 1,000 gal tube oil lank Regulation No.3,Pad C,Section ILE.3 aaa ._ — neg. 210 bbl.Lube oil tank Regulation No.3,Part C,Section II.E.3.aaa — — neg. 1.000 gal TEG glycol lank Regulation No.3,Part A,Section ll.13.1.a — — neg. 1.000 gal Norkool glycol lank Regulation No.3,Part A,Section 11.D.1.a — — nag. 20 bbl slop oil lank Regulation No.3,Part A.Section 1113.1.a -- — neg. 30,000 gal Pressurized Condensate Storage Tank Regulation No.3,Part A,Section 11.0.1.zz — — neg. N/A-Not a source of emissions 30,000 gal Pressurized Condensate Storage Tank Regulation No.3.Part A.Section 11.0.t.zz — — neg. WA-Not a source of emissions Pressurized Condensate Truck Loadout Regulation No.3,Part A,Section II.D.1.a — — 0.33 Engineering Estimate _ Dehy Reboiler H-112 Regulation No.3,Part A,Section II.D.1.a 036 0.30 0.02 AP-42 Section 1.4,Table 1.4-1 Dehy Reboller R-113 Regulation No.3.Pad A,Section II.D.1.a 042 0 35 0.02 AP-42 Section 1.4,Table 1.4-2 20 bbl,Stormwater tank Regulation No.3,Pad A,Section 11.0.1 a —- ._ nog, 80 bbl,Stomrwaler tank Regulation No.3,Pad A.Section II.D.1.a — — neg. 80 bbl,Stormwater tank Regulation No.3,Pad A,Section 11.0.1 a -- — neg. — 80 bbl,Stormwater tank Regulation No.3,Pad A.Section 11.0 la — -- neg. 80 bbl,Stormwater lank Regulation No.3,Pad A,Section II.D.1.a -- — neg. 80 bbl,Produced Water Tank Regulation No.3,Pad A,Section II.D.I.a — -- 0.10 5 Memo 09-02 60 bbl.Produced Water Tank Regulation No.3,Pad A,Section II.D.1.a — — 010 S Mena 09-02 80 bbl.Produced Water Tank Regulation No.3,Pad A,Section 11.0.1.a — -- 010 S Mena 0902 80 bbl,Produced Water Tank Regulation No.3,Part A,Section 11.D,1a — — 0.10 S Memo 09-02 110 bbl,Produced Water Tank Regulation No.3,Pad A,Section 110.1 a — — 0.10 5 Memo 09-02 NRCC Flares and Vapor Oxidizers,Table 4 Condenser Combustor Regulation No.3,Part A,Section II.D.1-a 0.43 152 — late Factors — C-148 vent bbwdown Regulation No.3,Part A,Section II.D.t.a -- — 0.18 ngineering Estimate C-135 vent blowdown Regulation No.3,Part A,Section 11.0.1 a -- — 0.18 ngineering Estimate C-151 vent blowdown Regulation No.3,Pad A,Section II.0.1.a — -- 0.18 ngineering Estimate C-166 vent blowdown Regulation No.3,Part A,Section II.D.1.a — — 0.18 ngineedng Estimate C-174 vent bbwdown Regulation No.3,Part A,Section II.D.1.a — — 0.18 ngineering Estimate C-176 vent bbwdown Regulation No.3,Pad A.Section 11.0.i.a .— — of ngineering Estimate Total Insignificant Emissions 1.21 2.18 2.18 'There is a blowdown vent for each compressor so each Is a separate emission point with estimated emissions of 0.18 Ipy VOC each • • Pressurized Condensate Truck Loadout Emissions Marla Compressor Station • DCP Midstream,LP Calculation of VOC Emissions from Truck Loading Hoses Assumptions: There are two hoses connected to each truck during loadout. Liquid Hose Diameter = 2 inches(average) Vapor Hose Diameter = 2 Inches(worst case) 'Liquid Hose Length = 1 feet(average) 'Length accounts for length of 'Vapor Hose Length = 1 feet(worst case) isolation valve on pressurized hose. Liquid Hose Volume = 0.0218 cubic feet Vapor Hose Volume = 0.0218 cubic feet Specific Gravity of liquid loaded Vapor Molecular Weight of liquid loaded Ibs/Ibmol Each truck is pressurized to storage tank pressure as listed below. Condensate Tank Pressure= 97.0 prig 109.2 psia Each condensate tank truck has a capacity of 7000 gallons per load. Tot.volume of products loaded/year and tot.loadout events/year as listed below. Product Gallon/Month Loads/Month Condensate 432.203 61.74 Annual throughput o15.2 MMgal/yr All liquid lines contain liquid products at individual specific gravity. All vapor retum 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(psia) V=volume of hoses(cubic feet) number of Ibmoles of product in hoses R=Universal Gas Constant=10.73 cubic feet'psi/Ibmole'deg R • T=ave.loadout temp. = 60 deg F = 519.67 deg R Vapor Density n(lbmole/f13) MW(Ib/Ibmole) Vapor Density(Ib/ft3) Condensate 0.0196 ' 32.4 = 0.6345 Liquid Density of Density Liquid Density Specific Gravity Water(lb/gal) (gal/ft3) (Ib/ft3) Condensate 0.65 8.3300 7.48 40.50 VOC Emissions from Liquid Hoses Loaded Llq.Density Hose Vol. Loads Per Emission Emission Product If b/ft31 ft3/1 Ioadi Month jib/month) Pon/month] Condensate 40.50 0.0218 61.74 54.53 0.03 Total 54.53 0.03 VOC Emissions from Vapor Return Hoses _ Loaded Vap.Density Hose Vol. Loads Per Emission Emission Product If bHt31 ft3/load Month Ib/month ton/month Condensate 0.6345 0.0218 61.74 0.85 0.00 Total — — — 0.85 0.00 MONTHL1i VOC.EMI5SIp1d$F.I'fQM�#4i.LQA�ING,Rp,GK ' .M a;`Cog1PTe84gp$tetlbg .. .: Hose Emissions From Condensate Loading= 0.03 ton/month Tot.Loadout Emiss a 0.33 tpy M DCP Midstream, LP C Midstiearn. Marla Compressor Station Title V Operating Permit Renewal Application Submitted To: Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South APCD-SS-B 1 Denver, CO 80246-1530 April 2011 Prepared By: Olsson Associates 4690 Table Mountain Drive, Suite 200 Golden, Colorado 80403 OLSSON ASSOCIATES • • • DCP Midstream ii Operating Permit Renewal Application Marla Compressor Station April 2011 • TABLE OF CONTENTS 1.0 Introduction 1 2.0 Facility Emissions 2 2.1 Point Source Emissions 3 2.1.1 Internal Combustion Sources 3 2.1.2 Triethylene Glycol Dehydration Units 3 2.2 Fugitive Emissions 4 2.2.1 Equipment Leaks 4 3.0 Applicable Requirements 6 3.1 Federal Requirements New Source Review 6 3.2 Federal Operating Permits 6 3.3 New Source Performance Standards 7 3.4 National Emission Standards for Hazardous Air Pollutants 8 3.5 Compliance Assurance Monitoring (CAM) 9 3.6 State Regulations 10 3.7 Chemical Accident Prevention Provisions, 40 CFR 68 11 • List of Tables Table 2-1 Facility Emissions Summary Table 2-2 Facility Equipment Inventory Table 2-3 Insignificant Emission Sources List of Appendices Appendix A Colorado Department of Public Health and Environment Title V Operating Permit Application Forms Appendix B Emissions Calculations Appendix C Current APENs Appendix D Construction Permits Appendix E Facility Plot Plans and Process Flow Diagrams • DCP Midstream iii Operating Permit Renewal Application Marla Compressor Station April 2011 List of Acronyms percent AP-42 EPA AP-42 Emission Factors APEN Air Pollutant Emission Notice BTEX benzene,toluene,ethylbenzene,and xylene CAM Compliance Assurance Monitoring cf cubic feet CO carbon monoxide EPA Tank 4.0 U.S.Environmental Protection Agency Tanks Version 4.0 EPA U.S.Environmental Protection Agency ESD emergency shutdown ft feet gal gallons HAP hazardous air pollutant hp horsepower hr hour in inch lb pound lb/yr pounds per year m3 cubic meters MACT Maximum Achievable Control Technology min minute • MMBtu 1,000,000 British thermal units Mscf 1000 standard cubic feet MMscf 1,000,000 standard cubic feet mol. molecular neg. negligible NOx nitrogen oxides NESHAPs National Emission Standards for Hazardous Air Pollutants NSPS New Source Performance Standard PM10 particulate matter,less than 10 microns psi pounds per square inch RMP Risk Management Plan scf standard cubic feet SIC Standard Industrial Classification SO2 sulfur dioxide SOx sulfur oxides tpy tons per year VOC volatile organic compound wt weight yr year • DCP Midstream iv Operating Permit Renewal Application Marla Compressor Station April 2011 • 1.0 INTRODUCTION DCP Midstream is submitting this application for a Title V Operating Permit renewal for the Marla Compressor Station located in Weld County,Colorado. The facility is located in the SE'4 of the SE'4 of Section 28,Township 4 North,Range 64 West,approximately 13 miles southeast of Greely, Colorado. This compressor station is classified under Standard Industrial Classification 4922.The Marla Compressor Station uses six(6)gas-fired internal combustion engines to drive compressors to transmit natural gas gathered from gas field laterals to a primary pipeline.All six engines are controlled through non-selective catalytic reduction(NSCR). The Marla Compressor Station was first issued Operating Permit 95OPWE020 on June 1,1999 and most recently was renewed on May 1,2007. This application will serve to renew the existing operating permit for an additional five year term. The completed permit application forms are contained in Appendix A,supporting calculation documentation is contained in Appendix B,current Air Pollutant Emission Notices(APENs)are provided in Appendix C,construction permits are in Appendix D and facility plot plans and process flow diagrams are in Appendix E This renewal permit incorporates the applicable requirements from the following construction permits: 01WE0499,01WE0500,01WE0501,01WE0502,01WE0503,01WE0504,01WE0505,01 WE0506 and 05WE0579. • • DCP Midstream 1 Operating Permit Renewal Application Marla Compressor Station April 2011 • 2.0 FACILITY EMISSIONS Emission sources found at the Marla Compressor Station include both point source and fugitive sources. All facility emission source types are summarized as follows, with emissions from these sources summarized in Table 2-1. Emissions are shown in detail in Appendix B. • Internal combustion sources (six compressor engines) • TEG dehydration units (two TEG units) • Fugitive equipment leaks Table 2-1. Facility Emissions Summary Constituent Emissions (tpy) NO, 183.0 CO 211.5 VOC 128.9 SO2 3.1 PM lo 0 0.20 Single Greatest HAP 1.60 (Formaldehyde) Total HAP 3.41 The facility equipment inventory is summarized in Table 2-2. • Table 2-2. Marla Compressor Station Facility Equipment Inventory Facility AIRS Point Source Usage Source Description Identifier Number C-148/P-102 123/0243/052 Compressor Engine Waukesha Model L-7042 GSI (1,478 HP) C-135/P-103 123/0243/053 Compressor Engine Waukesha Model L-7042 GSI(1,478 HP) C-151/P-104 123/0243/054 Compressor Engine Waukesha Model L-7042 GSI (1,478 HP) P-106 123/0243/056 Fugitive Emissions Inline Service Equipment Leaks including the JT Skid C-166/P-109 123/0243/059 Compressor Engine Waukesha Model L-7044 GSI (1,680 HP) C-174/P-110 123/0243/060 Compressor Engine Waukesha Model L-7044 GSI(1,680 HP) C-176/P-111 123/0243/061 Compressor Engine Waukesha Model L-7044 GSI(1,680 HP) P-112 123/0243/062 Dehydrator TEG Natural Gas Dehydration Unit . P-I 13 123/0243/063 Dehydrator TEG Natural Gas Dehydration Unit DCP Midstream 2 Operating Permit Renewal Application Marla Compressor Station April 2011 • 2.1 POINT SOURCE EMISSIONS 2.1.1 Internal Combustion Sources The Marla Compressor Station uses six (6) gas-fired internal combustion engines to drive compressors to transmit natural gas gathered from gas field laterals to a primary pipeline. AU six engines are controlled through non-selective catalytic reduction (NSCR). Internal combustion sources at the MVS Compressor Station include the following: • Three Waukesha 7042 GSI 1,478 hp natural gas fired compressor engines (AIRS Point Numbers 052, 053 and 054) • Three Waukesha 7044 GSI 1,680 hp natural gas fired compressor engines (AIRS Point Numbers 059, 060 and 061) Emissions from reciprocating engines are produced during the combustion process, and are dependent upon the fuel mixture, engine design specifications, and specific properties of the natural gas being burned. The pollutants of concern are Nitrogen Oxides (NOx), Carbon Monoxide (CO) and Volatile Organic Compounds (VOC). Emissions of NON, CO, VOCs, and formaldehyde were calculated based on manufacturer's data and vendor specifications. All other pollutants (Sulfur dioxide (SO2), particulate matter(PMto), and hazardous air pollutants (HAPs)) were estimated based on EPA's AP-42 emission factors. Emission factors, their sources, and calculated potential emissions are presented in Appendix B. • 2.1.2 Triethylene Glycol Dehydration Units There are two triethylene glycol (TEG) dehydration units (AIRS 062 & 063), which are used to remove entrained water from the natural gas stream. TEG is contacted with the natural gas stream to reduce the moisture in the natural gas to a desired level. The wet glycol is regenerated using glycol reboilers. Natural gas fired heaters for the reboilers are rated at 0.85 million and 1.0 British thermal units per hour (MMBtu/hr). Regenerator still vent vapors are routed to a condenser and then a combustor flare for both TEG units. Each TEG unit is rated at 45 million standard cubic feet per day (MMscfd). Flash tank vapors are recycled back to the wet inlet gas line for further processing. The emissions from this process are estimated using Gas Research Institute's GLYCalc Model version 4.0. This model estimates VOC and HAP emissions based on inputs of the glycol recirculation rate, cubic feet of gas processed, inlet temperature and pressure of the processed wet gas. Emissions for each TEG dehydration unit are presented in Appendix B. • DCP Midstream 3 Operating Permit Renewal Application Marla Compressor Station April 2011 • 2.2 Fugitive Emissions 2.2.1 Equipment Leaks Emissions of VOCs and HAPs from fugitive equipment leaks (AIRS 056) at the Marla Compressor Station were calculated using EPA-453 emission factors, a recent gas analysis, a natural gas liquids analysis and an actual hard count of components. Emissions are generated from inline service equipment including connections, flanges, open-ends, pumps and valves. The compressor station also operates a Fuel Conditioning Unit that removes heavy hydrocarbon liquids such as propane from the gas stream to effectively lower the natural gas Btu value for combustion in stationary engines. Storage of the heavy hydrocarbons or natural gas liquids (NGLs) is contained within the two pressurized onsite bullet tanks. Emissions from the dehydrator equipment sources are attached in Appendix B. 2.3 Insignificant Activities Insignificant sources are the sources for which an Air Pollution Emission Notice(APEN) is not required. • Insignificant sources are listed in Table 2-2 of Section 2.0. • Table 2-3. Marla Compressor Station Insignificant Emission Sources Marla Compressor Station Insignificant Emission Sources Source Description Regulatory Reference Insignificant Source of Emissions 1,000 gal, Methanol Tank Regulation No. 3, Part A, Section II.D.1.a 300 bbl Methanol Tank Regulation No. 3, Part A, Section II.D.1.a 1,000 gal Lube Oil Tank Regulation No. 3, Part C, Section II.E.3.aaa 210 bbl, Lube Oil Tank Regulation No. 3, Part C, Section II.E.3.aaa 1,000 gal TEG glycol Tank Regulation No. 3, Part A, Section II.D.1.a 1,000 gal Norkool Glycol Tank Regulation No. 3, Part A, Section II.D.1.a 20 bbl Slop Oil Tank Regulation No. 3, Part A, Section II.D.1.a 30,000 gal Pressurized Condensate Regulation No. 3, Part A, Section II.D.1.zz Storage Tank 30,000 gal Pressurized Condensate Regulation No. 3, Part A, Section II.D.1.zz Storage Tank • Pressurized Condensate Truck Loadout Regulation No. 3, Part A, Section II.D.1.a DCP Midstream 4 Operating Permit Renewal Application Marla Compressor Station April 2011 • Dehy Reboiler H-112 Regulation No.3,Part A,Section II.D.1.a Dehy Reboiler H-113 Regulation No.3,Part A,Section II.D.1.a 20 bbl,Stormwater Tank Regulation No.3,Part A,Section II.D.1.a 80 bbl,Stormwater Tank Regulation No.3,Part A,Section II.D.1.a 80 bbl,Stormwater Tank Regulation No.3,Part A,Section II.D.1.a 80 bbl,Stormwater Tank Regulation No.3,Part A,Section II.D.1.a 80 bbl,Stormwater Tank Regulation No.3,Part A,Section II.D.1.a 80 bbl,Produced Water Tank Regulation No.3,Part A,Section II.D.1.a 80 bbl,Produced Water Tank Regulation No.3,Part A,Section II.D.1.a 80 bbl,Produced Water Tank Regulation No.3,Part A,Section II.D.1.a 80 bbl,Produced Water Tank Regulation No.3,Part A,Section II.D.1.a 110 bbl,Produced Water Tank Regulation No.3,Part A,Section II.D.1.a Condenser Combustor Regulation No.3,Part A,Section II.D.1.a C-148 vent blowdown Regulation No.3,Part A,Section II.D.1.a C-135 vent blowdown Regulation No.3,Part A,Section II.D.1.a C-151 vent blowdown Regulation No.3,Part A,Section II.D.1.a C-166 vent blowdown Regulation No.3,Part A,Section II.D.1.a • C-174 vent blowdown Regulation No.3,Part A,Section II.D.1.a C-176 vent blowdown Regulation No.3,Part A,Section II.D.1.a DCP Midstream 5 Operating Permit Renewal Application Marla Compressor Station April 2011 • 3.0 APPLICABLE REQUIREMENTS The Marla Compressor Station is located in Weld County, Colorado, which is designated as non- attainment for ozone. The facility is subject to federal and state requirements. A summary of the potentially applicable requirements is presented below. 3.1 Federal Requirements New Source Review The federal New Source Review program applies to new or modified sources in both attainment and non-attainment areas that result in emission increases in excess of specified thresholds. Weld County is designated as non-attainment for ozone (also known as the 8-Hour Ozone Control Area), so sources in this area are potentially subject to Non-Attainment New Source Review (NNSR) if emissions of NO„ or VOC are in excess of 100 tpy. The Marla Compressor Station is an existing facility and does not have new or modified sources of emissions that would emit more than 100 tpy of both NQ and VOC; therefore, will not trigger NNSR. Specific source types are subject to PSD review if their potential to emit (PTE) exceeds 100 tons per year(tpy) of any criteria air pollutant. All other source types are subject to PSD review if their PTE exceeds 250 tpy. The Marla Compressor Station is not one of the specific source types and does not exceed a PTE of 250 tpy of any criteria pollutant; therefore, it is not subject to PSD review. On June 30, 2010, EPA promulgated the Green House Gas (GHG) Tailoring Rule listed in 75 Federal Register 31514. This rule establishes a phased schedule for applying PSD review to major sources of • GHGs. Step 1 of the phase-in is the period from January 2, 2011 to June 30, 2011. Step 2 of the phase in the period between July 1, 2011 and June 30, 2013. The Colorado Air Quality Control Commission adopted revisions to Regulation No. 3, Part A to implement the directives contained in the federal GHG Tailoring Rule, including the phase-in framework in the federal rule. During the Step 1 period, PSD review will apply to GHG emissions from a new stationary source only if the source is subject to PSD review anyway due to its projected emissions of non-GHG pollutants. See Regulation No. 3, Part A, Section I.B.44.d(i); see also 40 C.F.R. §§ 51.166(b)(48)(iv), 52.21(b)(49)(iv). During the Step 1 period, no source will be subject to PSD or Title V permitting requirements due solely to GHG emissions. During the Step 2 period, a source can be subject to PSD or Title V permitting requirements based solely on the level of GHG emissions from the project. DCP has also estimated and reported in this application the emissions of CO2e from the project are approximately 53,747 tpy. Based on these estimated emissions, the Marla Compressor Station is not subject to PSD review for any criteria pollutant; therefore, GHG emissions from the project are not subject to PSD review. 3.2 Federal Operating Permits Sources are required to obtain a Part 70 Title V Operating Permit if they are a"major source" under the Title V Rules. See Regulation No. 3, Part C, Section III.C.3.a. A major source is defined as a stationary source that emits or has a PTE of 10 tpy of any single HAP, 25 tpy of any group of HAPs in the aggregate, or 100 tpy of any criteria air pollutant. The Marla Compressor Station has criteria pollutant emissions greater than 100 tpy and is renewing the current Title V operating permit. • Regulation No. 3, Part A, Section I.B.44.e specifies that beginning July I, 2011, GHG emissions shall be "subject to regulation" under Title V operating permit requirements if a new stationary source will emit DCP Midstream 6 Operating Permit Renewal Application Marla Compressor Station April 2011 • or have a PTE of 100,000 tpy of CO2e and 100 tpy total of GHG mass emissions from all six GHG pollutants. See also 40 C.F.R. § 70.2 (definition of"major source"). Since this application is being filed prior to July 1, 2011, does not otherwise trigger Title V, and involves emissions of less than 100,000 tpy of CO2e, Title V does not apply to the GHG emissions from the project. Current CO2e emission estimates for the Marla Compressor Station are approximately 53,747 tpy generated from combustion sources, engine blowdowns and rod packing venting emissions. This amount is less than the Title V regulatory applicability volume. 3.3 New Source Performance Standards 40 CFR Part 60 Subpart A - General Provisions The General Provisions of the New Source Performance Standards (NSPS), 40 C.F.R. Part 60, Subpart A. apply to any stationary source that contains an "affected facility" to which a NSPS is applicable. As discussed below, this facility is subject to several NSPS; therefore, various elements of Subpart A will apply. NSPS Subpart Dc, Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units (40 C.F.R. §§ 60.40c to 60.48c) Subpart Dc applies to each "steam generating unit" for which construction, modification, or reconstruction commenced after June 9, 1989 and that has a maximum design heat input capacity of 29 megawatts (MW) (100 MMBtu/hr) or less, but greater than or equal to 2.9 MW (10 MMBtu/hr). Section 60.41c states: • "Steam generating unit means a device that combusts any fuel and produces steam or heats water or heats any heat transfer medium. This term includes any duct burner that combusts fuel and is part of a combined cycle system. This term does not include process heaters as defined in this subpart." There are no steam generating units with a design heat input capacity in excess of 10.0 MMBtu/hr at the Marla Compressor Station; therefore, NSPS Subpart DC does not apply. NSPS Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels)for Which Construction, Reconstruction, or Modification Commenced After July 23, 1984 (40 C.F.R. §§ 60.110b to 60.117b) Subpart Kb applies to each storage vessel with a capacity greater than or equal to 75 cubic meters (m3) [19,800 gallons (gal)] used to store volatile organic liquids (VOL) for which construction, reconstruction, or modification is commenced after July 23, 1984. The Marla Compressor Station storage tanks do not have a capacity greater than 19,800 gallons or are pressurized tanks; therefore, Subpart Kb does not apply. 40 CFR Part 60 Subpart KKK- Standards of Performance for Equipment Leaks of VOC From Onshore Natural Gas Processing Plants (40 C.F.R. §§ 60.630 to 60.636) Subpart KKK applies to equipment leaks of VOC at onshore natural gas processing plants that commenced construction, modification or reconstruction after January 20, 1984. A "natural gas processing plant" is defined in Subpart KKK as any processing site engaged in the extraction of natural gas liquids from field gas, fractionation of mixed natural gas liquids to natural gas products, or both [40 C.F.R. § 60.631]. The Marla Compressor Station will extract natural gas liquids in a fuel conditioning • skid unit and, on that basis, will be subject to Subpart KKK. The fuel conditioning skid will only process the amount of gas needed to operate the natural gas fired equipment at the facility, which will be less DCP Midstream 7 Operating Permit Renewal Application Marla Compressor Station April 2011 than 10 MMSCFD. Only the fuel conditioning skid will be subject to NSPS KKK as the rest of the equipment at the facility is not associated. Since the throughput of the fuel skid is less than 10 MMSCFD, Section 60.633(d) provides that pumps in light liquid service, valves in gas/vapor service, and light liquid service are not subject to the routine monitoring specified in Sections 60.482-2(a)(1) and 60.482-7(a) (LDAR). The fuel skid will be subject to weekly audio, visual, and olfactory inspections (AVOs) (see e.g., Section 60.482-2(a)(2) for pumps in light liquid service—the fuel conditioning skid will have a pump in light liquid service). DCP will conduct weekly AVOs for the entire facility as a best management practice. 40 CFR Part 60 Subpart.JJJJ- Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (40 C.F.R. §§ 60.4230 to 60.4248) Subpart JJJJ applies to stationary spark ignition internal combustion engines that commence construction after June 12, 2006, where the engines are 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); On or after January 1, 2008, for lean burn engines with a maximum engine power greater than or equal to 500 HP and less than 1,350 HP; On or after July 1, 2008, for engines with a maximum engine power less than 500 HP; or On or after January 1, 2009, for emergency engines with a maximum engine power greater than 19 KW (25 HP). For the purposes of this subpart, the date that construction "commences" is the date the engines are ordered by the owner or operator [40 C.F.R. § 60.4230(a)]. The Waukesha 7042 and 7044 GSI compressor engines are 1,478 hp and 1,680 hp 4-stroke rich burn engines, respectively, which were ordered prior to June 12, 2006; therefore, the engines are not subject to NSPS JJJJ. 3.4 National Emission Standards for Hazardous Air Pollutants 40 CFR Part 63 Subpart HH-National Emission Standards for Hazardous Air Pollutants from Oil and Natural Gas Production Facilities (40 C.F.R. §§ 63.760 to 63.777) The National Emission Standards for Hazardous Air Pollutants (NESHAP) Subpart HH applies to oil and natural gas production facilities that are major and area sources of HAPs. A major source is defined as a stationary source that emits or has the potential to emit 10 tpy of any single HAP or 25 tpy of any group of HAPs in the aggregate. An "area source" is any stationary source of HAPs that is not a"major source" [40 C.F.R. § 63.2]. The Marla Compressor Station is an area source of HAPs. At area sources, the potentially affected emissions units only include triethylene glycol dehydration units. The Marla Compressor Station operates two TEG dehydration units that are located in the Colorado 8- hour Ozone Control Area. Emissions from these TEG sources are required to reduce uncontrolled emissions by 90 percent through the use of a condenser or other air pollution control equipment. Facility emissions from each TEG dehydrator are controlled by a condenser and combustion flare. Total projected actual annual benzene emissions are less than one ton. DCP Midstream maintains GRt GLYCalc reports to document VOC and HAP emissions. DCP Midstream 8 Operating Permit Renewal Application Marla Compressor Station April 2011 40 CFR Part 63 Subpart ZZZZ-National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines (40 C.F.R. §§ 63.6580 to 63.6675) Subpart ZZZZ applies to stationary reciprocating internal combustion engines (RICE) at major or area sources of HAP emissions. The Marla Compressor Station is designated as an area source of HAPs. A stationary RICE located at an area source of HAPs is "existing" if construction or reconstruction commenced before June 12, 2006 [40 C.F.R. § 63.6590(a)(1)(iii)]. For the purposes of Subpart ZZZZ, the date that construction commences is the date of installation. Each of the six compressor engines were installed prior to June 12, 2006; therefore Subpart ZZZZ does not apply. 3.5 Compliance Assurance Monitoring (CAM) Compliance Assurance Monitoring (CAM) requirements apply to a pollutant-specific emissions unit (PSEU) at a major source that is required to obtain a part 70 or 71 permit if the unit satisfies all of the following criteria: • The unit is subject to an emission limitation or standard for the applicable regulated air pollutant (or a surrogate thereof); • The unit uses a control device to achieve compliance with any such emission limitation or standard; and • The unit has 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. • There are emission units at the facility that have pre-control emissions that are greater than the major source thresholds and that use control devices to comply with emission standards. The following emission points at the Marla 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 (100 tons per year). 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: • Engine C-148, C-135, C-151 Waukesha Model L-7042 GSI (1,478 hp) • Engine C-166, C-174, C-176 Waukesha Model L-7044 GSI (1,680 hp) The primary purpose of the CAM program is to supplement or enhance the Operating Permit monitoring requirements as necessary to adequately demonstrate compliance. All six of the compressor engines are equipped with non selective catalytic reduction & air/fuel ratio controllers. The exhaust gas temperature on each engine is monitored continuously with thermocouples. The pressure drop across the catalyst is measured in inches of water with a continuously operating manometer. The proper performance envelopes for the control device parameters being monitored are any temperature between 750 °F and 1250 °F and a pressure drop within three inches of water. The CAM provisions require a source to monitor at least one indicator of performance per control device and to perform at least one parameter observation per 24 hours. DCP selected to continuously monitor the exhaust gas outlet temperature and pressure drop across the catalyst. The daily measurement • frequency satisfies the minimum CAM requirement. • Natural Gas Dehydration Units using triethylene glycol (P-112 & P-113) DCP Midstream 9 Operating Permit Renewal Application Marla Compressor Station April 2011 • The CAM provisions require a condenser and combustor flare to be installed for the TEG unit. Excursions or deviations to operating conditions would be where the average condenser temperature exceeds 140 °F or the absence of a pilot light flame within the flare unit. The Marla Compressor Station meets this requirement. 3.6 State Regulations Regulation 3, Part A, Section II Regulation 3, Part A, Section II describes when an Air Pollutant Emission Notice (APEN) must be filed for new, modified, and existing sources. APENs are included in this application for all non-APEN- exempt sources. Copies of current APENs on file with the State of Colorado are included with this application. Regulation 3, Part B Regulation 3, Part B describes the requirements for Construction Permits. This renewal permit incorporates the applicable requirements from the following construction permits: 01WE0499, 01 WE0500, 01WE0501, 01WE0502, 01 WE0503, 01WE0504, 01 WE0505, 01 WE0506 and 05WE0579. Regulation 3, Part C Regulation 3, Part C describes the requirements for Title V Operating Permits. The Marla Compressor Station is subject to Regulation 3, Part C and is permitted under 95OPWE020. Regulation 3, Part D • Regulation 3, Part D sets forth PSD and NNSR requirements. The Marla Compressor Station is not subject to PSD or NSR review at this time. Regulation 6 Regulation 6 incorporates by reference the EPA's New Source Performance Standards (NSPS). NSPS applicability is discussed in Section 3.0 above. Regulation 7, Section X11 Section XII.G.5 provides that Section XII shall not apply to the operation of natural gas compressor stations if the requirements of Section XII.G.5.a-d are met. These include the following: a. Air pollution control equipment is installed and properly operated to reduce VOC emissions from all atmospheric condensate storage tanks (or tank batteries) that have uncontrolled actual emissions of greater than or equal to two tons per year; b. The air pollution control equipment is designed to achieve a VOC control efficiency of at least 95% on a rolling 12-month basis and meets the requirements of Sections XII.C.1.a and XII.C.1.b; Section XII.C.l.a requires all air pollution control equipment used to demonstrate compliance with this Section XII to be operated and maintained consistent with manufacturer specifications and good engineering and maintenance practices. Manufacturer specifications for air pollution control equipment must be kept on file and adequately designed and sized to achieve the control efficiency rates required by Section XII, including the ability to handle reasonably foreseeable fluctuations in VOC emissions. • DCP Midstream 10 Operating Permit Renewal Application Marla Compressor Station April 2011 • Section XII.C.1.b requires all condensate collection,storage,processing and handling operations, regardless of size,to be,to the maximum extent practicable,designed,operated and maintained so as to minimize leakage of VOC to the atmosphere. c. The owner or operator of the natural gas compressor station,DCP in this case,does not own or operate,which it does not,any exploration and production facilities in the 8-Hour Ozone Control Area;and d. The addition of the air pollution control equipment is memorialized,as it will be in this case, a construction permit issued by the Division. Section XII.G.6 provides that a natural gas compressor station subject to Section XII.G.and at which a glycol natural gas dehydrator and/or natural gas-fired stationary or portable engines are operated to comply with Regulation No.7,Sections XII.H.and/or XVI. • Section XII.H requires a still vent and vent from any gas-condensate-glycol(GCG)separator (flash separator or flash tank),if present,on a glycol natural gas dehydrator to reduce uncontrolled actual emissions of VOC by at least 90 percent through the use of a condenser or air pollution control equipment. The Marla Compressor Station meets this requirement. • Section XVI specifies emission control requirements applicable to portable and stationary RICE located in 8-Hour Ozone Control Area. The Waukesha 7042 and 7044 GSI compressor engines are 1,478 hp and 1,680 hp 4-stroke rich burn engines,respectively,will be subject to Section XVI.B.I,which requires rich burn RICE>500 hp to operate with non-selective catalyst reduction and an air fuel ratio controller.The Marla Compressor Station meets this requirement. • Regulation 8 Regulation 8 incorporates by reference the EPA's National Emission Standards for Hazardous Air Pollutants(NESHAPs).NESHAP applicability is discussed in Section 4.0. 3.7 Chemical Accident Prevention Provisions,40 CFR 68 The Accident Prevention rules under 40 CFR Part 68 require covered facilities to conduct a hazard assessment,develop a prevention program,develop an emergency response program,and submit a Risk Management Plan(RMP). Facilities must comply if they have"covered"processes involving regulated, highly hazardous substances in excess of specified threshold levels. The Marla Compressor Station does not have"covered"processes involving regulated,highly hazardous substances in excess of the specified threshold levels in 40 CFR Part 68;therefore this part does not apply. S DCP Midstream 11 Operating Permit Renewal Application Marla Compressor Station April 2011 • Appendix A Colorado Department of Public Health and Environment ID Air Pollution Control Division Title V Operating Permit Application Forms • Marla Compressor Station Title V Operating Permit Application Forms Facility Information The Following Forms are Attached: 2000-100 2000-101 2000-102 2000-102a 2000-102b 2000-602 2000-603 2000-605 2000-607 2000-608 2000-700 2000-800 • • 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 and Name Marla Compressor Station mailing address Street or Route 370 17th Street,Suite 2500 City, State,Zip Code Denver,Colorado 80202 2. Facility location Street Address SESE Section 28,T4N,R64W (No P.O. Box) City,County,Zip Code Weld County,Colorado 3. Parent corporation Name DCP Midstream Street or Route 370 17"Street,Suite 2500 City, State,Zip Code Denver,Colorado 80202 Country(if not U.S.) 4. Responsible Name Joe Kuchinski official Title Vice President,Area Operations North Telephone (303)595-3331 5. Permit contact person Name Wes Hill • Title Senior Environmental Specialist (If Different than 4) Telephone (303)605-1716 6. Facility SIC code: 4922 7. Facility identification code: CO 1230243 8. Federal Tax I. D.Number: 841041166 9. Primary activity of the operating establishment: The Marla Compressor Station operates as a natural gas dehydration and compressor facility. 10. Type of operating permit New Modified X Renewal 11. Is the facility located in a"nonattainment" area: X Yes No If"Yes",check the designated"non-attainment" pollutant(s): Carbon Monoxide X Ozone PMIO Other(specify) • 1 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. Marla Compressor Station, • Operating Permit 95OPWE020,issued June 1, 1999 • Construction Permit Number 01WE0499 issued September 25,2001 for Engine C-148,P-102 AIRS Point Number 052 • Construction Permit Number 01 WE0500 issued September 25,2001 for Engine C-135,P-103 AIRS Point Number 053 • Construction Permit Number 01 WE0501 issued September 25,2001 for Engine C-151,P-104 AIRS Point Number 054 • Construction Permit Number 01 WE0502 issued September 25,2001 for Facility Fugitive Emissions P-106 AIRS Point Number 056 • Construction Permit Number 01WE0503 issued September 25,2001 for Engine C-166,P-109 AIRS Point Number 059 • Construction Permit Number 01 WE0504 issued September 25,2001 for Engine C-174,P-110 AIRS Point Number 060 • Construction Permit Number 01 WE0505 issued September 25,2001 for Engine C-176,P-111 AIRS Point Number 061 • Construction Permit Number 01 WE0506 issued September 25,2001 for TEG Dehydrator P-112 AIRS Point Number 062 • Construction Permit Number 05WE0579 issued February 22,2006 for TEG Dehydrator P-113 AIRS Point Number 063 S 2 Operating Permit Application FACILITY PLOT PLAN FORM 2000-101 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division alFacility Name: Marla Compressor Station Facility Identification Code: CO 1230243 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. See Appendix E 2. The maximum height of each building (excluding stack height). See Appendix E 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. 1 he location of property boundary lines. See Appendix E • 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? Yes x 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? x Yes No List the name(s)of any neighboring state(s)within a 50 mile radius of your facility: Wyoming 11. Operating Permit Application SOURCE AND SITE DESCRIPTIONS FORM 2000-102 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division 40 Facility Name: Marla Compressor Station Facility Identification Code: CO 1230243 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 Marla Compressor Station uses six(6)gas-fired internal combustion engines to drive compressors to transmit natural gas gathered from gas field laterals to a primary pipeline. These engines are controlled through non-selective catalytic reduction (NSCR). The station also includes two(2)triethylene glycol dehydrator units that contact"dry"triethylene glycol with the natural gas stream to remove moisture. The"wet" glycol mixture is regenerated in a still for reuse in the process.These units are equipped with a condenser and combustor device for VOC control.Liquids from the dehydrators are routed to the pressurized slug catchers. Each dehydrator's flash tank vapors are captured by a vapor recovery unit and routed back into the inlet stream.Regenerator still vent vapors are routed to a condenser before being sent to the combustor device. Other equipment on-site includes two pressurized bullet condensate storage tanks, which are considered an insignificant activity. • 2.Site Location and Description (Include instructions needed to drive to remote sites not identified by street addresses) Site location: SESE Section 28,T4N, R64W, Directions from Denver,Colorado: Take I-76 North out of the Denver Metro area,go approximately 3 miles past the town of Hudson and exit I-76 at Co Road 49 and proceed north.Travel north on Co Road 49 for approximately 10 miles and turn east on Co Road 34.Proceed east bound on Co Road 34 for 2 miles,turn north on Co Road 53.Proceed north Co Road 53 for 3 miles and turn east on Co Road 40,proceed for one mile,Marla Compressor Station is at the NW corner of Co Road 40& Co Road 55. 3. Safety Equipment Identify safety equipment required for performing an inspection of the facility: Protection X Other, specify Fire retardant clothing x Hard Hat x Safety shoes x Hearing Protection Gloves 0 4 Operating Pennit Application SOURCE DESCRIPTION-APENS FORM 2000-102A Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division . Facility Name: Marla Compressor Station Facility Identification Code: CO 1230243 NOTE: Each new or updated Air Pollutant Emission Notice (APEN) submitted must be accompanied by payment of $152.90 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) Appendix C contains copies of the following APENs: Source ID AIRS ID Source Usage Source Description C-148, P-102 123/0243/052 Compressor Engine Waukesha 7042-GSI (1,478 hp) C-135, P-103 123/0243/053 Compressor Engine Waukesha 7042-GSI (1,478 hp) C-151, P-104 123/0243/054 Compressor Engine Waukesha 7042-GSI (1,478 hp) Equipment Fugitives 123/0243/056 Facility Equipment Fugitive Emissions Equipment Fugitive Leak VOC P-106 Emissions including the JT Skid C-166, P-109 123/0243/059 Compressor Engine Waukesha 7044-GSI (1,680 hp) C-174, P-110 123/0243/060 Compressor Engine Waukesha 7044-GSI (1,680 hp) C-176, P-111 123/0243/061 Compressor Engine Waukesha 7044-GSI (1,680 hp) TEG Dehydrator 123/0243/062 TEG Dehydration Unit 45 MMscfd P-112 TEG Dehydrator 123/0243/063 TEG Dehydration Unit 45 MMscfd P-113 • 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 (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 x No Filing Fee Enclosed New permit application enclosed: Yes x No Permit modification application enclosed: Yes x No ID 5 Operating Permit Application SOURCE DESCRIPTION - INSIGNIFICANT ACTIVITIES FORM 2000-102B Colorado Department of Public Health and Environment Rev(16-95 Air Pollution Control Division 0 Facility Name:Marla Compressor Station Facility Identification Code: CO 1230243 NOTE:The operating permit must be prepared and submitted on forms supplied by the Division. This is a supplemental form 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 fort 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 1.6.58 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). x 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). 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 less 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. 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. Storage tanks meeting all of the following criteria: 6 (i) annual throughput is less than 400,000 gallons; and (ii) the liquid stored is one of the following: (A) diesel fuels 1-D, 2-D, or 4-D; (B) fuel oils#1 through #6; (C) gas turbine fuels 1-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). x 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 five 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. • x 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 be submitted for any insignificant activities. USE FORM 2000-700 TO PROVIDE AN ITEMIZED LIST OF THE SOURCES OR ACTIVITIES BEING IDENTIFIED AS INSIGNIFICANT ACTIVITIES. DO NOT ITEMIZE INDIVIDUAL PIECES OF LANDSCAPING EQUIPMENT. THE LIST IS NEEDED TO ACCURATELY ACCOUNT FOR ALL ACTIVITIES AT THE FACILITY 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 1. Facility name:Marla Compressor Station 2. Facility identification code: CO 1230243 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. X Attached Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name Quantity Units Quantity Units 50-00-0 Formaldehyde 1.60 TPY 67-56-1 Methanol 0.50 TPY 75-07-0 Acetaldehyde 0.45 TPY 107-02-8 Acrolein 0.43 TPY 71-43-2 Benzene 0.28 TPY 108-88-3 Toluene 0.11 TPY 1330-20-7 Xylene 0.04 TPY • 100-41-4 Ethylbenzene 0.00 TPY 110-54-3 n-Hexane 0.00 TPY 540-84-1 224-TMP 0.00 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. 8 Operating Permit Application PLANT-WIDE CRITERIA AIR POLLUTANTS FORM 2000-603 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division al SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Complete the following emissions summary for the listed emissions at this facility. Air pollutant Actual Potential to Maximum allowable emit TPY TPY TPY Particulates(TSP) 0.2 PM-10 0.2 Nitrogen oxides 183.0 183.0 Volatile organic compounds 128.9 128.9 Carbon monoxide 211.5 211.5 Lead Sulfur dioxide 3.1 Total reduced sulfur • Reduced sulfur compounds Hydrogen sulfide• Sulfuric acid mist Fluorides • 9 Operating Permit Application PERMIT SHIELD PROTECTION FORM 2000-605 Colorado Department of Public Health and Enviromnent IDENTIFICATION Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Specify Emission Source: 4.Do not use 5. Pollutant, 6. Colorado Air Quality 7. Equipment, Regulations State or Only Process NA S 8. 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 io Operating Pennit Application PLANT-WIDE APPLICABLE REQUIREMENTS FORM 2000-607 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division • FORM NOT REQUIRED FOR ALL FACILITIES-SEE INSTRUCTIONS#3 AND#8 ON REVERSE SIDE IF FORM 2000-607 IS USED; FORM 2000-608 MUST ALSO BE COMPLETED 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Pollutant 4. Colorado Air Quality 5. 6.Limitation 7. Compliance Regulations State Status or Only IN OUT Permit Number NA • 8. Is this facility subject to the provisions governing prevention of accidental releases of hazardous air pollutants contained in section 112(r)(7)of the Clean Air Act'? Yes X No Has a prevention plan been prepared'? Yes No Has the plan been submitted to the regulatory agency? Yes No What Agency? Date submitted: 9. Other requirements(e.g.,malfunction reporting, special operating conditions from an State Only Compliance existing permit such as material limitation,hours of operation,etc.) Status IN OUT • ****USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT. THIS FORM IS NOT A SUBSTITUTE FOR FORM 2000-604 ***** 11 Operating Pennit Application PLANT-WIDE COMPLIANCE PLAN FORM 2000-608 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE Rev 06-95 Air Pollution Control Division USE THIS FORM ONLY IF FORM 2000-607 USED • SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor 2. Facility identification code: CO 1230243 Station 3. For facilities that are presently in compliance with all applicable requirements.including any monitoring and compliance certification requirements under Colorado Air Quality Regulation 3.Part C that apply,complete the following. These commitments are part of the application for operating permits. x We will continue to operate and maintain this facility in compliance with all applicable requirements. Form 2000-607 includes new requirements that apply or will apply to this facility during the term of the permit. We will meet such requirements on a timely basis. 4. For facilities not presently fully in compliance,complete the following. This facility 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 sheets.): Applicable Requirement Corrective Deadline Actions 1. • 2. 3. Progress reports will be submitted: Start date: August 1,2011 and every six(6)months thereafter THIS FORM IS NOT A SUBSTITUTE FOR FORM 2000-606 12 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. This form supplements Form 2000-102B for Emission Unit Insignificant Sources Additional Information,Diagrams Item Number 1,000 gal,Methanol tank 300 bbl,Methanol Tank(12,600 gal) 1,000 gal Lube oil tank 210 bbl Lube oil tank(8,820 gal) 1,000 gal TEG glycol tank 1,000 gal Norkool glycol tank 20 bbl,slop oil tank 30,000 gal Pressurized Condensate Storage Tank 30,000 gal Pressurized Condensate Storage Tank Pressurized Condensate Truck Loadout Dehy Reboiler H-112 . Dehy Reboiler H-113 20 bbl,Stormwater Tnk 80 bbl,Stormwater Tank 80 bbl,Stormwater Tank 80 bbl,Stormwater Tank 80 bbl,Stormwater Tank 80 bbl,Produced Water Tank 80 bbl,Produced Water Tank 80 bbl,Produced Water Tank 80 bbl,Produced Water Tank 80 bbl,Produced Water Tank 110 bbl,Produced Water Tank Condenser Combustor C-148 vent blowdown C-135 vent blow down C-151 vent blow down • C-166 vent blow down C-174 vent blow down C-176 vent blow down 1 Operating Permit Application TABULATION OF PERMIT APPLICATION FORMS FORM 2000-800 Colorado Department of Health 09-94 Air Pollution Control Division Facility Name: Marla Compressor Station Facility Identification Code: CO 1230243 ADMINISTRATION This application contains the following forms: Form 2000-100,Facility Identification Fonn 2000-101,Facility Plot Plan Fonns 2000-102.-102A.and-102B.Source and Site Descriptions II. EMISSIONS SOURCE Total Number DESCRIPTION of This Form This application contains the following forms Fonn 2000-200,Stack Identification 9 lone fonn for each facility boiler,printing Fonn 2000-300,Boiler or Furnace Operation For 2000-301,Storage Tanks 6 Form 2000-302,Internal Combustion Engine Form 2000-303,Incineration Fonn 2000-304.Printing Operations Fonn 2000-305,Painting and Coating Operations Form 2000-306,Miscellaneous Processes I Form 2000-307.Glycol Dehydration Unit 2 III. AIR POLLUTION CONTROL Total Number SYSTEM of This Form This application contains the following forms: Form 2000-400.Miscellaneous 8 • Form 2000-401,Condensers 2 Form 2000-402.Adsorbers Form 2000-403,Catalytic or Thermal Oxidation 2 Form 2000-404.Cyclones/Settling Chambers Fonn 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 9 (one for each facility boiler,printing operation, Renortine Form 2000-501,Continuous Emission Monitoring Form 2000-502,Periodic Emission Monitoring Using 7 Portable Monitors Form 2000-503,Control System Parameters or Operation 8 Parameters of a Process Form 2000-504,Monitoring Maintenance Procedures 1 Form 2000-505.Stack Testing Fonn 2000-506,Fuel Sampling and Analysis 8 Form 2000-507,Recordkeeping 9 • Form 2000-508,Other Methods 8 13 • V. EMISSION SUMMARY AND Tmal Number COMPLIANCE CERTIFICATION alibis Form This application umerinr the folhowlgforms 0 Form 2000400,Emission*Unit Hazardous Air Palladino 9 quamiyid emissions,certifying compliance with applicable requirements,and developing a mac plan ❑ Form 2000401,Emission Unit Crime Air Pollutants 9 ❑ Form 2000602,Facility Eaardow Air Patients 1 O Form 2100-503,Facility Crania AirPoiluanu 1 O Form 2000-604,Applicable Requirements and Status of 9 Emission Unit O Form 2000403,Permit Shield Protection Identification 9 ❑ Form 2000406,Emission Unit Compliant Plan- 9 Commitments and Schedule O Form 2000.507,Plant-Wide ApplicableRagtdremau ❑ Form 2000408,Plant-Wide Compliance Plan- Cttenolments and Schedule VI. SIGNATURE OF RESPONSIBLE OFFICIAL - FEDERAL/STATE CONDITIONS A. STATEMENT OF COMPLETENESS I have reviewed this application in its entimty and,based on information and belief formed after reasonable • inquiry,I certify that the etataneats and information contained in this application are true,accurate and complete. • B. CERTIFICATION OF FACILITY COMPLIANCE STATUS-FEDERAUSTATE CONDITIONS(dteck one box only) ❑ I certify that the facility deetaibod in this air pollution permit application is fully in compliance with all applicable require nmb. ❑ I certify that the facility deathbed in this air pollution permit application is firmly in compliance with all applicable requirements,except for the following aniwions unit(s): (list all non-complying units) WARNING: Any person who Inowlogly,as defined in§18-1-501(6),CRS,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 ha accordance with the provisions of§25-7 112.1,C.R.S. Printed or Typed Name Title Joe Kuchindd Vice President,Area Operation North Signature Date Signed , Apt( 1 ?.6 f 2. 011 • • 14 • Opaatiag remit Application CERTIFICATION FOR STATE-ONLY CONDITIONS FORM 2000-800 Colorado Department ofUox6 09-91 Air Pollution Coaool Division Facility Name: Marla Compressor Station Facility Identification Code:CO 1230243 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) x I certify that the facility described in this air pollution permit application is folly in compliance with all applicable requirementi ❑ 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 I.418-1-501(6),C.R.g»make 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.B.S. Printed or Typed Name Title Joe Kachinski Via President,Area Operation North Signature Date Signed SEND ALL MATERIALS TO: COLORADO DEPARTMENT OF HEALTH APCD-SS-131 4300 CHERRY CREEK DRIVE SOUTH DENVER,CO 80246-1530 • 15 • MAJOR SOURCE OPERATING PERMIT APPLICATION APPLICATION COMPLETENESS SUMMARY FORM 1. FACILITY NAME: 2. PERMIT: 3. REVIEW ENGINEER: 4. DATE OF APPLICATION: 5. DATE RECEIVED BY APCD COMPLETENESS DETERMINATION I. IDENTIFYING INFORMATION COMPLETE INCOMPLETE NOT APPLICABLE II. EMISSIONS COMPLETE INCOMPLETE NOT APPLICABLE III. APPLICABILITY COMPLETE INCOMPLETE NOT APPLICABLE IV. COMPLIANCE COMPLETE INCOMPLETE NOT APPLICABLE APPLICATION FORM CERTIFIED FOR TRUTH,ACCURACY, AND COMPLETENESS BY: • OFFICIAL TITLE SIGNATURE DATE APPLICATION EVALUATION COMPLETE(BASIC INFORMATION PRESENT TO BEGIN PROCESSING) INCOMPLETE-RETURN WITH ADDITIONAL INFORMATION BY: COMMENTS REVIEWED BY: DATE • 16 MAJOR SOURCE OPERATING PERMIT APPLICATION APPLICATION COMPLETENESS CHECK LIST • IDENTIFYING INFORMATION COMPLETE INCOMPLETE NOT APPLICABLE A. FACILITY INFORMATION FACILITY NAME, LOCATION&MAILING ADDRESS YES NO PERMIT CONTACT PERSON YES NO RESPONSIBLE OFFICIAL YES NO PERMIT REQUESTED YES NO B. SOURCE DESCRIPTION 1. OPERATIONAL INFORMATION: YES NO SIC/SCC CODES YES NO LISTING AND DESCRIPTION OF EMISSION SOURCE(S) YES NO 2. IDENTIFICATION AND DESCRIPTION OF ALTERNATIVE OPERATIVE SCENARIOS(IF APPLICABLE) YES NO N/A C. PERMIT SHIELD REQUESTED S NO II. EMISSIONS COMPLETE INCOMPLETE NOT APPLICABLE A. EMISSIONS INFORMATION 1. QUANTIFICATION OF ALL EMISSIONS OF REGULATED AIR POLLUTANTS YES NO 2. EMISSION SOURCES: IDENTIFICATION AND DESCRIPTION OF ALL EMISSION SOURCES IN SUFFICIENT DETAIL TO YES NO ESTABLISH THE BASIS FOR FEES AND APPLICABILITY OF REQUIREMENTS. A LIST OF INSIGNIFICANT EMISSIONS UNITS OR ACTIVITIES EXEMPTED YES NO N/A BECAUSE OF SIZE OR PRODUCTION RATE. 4. PROCESS INFORMATION TO THE EXTENT IT IS NEEDED TO DETERMINE OR REGULATE EMISSIONS: FUELS YES NO N/A RAW MATERIAL(S)/MATERIALS USED YES NO N/A PRODUCTION RATES YES NO N/A 5. FOR REGULATED AIR POLLUTANTS, LIMITATIONS ON SOURCE OPERATIONS AFFECTING: EMISSIONS YES NO N/A ANY WORK PRACTICE STANDARDS OS NO N/A 6. OTHER INFORMATION REQUIRED BY ANY APPLICABLE REQUIREMENTS FOR ALL REGULATED AIR POLLUTANTS SUCH AS: FLOW RATES YES NO N/A 17 STACK PARAMETERS YES NO N/A 7. CALCULATIONS ON WHICH EMISSIONS RELATED INFORMATION ARE BASED YES NO N/A • • • 18 III. APPLICABILITY COMPLETE INCOMPLETE NOT APPLICABLE ak 1. CITATION AND DESCRIPTION OF ALL APPLICABLE REQUIREMENTS IIIMES NO 2. OTHER SPECIFIC INFORMATION THAT MAY BE NECESSARY TO IMPLEMENT AND ENFORCE OTHER YES NO APPLICABLE REQUIREMENTS OR TO DETERMINE THE APPLICABILITY OF REQUIREMENTS 3. AN EXPLANATION OF ANY PROPOSED EXEMPTIONS FROM OTHERWISE APPLICABLE REQUIREMENTS YES NO _ N/A IV. COMPLIANCE COMPLETE INCOMPLETE NOT APPLICABLE A. COMPLIANCE STATUS 1. A DESCRIPTION OF THE COMPLIANCE STATUS OF THE SOURCE WITH RESPECT TO ALL YES NO APPLICABLE REQUIREMENTS 2. FOR APPLICABLE REQUIREMENTS WITH WHICH THE SOURCE IS IN COMPLIANCE,A STATEMENT YES NO THAT THE SOURCE WILL CONTINUE TO COMPLY WITH SUCH REQUIREMENTS 3. FOR APPLICABLE REQUIREMENTS THAT WILL BECOME EFFECTIVE DURING THE PERMIT TERM, YES NO _ N/A A STATEMENT THAT THE SOURCE WILL MEET SUCH REQUIREMENTS ON A TIMELY BASIS 4. FOR REQUIREMENTS FOR WHICH THE SOURCE IS NOT IN COMPLIANCE AT THE TIME OF YES NO N/A PERMIT ISSUANCE,A NARRATIVE DESCRIPTION OF HOW THE SOURCE WILL ACHIEVE COMPLIANCE WITH SUCH REQUIREMENTS 5. IDENTIFICATION AND DESCRIPTION OF AIR POLLUTION CONTROL EQUIPMENT AND COMPLIANCE YES NO MONITORING DEVICES OR ACTIVITIES 6. DESCRIPTION OF OR REFERENCE TO ANY APPLICABLE TEST METHOD FOR DETERMINING YES NO • COMPLIANCE WITH EACH APPLICABLE REQUIREMENT B. COMPLIANCE SCHEDULE COMPLETE INCOMPLETE NOT APPLICABLE 1. A SCHEDULE OF COMPLIANCE FOR SOURCES THAT ARE NOT IN COMPLIANCE WITH ALL YES NO N/A APPLICABLE REQUIREMENTS AT THE TIME OF PERMIT ISSUES 2. A SCHEDULE FOR SUBMISSION OF CERTIFIED PROGRESS REPORTS NO LESS FREQUENTLY YES NO N/A THAN EVERY SIX MONTHS FOR SOURCES REQUIRED TO HAVE A SCHEDULE OF COMPLIANCE TO REMEDY A VIOLATION C. COMPLIANCE CERTIFICATION COMPLETE INCOMPLETE NOT APPLICABLE 1. CERTIFICATION OF COMPLIANCE WITH ALL APPLICABLE REQUIREMENTS BY _YES NO A RESPONSIBLE OFFICIAL 2. A STATEMENT OF METHODS USED FOR DETERMINING COMPLIANCE,INCLUDING A DESCRIPTION YES NO OF MONITORING,RECORDKEEPING,AND REPORTING REQUIREMENTS AND TEST METHODS 3. A SCHEDULE FOR SUBMISSION OF COMPLIANCE CERTIFICATIONS YES NO 4. A STATEMENT INDICATING THE SOURCE'S COMPLIANCE STATUS WITH ANY APPLICABLE YES NO ENHANCED MONITORING AND COMPLIANCE CERTIFICATION REQUIREMENTS OF THE FEDERAL ACT • 19 Marla Compressor Station Title V Operating Permit Application Forms C-148/P-102 Waukesha 7042 GSI 123/0243/052 The Following Forms are Attached: 2000-200 2000-302 2000-400 2000-500 2000-502 2000-503 2000-506 2000-507 2000-508 2000-600 • 2000-601 2000-604 2000-605 2000-606 S • 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-102 3a. Construction Permit Number: 01WE0499 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 C-148 2000-303 2000-304 2000-305 2000-306 2000-307 5. Stack identified on the plot plan required on Form 2000-101 Ai 6. Indicate by checking: xi I This stack has an actual exhaust point. Thc_parameiers arc_ntcrcd in Ilcros 7-I 3. 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. Discilinebeighcabovegroundlevel•JL(feet)7 8. Inside at t utlet{checkcne and complete): • Circular 1.47 (tea) Rectangular , length(*et).,,_, width{ :s ip 9- Exhia Normal 6967 tAeflvt) *Mount E � Velocity 'tpu ) 'Calculated Stack Test / rtq Aooa p95W0 100099 ambr t,*motsus content? Yes Noll 7 , 'tit x If!Ye? content: Nornral percent 12. s 84881ip d $on Up. Down ,flo*O tAgl ��{ ,k 713 he �� a ts>�aftstWAY obsiruclioTh bow the exhcensi.� Ae sek`t Yes 4 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. • • Operating Permit Application INTERNAL COMBUSTION ENGINE OPERATION FORM 2000-302 Colorado Department of Rev 06-95 Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-102 4. Engine(Unit)code: C-148 4a.Date first placed in service: 10/10/2000 Date last modified: 09/14/2005 5. Engine use: Powering a natural gas compressor 6. Engine Features: 2-Cycle '\/ 4-Cycle J Spark-ignition Diesel J Standard rich burn Standard lean bum V Air/fuel ratio controller 'I Turbocharger Low-NOx design Other(Describe): 7. Emission controls: No J Yes-Attach control device form J Non-Selective catalytic reduction Thee-way catalyst Selective catalytic reduction Ammonia injected -V Oxidation catalyst Other: 8. Manufacturer: Waukesha 9. Model No: L-7042 GSI S/N: 383730 10. Max Fuel Design Rate: 11.57 mmBTU/hr 11. Horsepower Max Design: Site: 1478 12. Heat Rate: 7,830 BTU/HP-hr 13. Operating Temp: Min. Max. °F • 14. Fuels: Primary Fuel Backup Fuel#1 Fuel Type: Natural Gas Heating Value BTU/SCF 1200 Sulfur Content (Wt.%) 0 (0%H2S) Ash Content, (Wt.%) N/A Moisture Content (%) 0 Maximum Hourly Consumption(Ft3,gal) 9644 scf/hr Maximum Yearly Consumption(Ft3,gal) 84.48 MMscf/yr NOTE: Data entry below is NOT OPTIONAL if parametric monitoring is used for compliance demonstration 15.Opat Low `. Igtutiou tri (degoeos) x Sd '14 a yr Air aid elr rite fit° " � ,,.. : � e a�an rc v isnt emoe`f Fuel kegulatoesetting ***** 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. ***** 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 l.Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-102 4. Unit identification code: C-148 5. Control device code: C-102 6. Manufacturer and model number:Johnson Mathey 7. Date placed in service: 10/10/2000 Date of last modification: 8. Describe the device being used. Non-Selective Catalytic Reduction 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 Emission Outlet pollutant Control Efficiency �ri ''. concentration (%) Y > Y- gr/acf ppmv • NOx 3.0 g/hp-hr VOC r 1.0 g/hp-hr CO 3.0 g hp-hr 10.Discalss lutes the teaterial will be h odl�d or reuse or disposal. disposal. " me have-to be' +ulth1he # use plan htivS,1$rtrit tare limited IG , fotiv'ivib e.tc#eeti t° the vi Sbyu4e. fbs.ie inot iv*. � ' � .r.This. tt a , .' 'a tl tikt b�.. , , sucvpoed� pY ! � a1.' { ' 't 1 tUe$O.130, . ., aa o%Ct ).. whaeislts~rlsa ".�p u ,(tatai • NOTE: COMPLETION OF INFORMATION IN SHADED AREA OF THIS FORM IS OPTIONAL • Operating Permit Application COMPLIANCE CERTIFICATION-MONITORING AND REPORTING FORM 2000-500 Colorado Department of DESCRIPTION OF METHODS USED Rev 06-95 Public Health and Enviromnent FOR DETERMINING COMPLIANCE Air Pollution Control Division 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 Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-102 4. Unit identification code: C-148 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): 'J Periodic Emission Monitoring Using Portable Monitors-Form 2000-502 Pollutant(s): Nitrogen Oxides,Carbon Monoxide Monitoring Control System Parameters or Operating Parameters of a Process-Form 2000-503 Pollutant(s): • 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): Nitrogen Oxides,Carbon Monoxide and Volatile Organic Compounds Recordkeeping-Form 2000-507 Pollutant(s): Nitrogen Oxides,Carbon Monoxide and Volatile Organic Compounds Af Other(please describe)-Form 2000-508 Pollutant(s): Visible Emissions-Opacity 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February 1,2012 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: February 1,2012 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. • Operating Permit Application COMPLIANCE DEMONSTRATION BY PERIODIC EMISSION FORM 2000-502 Colorado Department of MONITORING USING PORTABLE MONITORS Rev 06-95 Public Health and Environment Air Pollution Control Division The use of a portable continuous emission monitor(CEM)may be acceptable as a compliance demonstration method. A monitoring plan shall contain the following information:the name and address of the source; the source facility identification code; a general description of the process and the control equipment; the pollutant or diluent being monitored;the manufacturer,model number, and serial number of each portable monitor; the operating principles of each portable monitor; and a schematic of the CEM system showing the sample acquisition point and the location of the monitors while sampling. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-102 4. Unit identification code: C-148 5. Pollutant(s)or diluent(s)being monitored: NOx,CO,and Ot 6.Name of manufacturer: Enerac 7.Model&serial number: 3000E/SN#3E001183 8. I Is this an existing system? xi Yes No 10. Type: In situ xi Extractive Dilution Other(specify) 11. Very briefly explain the measurement design concept of the monitor: State required portable monitoring is performed on a quarterly basis.Exhaust gas samples are measured with a portable probe and analyzer by extracting a small volume of gas from the stack near the discharge point and analyzing using the • portable unit.The Marla Compressor Facility conducts portable analyzer testing as per CDPHE's Portable Analyzer Monitoring Protocol of March 2006. 12. Backup system: Spare analyzers provided by the contractor. 13. Compliance shall be demonstrated: Daily Weekly Monthly Ai Other-Quarterly 14. Quality Assurance/Quality Control: A quality assurance/quality control plan for the portable monitor is attached for Division review. The plan is not attached,but will be submitted to the Division by QAQC procedures as specified by the portable monitor manufacturer and the test method will be followed and documented for each measurement ***** Any test value over the emission limit shall be reported as an excess emission. ***** Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-503 Colorado Department of MONITORING CONTROL SYSTEM PARAMETERS OR Rev 06-95 Public Health and Environment OPERATING PARAMETERS OF A PROCESS IIAir Pollution Control Division 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-102 4. Unit identification code: C-148 5. Pollutant(s)being monitored: Nitrogen Oxides and Carbon Monoxide 6. Name of manufacturer: Unknown 7. Model number: Unknown 8. Is this an existing system? VYes No 9. Res_nctl far iuturc usc 10. Describe the method of monitoring: The Air Fuel Ratio millivolt reading will be monitored and recorded monthly.During quarterly portable analyzer testing activities,the Air Fuel Ratio millivolt reading will also be monitored and recorded.Millivolt recordings are recorded on a facility logsheet and compared to manufacturer recommended operating conditions. 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. -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 The Mr Fuel Ratio millivolt reading and operating range will be maintained according to manufacturer's specifications. Specifications will be maintained onsite and available for review upon request. 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 • Air Fuel Ratio millivolt reading Monthly • Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-506 Colorado Department of Public Health and Environment FUEL SAMPLING AND ANALYSIS Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-102 4.Unit identification code: C-148 5. Pollutant being monitored: Nitrogen Oxides,Carbon 6.Fuel being sampled: Natural gas used to fuel the Monoxide and Volatile Organic Compounds compressor engine 7. List the ASTM or EPA fuel sample collecting and analyzing methods used: The BTU content of the natural gas used to fuel the engine will be verified using GPA 2261 analysis or an equivalent methodology 8. Is this an existing FSA system? J Yes No 9. Implementation Date: 10. Automated sampling J Manual sampling 11. Backup system? 12. Compliance shall be demonstrated: Daily - Weekly Monthly Al Other—specify Semi-annually 13. Quality Assurance/Quality Control: The FSA system certification is attached for Division review. • The FSA system is not certified,but the certification package was submitted to the Division on The FSA system certification will be submitted to the Division by the date shown in our monitoring/compliance plan. A Quality Assurance/Quality Control plan for the fuel sampling program is attached for Division review. The QA/QC plan is not attached,but will be submitted to the Division by DCP Midstream uses an internal analytical laboratory for fuel sampling and analysis.A database is utilized to track fuel composition.The operation of this database includes fuel system certification and quality assurance quality control. 14. Attach a schematic of the FSA system showing the sample acquisition point and the location of the machine that produces the daily,weekly,or monthly composite fuel sample. *****Any composite sample over the emission limit shall be reported as an excess emission. ***** • Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of BY RECORDKEEPING Rev 06-95 Public Health and Environment • 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-102 4. Unit identification code: C-148 5. Pollutant(s)being monitored:Nitrogen Oxides,Carbon 6. Material or parameter being monitored and recorded: Monoxide,Volatile Organic Compounds, Hazardous Air Calculation of engine emissions,engine fuel consumption, Pollutants engine hours of operation,air fuel ratio controller millivolt reading. Natural gas is the only fuel allowed to be combusted in the engine. 7. Method of monitoring and recording(see information on back of this page): DCP Midstream records and monitors facility-wide fuel consumption and fuel BTU content.DCP Midstream uses engine hours to determine the fuel consumption for each unit. Engine operating hours are used to calculate actual emissions for the monthly 12-month rolling totals and tracking report.The air fuel ratio controller millivolt is a visual reading that is recorded monthly and during portable analyzer monitoring events.Only natural gas is used as fuel for the engine, therefore,compliance with the 20%opacity limit is presumed. 8. List any EPA methods used: • 9. Is this an existing method of demonstrating 10. Start date: On-going compliance? No \I Yes 11. Backup system: 12 a. Data collection frequency: Daily Weekly i Monthly Batch(not to exceed monthly) Other-specify 12 b. Compliance shall be demonstrated: Daily Weekly h)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 Midstream currently conducts recordkeeping for the Marla Compressor Station.DCP Midstream uses a internal database spreadsheet to record monitoring data,calculate emissions and maintain a 12-month rolling total of pollutant emissions. 14. A proposed format for the compliance certification report and excess emission report is attached. DCP Midstream currently submits compliance certification reports and excess emissions reports to the Colorado Air Pollution Control for this facility as required.The format for these submittals can be found on previous submittals from DCP Midstream. • ***** 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. • Operating Pennit 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: Marla Compressor Station 2.Facility identification code:CO 1230243 3. Stack identification code: P-102 4.Unit Identification code: C-148 5.Pollutant(s)or Parameter(s)being monitored: Opacity of exhaust. 6. Description of the method of monitoring: Because natural gas fuel is the only fuel being used,compliance with the 20%opacity limit set forth by Condition 1.3 of Operating Permit 95OPWE020 and Condition 3 of Construction Permit 01WE0499 shall be presumed. • 7. Compliance shall be demonstrated: (Specify the frequency with which compliance will be demonstrated) • Operating Permit Application EMISSION UNIT HAZARDOUS AIR POLLUTANTS FORM 2000-600 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division alSEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code:P-102 4. Unit identification code: C-148 5. Unit material description:Natural Gas 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor references. Attached X :1ctuw:il=nassion. I)at,: i, for calendar\ear 19 Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name Quantity' Measurement Quantity Measurement Units Units 50-00-0 Formaldehyde 0.25 TPY 67-56-1 Methanol 0.08 TPY 75-07-0 Acetaldehyde 0.07 TPY 107-02-8 Acrolein ; .,. ..._ 0.07 TPY 71-43-2 Benzene 0.04 TPY 108-88-3 Toluene 0.01 TPY 1330-20-7 Xylene 0.00 l PY 100-41-4 Ethylbenzene 0.00 1 P 110-54-3 n-Hexane 0.00 TPY 540-84-1 224-TMP ;:.. :::::., 0.00 TPY r TPY IPY TPY TPY TPY • • TPY TPY TAY 1 TPY TPY • 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:Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-102 4. Unit identification code:C-148 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached X Air pollutant Actual Potential to emit Maximum allowable Quantity U TPY U TPY Particulates(TSP) 11'1 PM-10 0.48 TPY Nitrogen oxides 42.82 TPY 3.0 h 42.82 Volatile organic compounds . . 14.27 TPY 1.0 6 14.27 • Carbon monoxide 42.82 TPY 3M 6 42.82 Lead TPY Sulfur dioxide 0.03 TPY otal reduced sulfur TPY Reduced sulfur compounds TPY Hydrogen sulfide TPY Sulfuric Acid Mist • TPY • Fluorides TPY TPY TPY TPY TPY Units(U)should be entered as follows: =lb/hr 2—Ib/mmBTU 3=grains/dscf 4=lb/gallon 5=ppmdv 6=gram/HP-hour 7=1b/mmscf 8=other(specify) 9=other(specify) 10=other(specify) 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:Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-102 4.Unit identification code: C-148 5.Pollutant 6. Colorado Air Quality 7. 8. Limitation 9. Compliance Regulations State Status or Only IN OUT Construction Permit Number Nitrogen Oxides 01WE0499 42.8 tpy X Carbon Monoxide 01WE0499 42.8 tpy X VOC 01WE0499 14.3 tpy X Natural Gas Fuel Use 01WE0499 84.48 MMscf/yr X Consumption (Minor Mod April 2011) Opacity 01WE0499 20 percent X HAPs Operating Permit# Each individual HAP 8.0 tpy X 95OPWE020 and Total HAPs 20.0 tpy • 10.Other requirements(e.g.,malfunction reporting, special operating conditions from an State Only Compliance existing permit such as material usage,hours of operation,etc.) Status IN OUT Portable Monitoring X Engine Maintenance,Control of Emissions from Stationary Engines(NSCR and X AFRC) BTU Content of Natural Gas Verification X Air/Fuel Ratio Controller Recordkeeping X Operation and Maintenance Plan X Compliance Assurance Monitoring X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** • Operating Permit Application PERMIT SHIELD PROTECTION FORM 2000-605 Colorado Department of Public Health and Environment IDENTIFICATION Rev 06-95 Air Pollution Control Division • SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2.Facility identification code: CO 1230243 3. Specify Emission Source: P-102 4.Do not use 5. Pollutant, 6.Colorado Air Quality 7. Equipment, Regulations State or Only Process NA • 8.Other requirements(e.g.,malfunction reporting,special operating conditions State Only from an 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 aerating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 lorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE l.Facility name:Marla Compressor Station 2.Facility identification code:CO 1230243 3.Stack identification code:P-102 4.Unit identification code:C-148 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. X 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 Actions Deadline 1. 2. 3. Progress reports will be submitted: Start date: and every six(6)months thereafter • • Marla Compressor Station Title V Operating Permit Application Forms C-135/P-103 Waukesha 7042 GSI 123/0243/053 The Following Forms are Attached: 2000-200 2000-302 2000-400 2000-500 2000-502 2000-503 2000-506 2000-507 2000-508 2000-600 2000-601 • 2000-604 2000-605 2000-606 • • 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-103 3a.Construction Permit Number: 01 WE0500 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 C-135 2000-303 2000-304 2000-305 2000-306 2000-307 5. Stack identified on the plot plan required on Form 2000-101 J 6. Indicate by checking: This stack has an actual exhaust point. 1 palm ictcn ate entered=n Items -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;alt(feet) S. Inside dale ens Mouths(cheek one and coiuplete): 1 J Circular 4.17 (feet), itoctanalar length(fretL......width(bet) 9. Exhaust flow tie; Normal 1961 (Aet4M) Ma*rinont .(ACFM)'. Velocity, 1 8 PS): G*uktxd 'Stack Test. 30. exllausf,g� {t Htaa* ' l y5 (">) 11. Does Procc,m9dir9 aathientamoistne conceal Yes No J if"Yea",maiaararils ntidttue-+mom' Normal Petceat bhptimmtt, steel*,,:;..:_ 12. Bahasa'.gas ,. 'i'Up Down Sor zonal# • 13. Inaba stackegtilpledwitlt a tsid$(or anyobstr ct om to the free flow of the exhaustgases'f*om thestack7 Yes 4No *****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. • • Operating Permit Application INTERNAL COMBUSTION ENGINE OPERATION FORM 2000-302 Colorado Department of Rev 06-95 Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-103 4. Engine(Unit)code: C-135 4a.Date first placed in service: 09/25/2001 Date last modified: 05/03/2010 5. Engine use: Powering a natural gas compressor 6. Engine Features: 2-Cycle J 4-Cycle J Spark-ignition Diesel J Standard rich burn Standard lean bum J Air/fuel ratio controller i Turbocharger Low-NOx design Other(Describe): 7. Emission controls: No J Yes-Attach control device form J Non-Selective catalytic reduction Three-way catalyst Selective catalytic reduction Ammonia injected Ni Oxidation catalyst Other: 8. Manufacturer:Waukesha 9. Model No: L-7042 GSI S/N: 317310 10. Max Fuel Design Rate: 11.57 mmBTU/hr 11. Horsepower Max Design: Site: 1478 12. Heat Rate: 7,830 BTU/HP-hr 13. Operating Temp: Min. Max. °F • 14. Fuels: Primary Fuel Backup Fuel#1 Fuel Type: Natural Gas Heating Value BTU/SCF 1200 Sulfur Content (Wt.%) 0(0%112S) Ash Content, (Wt.%) N/A Moisture Content (%) 0 Maximum Hourly Consumption(Ft3,gal) 9644 scf/hr Maximum Yearly Consumption(Ft3,gal) 84.48MMscf/yr NOTE: Data entry below is NOT OPTIONAL if parametric monitoring is used for compliance demonstration IS.OPaationalPSten ITB��S�a) � a �v � 0. � '- ? ¢�� Speed 5"` ry i Ped t. S ?!.. / ; a Fat Art' 2$ Ir r);i*Temp, Air alidiue11t9*nS �' _ �) �'� � -IFµ y'"'✓i �Y '. Watt ate patio. FuelEegulator setting l ***** 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. ***** 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 I.Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-103 4. Unit identification code: C-135 5. Control device code: C-103 6. Manufacturer and model number:Johnson Mathey 7. Date placed in service: 09/25/2001 Date of last modification: 8. Describe the device being used. Non-Selective Catalytic Reduction 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 Outlet pollutant Control Efficiency t concentration (%) , s prfacf Mori' gr/acf ppmv • X NOx 2.0 g hp-hr VOC c 1.0 g/hp-hr rt, a F } CO 3.0 g/hp-hr 10.Discuss how the coila0ed:tt Y411 b411,140,,,e for nor dMpont f N l ry k, nos .. ;� �hilrn l-8'v,e_.t-o h '`t€,, the 1!111{!Wi . lw , fli,r:iint::.44141,04144144,14, 1$,44ThlithiS device -�..� t as 0:4T''g0:0#}�y�w' �l Wit'# ('(q��y�� Y t r y,yOv6YRM *It k t Y ' W IDrrirr# h i x k will tea .. 1" +110; d,An I Sithero is icii f tit NOTE: COMPLETION OF INFORMATION IN SHADED AREA OF THIS FORM IS OPTIONAL Operating Permit Application COMPLIANCE CERTIFICATION-MONITORING AND REPORTING FORM 2000-500 Colorado Department of DESCRIPTION OF METHODS USED Rev 06-95 Public Health and Environment FOR DETERMINING COMPLIANCE Air Pollution Control Division 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 Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-103 4. Unit identification code: C-135 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): J Periodic Emission Monitoring Using Portable Monitors-Form 2000-502 Pollutant(s): Nitrogen Oxides,Carbon Monoxide Quarterly monitoring Monitoring Control System Parameters or Operating Parameters of a Process-Form 2000-503 Pollutant(s): • 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): Nitrogen Oxides,Carbon Monoxide and Volatile Organic Compounds Recordkeeping-Form 2000-507 Pollutant(s): Nitrogen Oxides,Carbon Monoxide and Volatile Organic Compounds J Other(please describe)-Form 2000-508 Pollutant(s): Visible Emissions—Opacity 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February 1,2012 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: February 1,2012 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. Operating Pennit Application COMPLIANCE DEMONSTRATION BY PERIODIC EMISSION FORM 2000-502 Colorado Department of MONITORING USING PORTABLE MONITORS Rev 06-95 Public Health and Environment Air Pollution Control Division The use of a portable continuous emission monitor(CEM)may be acceptable as a compliance demonstration method. A monitoring plan shall contain the following information: the name and address of the source;the source facility identification code; a general description of the process and the control equipment; the pollutant or diluent being monitored;the manufacturer, model number, and serial number of each portable monitor;the operating principles of each portable monitor;and a schematic of the CEM system showing the sample acquisition point and the location of the monitors while sampling. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-103 4. Unit identification code: C-135 5. Pollutant(s) or diluent(s)being monitored: NOx,CO,and O2 6.Name of manufacturer: Enerac 7.Model&serial number:3000E/SN#3E001183E 8. Is this an existing system? 1 Yes No 10. Type: In situ 'I Extractive Dilution Other(specify) 11. Very briefly explain the measurement design concept of the monitor: State required portable monitoring is performed on a quarterly basis. Exhaust gas samples are measured with a portable probe and analyzer by extracting a small volume of gas from the stack near the discharge point and analyzing using the portable unit.The Marla Compressor Facility conducts portable analyzer testing as per CDPHE's Portable Analyzer Monitoring Protocol of March 2006. 12. Backup system: Spare analyzers provided by the contractor. 13. Compliance shall be demonstrated: Daily Weekly Monthly 4 Other-Quarterly 14. Quality Assurance/Quality Control: A quality assurance/quality control plan for the portable monitor is attached for Division review. The plan is not attached,but will be submitted to the Division by QAQC procedures as specified by the portable monitor manufacturer and the test method will be followed and documented for each measurement *****Any test value over the emission limit shall be reported as an excess emission. ***** Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-503 Colorado Department of MONITORING CONTROL SYSTEM PARAMETERS OR Rev 06-95 Public Health and Environment OPERATING PARAMETERS OF A PROCESS • Air Pollution Control Division 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-103 4. Unit identification code: C-135 5. Pollutant(s)being monitored: Nitrogen Oxides and Carbon Monoxide 6. Name of manufacturer: Unknown 7. Model number: Unknown 8. Is this an existing system? VYes No 9. Re`:crV cd lot-future use 10. Describe the method of monitoring: The Air Fuel Ratio millivolt reading will be monitored and recorded monthly.During quarterly portable analyzer testing activities,the Air Fuel Ratio millivolt reading will also be monitored and recorded.Millivolt recordings are recorded on a facility logsheet and compared to manufacturer recommended operating conditions. 11. Backup system: 0 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 - . The Air Fuel Ratio millivolt reading and operating range will be maintained according to manufacturer's specifications. Specifications will be maintained onsite and available for review upon request. 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 . Air Fuel Ratio millivolt reading Monthly • Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-506 Colorado Department of Public Health and Environment FUEL SAMPLING AND ANALYSIS Rcv 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-103 4. Unit identification code: C-135 5. Pollutant being monitored: Nitrogen Oxides,Carbon 6. Fuel being sampled: Natural gas used to fuel the Monoxide and Volatile Organic Compounds compressor engine 7. List the ASTM or EPA fuel sample collecting and analyzing methods used: The BTU content of the natural gas used to fuel the engine will be verified using GPA 2261 analysis or an equivalent methodology 8. Is this an existing FSA system? J Yes No 9. Implementation Date: 10. Automated sampling J Manual sampling 11. Backup system? 12. Compliance shall be demonstrated: Daily Weekly Monthly J Other—specify Semi-annually 13. Quality Assurance/Quality Control: The FSA system certification is attached for Division review. • The FSA system is not certified,but the certification package was submitted to the Division on The FSA system certification will be submitted to the Division by the date shown in our monitoring/compliance plan. A Quality Assurance/Quality Control plan for the fuel sampling program is attached for Division review. The QA/QC plan is not attached,but will be submitted to the Division by DCP Midstream uses an internal analytical laboratory for fuel sampling and analysis. A database is utilized to track fuel composition.The operation of this database includes fuel system certification and quality assurance quality control. 14. Attach a schematic of the FSA system showing the sample acquisition point and the location of the machine that produces the daily, weekly,or monthly composite fuel sample. ***** Any composite sample over the emission limit shall be reported as an excess emission. ***** I Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of BY RECORDKEEPING Rev 06-95 Public Health and Environment • 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-103 4. Unit identification code: C-135 5. Pollutant(s)being monitored:Nitrogen Oxides,Carbon 6. Material or parameter being monitored and recorded: Monoxide,Volatile Organic Compounds,Hazardous Air Calculation of engine emissions,engine fuel consumption, Pollutants engine hours of operation,air fuel ratio controller millivolt reading. Natural gas is the only fuel allowed to be combusted in the engine. 7. Method of monitoring and recording(see information on back of this page): DCP Midstream records and monitors facility-wide fuel consumption and fuel BTU content.DCP Midstream uses engine hours to determine the fuel consumption for each unit.Engine operating hours are used to calculate actual emissions for the monthly 12-month rolling totals and tracking report.The air fuel ratio controller millivolt is a visual reading that is recorded monthly and during portable analyzer monitoring events.Only natural gas is used as fuel for the engine, therefore,compliance with the 20%opacity limit is presumed. 8. List any EPA methods used: • 9. Is this an existing method of demonstrating 10. Start date: On-going compliance? No J Yes 11. Backup system: 12 a. Data collection frequency: Daily Weekly 'Monthly Batch(not to exceed monthly) Other-specify 12 b. Compliance shall be demonstrated: Daily Weekly 'IMonthly 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 Midstream currently conducts recordkeeping for the Marla Compressor Station.DCP Midstream uses a internal database spreadsheet to record monitoring data,calculate emissions and maintain a 12-month rolling total of pollutant emissions. 14. A proposed format for the compliance certification report and excess emission report is attached. DCP Midstream currently submits compliance certification reports and excess emissions reports to the Colorado Air Pollution Control for this facility as required.The format for these submittals can be found on previous submittals from DCP Midstream. ***** 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. 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-103 4. Unit Identification code: C-135 5.Pollutant(s)or Parameter(s)being monitored: Opacity of exhaust. 6. Description of the method of monitoring: Because natural gas fuel is the only fuel being used,compliance with the 20%opacity limit set forth by Condition 1.3 of Operating Permit 95 OPWE020 and Condition 3 of Construction Permit 01WE0500 shall be presumed. • 7. Compliance shall be demonstrated: (Specify the frequency with which compliance will be demonstrated) • Operating Permit Application 2000-600 EMISSION UNIT HAZARDOUS AIR POLLUTANTS FORM Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE I. Facility name:Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code: P-103 4. Unit identification code:C-135 5. Unit material description:Natural Gas 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor refenfnces. Attached X A,:tuilll Laiendarycar !`1 Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name Quantity. .Measurement Quantity Measurement : . Units Units 50-00-0 Formaldehyde 0.25 TPY 67-56-1 Methanol 0.08 TPY 75-07-0 Acetaldehyde 0.07 TPY 107-02-8 Acrolein , . -.- , 0.07 TPY 71-43-2 Benzene -•. 0.04 TPY III108-88-3 Toluene 0.01 TPY 1330-20-7 Xylene 0.00 TPY 100-41-4 Ethylbenzene 0.00 1P Y 110-54-3 n-Hexane 0.00 TPY 540-84-1 224-TMP 0.00 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. Operating Permit Application UNIT CRITERIA AIR POLLUTANTS FORM 2000-601 Colorado Department of Public Health and EnvEMISSIONironment (l9 94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code:P-103 4. Unit identification code:C-135 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached X Air pollutant Actual Potential to emit Maximum allowable Quantity U . .TPY U TPY Particulates(TSP) TPY PM-10 . . 0.03 TPY Nitrogen oxides 28.54 TPY 2.0 6 28.54 Volatile organic compounds • 14.27 TPY 1.0 6 14.27 Carbon monoxide 42.82 TPY 3.0 6 42.82 Lead , : .... TPY Sulfur dioxide 0.004 FPY Illkotal reduced sulfur • I PY Reduced sulfur compounds FPY Hydrogen sulfide TPY . Sulfuric Acid Mist TPY Fluorides TPY TPY I PY • TPY TPY Units(U)should be entered as follows: t=lb/hr 2=Ib/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) • Operating Pennit Application FORM 2000-604 APPLICABLE REQUIREMENTS AND 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-103 4. Unit identification code: C-135 5. Pollutant 6. Colorado Air Quality 7. 8. Limitation 9. Compliance Regulations State Status or Only IN OUT Construction Permit Number Nitrogen Oxides 01WE0500 28.54 tpy X Carbon Monoxide 01 WE0500 42.82 tpy X VOC 01 WE0500 14.27 tpy X Natural Gas Fuel Use 01 WE0500 84.48 MMscf/yr X Consumption (April 2011 Minor Mod) Opacity 01 WE0500 20 percent X HAPs Operating Permit# Each individual HAP 8.0 tpy X 95OPWE020 and Total HAPs 20.0 tpy • 10. Other requirements(e.g.,malfunction reporting,special operating conditions from an State Only Compliance existing permit such as material usage,hours of operation,etc.) Status IN OW Portable Monitoring X Engine Maintenance,Control of Emissions from Stationary Engines(NSCR and X AFRC) BTU Content of Natural Gas Verification X Air/Fuel Ratio Controller Recordkeeping X Operation and Maintenance Plan X Compliance Assurance Monitoring X ****USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** • Operating Pennit Application PERMIT SHIELD PROTECTION FORM 2000-605 Colorado Department of Public Health and Environment IDENTIFICATION Rev 06-95 Air Pollution Control Division • SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Maria Compressor Station 2. Facility identification code: CO 1230243 3. Specify Emission Source: P-103 4.Do not use 5. Pollutant, 6. Colorado Air Quality 7. Equipment, Regulations State or Only Process NA • 8. Other requirements(e.g.,malfunction reporting,special operating conditions State Only from an 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 'aerating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 lorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1.Facility name:Marla Compressor Station 2.Facility identification code:CO 1230243 3.Stack identification code:P-103 4.Unit identification code:C-135 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. X 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 Actions Deadline I. • 2. 3. Progress reports will be submitted: Start date: and every six(6)months thereafter . • Marla Compressor Station Title V Operating Permit Application Forms C-151/P-104 Waukesha 7042 GSI 123/0243/054 The Following Forms are Attached: 2000-200 2000-302 2000-400 2000-500 2000-502 2000-503 2000-506 2000-507 2000-508 2000-600 2000-601 2000-604 • 2000-605 2000-606 • • 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-104 3a. Construction Permit Number: 01WE0501 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 C-151 2000-303 2000-304 2000-305 2000-306 2000-307 5. Stack identified on the plot plan required on Form 2000-101 xi 6. Indicate by checking: This stack has an actual exhaust point. The parameters me catered in I lcm7-13. 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. sebarge heisitrntye,lmad kvelc Jj(&et) 8- Iasi&dtarec .titelit4 t: ligei[ 8M r ): ' 4 Pritet0 Reclane ' . 1010 .. t ) t vol°043I 41114 -2_1.-11414P,Oklaktelaggla iiM1WYT 4 v�,,. 4 h . its b �t t,a .Yiv4. q. 4 e ` i!'� ' tI. 11 I9iies , 12 $ • "41* polo, at Y 13 r f �xalebe 'romet ,l t 5 s t *****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. • Operating Permit Application INTERNAL COMBUSTION ENGINE OPERATION FORM 2000-302 Colorado Department of Rev 06-95 Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-104 4. Engine(Unit)code: C-151 4a. Date first placed in service: prior to June 2005 Date last modified: 5. Engine use: Powering a natural gas compressor 6. Engine Features: 2-Cycle J 4-Cycle J Spark-ignition Diesel 1 Standard rich burn Standard lean burn I Air/fuel ratio controller J Turbocharger Low-NOx design Other(Describe): 7. Emission controls: No I Yes-Attach control device form J Non-Selective catalytic reduction Three-way catalyst Selective catalytic reduction Ammonia injected Ni Oxidation catalyst Other: 8. Manufacturer:Waukesha 9. Model No: L-7042 GSI S/N: C-12843/1 10. Max Fuel Design Rate: 11.57 mmBTU/hr 11. Horsepower Max Design: Site: 1478 12. Heat Rate: 7,830 BTU/HP-hr 13. Operating Temp: Min. Max. °F • 14.Fuels: Primary Fuel Backup Fuel#1 Fuel Type: Natural Gas Heating Value BTU/SCF 1200 Sulfur Content (Wt.%) 0(0% H2S) Ash Content, (Wt.%) N/A Moisture Content (%) 0 Maximum Hourly Consumption(Ft3,gal) 9644 scf/hr Maximum Yearly Consumption(Ft3,gal) 84.48MMscf/yr NOTE: Data entry below is NOT OPTIONAL if parametric monitoring is used for compliance demonstration 15.�3+ltls Low �, i r r �r, x i `: • lntaks',a' 'tento ti v.• , r z Ati+' `IF s '. ,'ff i tWi fii• ✓' _ ;4_ ,••••;-;,-; .',‘,t4:-.::',,E ****" 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. ***** 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-104 4. Unit identification code: C-151 5. Control device code: C-104 6. Manufacturer and model number:Johnson Mathey 7. Date placed in service: June 2005 Date of last modification: April 2011 8. Describe the device being used. Non-Selective Catalytic Reduction 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 ppihtptat ..,T40009.0 Outlet pollutant Control Efficiency . � concentration (%) gil a gr/acf ppmv • NOx "- r 1.0 g/hp-hr VOC 0.7 g/hp-hr CO 2.0 g/hp-hr 10.Discutt how the c9lledteti met ial wilt be, to a al439sgl. •-•\ OinforiliartieliOdOtaiii‘eitiskestilietilint*gtoot wb., [ Ali tl Ibs' 1etl a�!pA1'1:;;ribiliftiiiiftWalfte;tilitts;AlitS121crotittspecitagasjasmusiliairepuntigtbs dhevtas rt lee t . . t ti+e mwdeeSt it,md n>u aor YVh�ets> ► #� , • NOTE: COMPLETION OF INFORMATION IN SHADED AREA OF THIS FORM IS OPTIONAL 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-104 4. Unit identification code: C-151 5. Control device code: C-104 6. Manufacturer and model number: Johnson Mathey 7. Date placed in service: June 2005 Date of last modification: April 2011 8. Describe the device being used. Attu 'i a�Sia�=ram of thz tiv She➢1. Non-Selective Catalytic Reduction 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 Outlet pollutant Control Efficiency concentration capture concentration (%) efficiency (°fig) gr/acf: ppmv gr/acf ppmv • NOx 1.0 g/hp-hr VOC 0.7 g/hp-hr CO 2.0 g/hp-hr 10.Discuss how the collected material will be handled for reuse or disposal 11.Prepare a malfunction prevention and abatement plan forthis 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 seems,pleasure sensors,CEMs). d.An inspection schedule and items or conditions that will be inspected. I Where is this plan available for review? • NOTE: COMPLETION OF INFORMATION IN SHADED AREA OF THIS FORM IS OPTIONAL • Operating Permit Application COMPLIANCE CERTIFICATION-MONITORING AND REPORTING FORM 2000-500 Colorado Department of DESCRIPTION OF METHODS USED Rev 06-95 Public Health and Environment FOR DETERMINING COMPLIANCE Air Pollution Control Division 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 Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-104 4. Unit identification code: C-151 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): J Periodic Emission Monitoring Using Portable Monitors-Form 2000-502 Pollutant(s): Nitrogen Oxides,Carbon Monoxide quarterly monitoring Monitoring Control System Parameters or Operating Parameters of a Process-Form 2000-503 Pollutant(s): • 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): Nitrogen Oxides,Carbon Monoxide and Volatile Organic Compounds Recordkeeping-Form 2000-507 Pollutant(s): Nitrogen Oxides,Carbon Monoxide and Volatile Organic Compounds J Other(please describe)-Form 2000-508 Pollutant(s): Visible Emissions—Opacity 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February 1,2012 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: February 1,2012 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. • Operating Permit Application COMPLIANCE DEMONSTRATION BY PERIODIC EMISSION FORM 2000-502 Colorado Department of MONITORING USING PORTABLE MONITORS Rev 06-95 Public Health and Environment Air Pollution Control Division The use of a portable continuous emission monitor(CEM)may be acceptable as a compliance demonstration method. A monitoring plan shall contain the following information: the name and address of the source; the source facility identification code;a general description of the process and the control equipment; the pollutant or diluent being monitored;the manufacturer, model number,and serial number of each portable monitor;the operating principles of each portable monitor;and a schematic of the CEM system showing the sample acquisition point and the location of the monitors while sampling. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-104 4. Unit identification code: C-151 5. Pollutant(s)or diluent(s)being monitored: NOx,CO,and O2 6.Name of manufacturer: Enerac 7.Model&serial number:3000E/SN #3E001183E 8. Is this an existing system? Ai Yes No 10. Type: In situ 4 Extractive Dilution Other(specify) 11. Very briefly explain the measurement design concept of the monitor: State required portable monitoring is performed on a quarterly basis. Exhaust gas samples are measured with a portable probe and analyzer by extracting a small volume of gas from the stack near the discharge point and analyzing using the • portable unit.The Marla Compressor Facility conducts portable analyzer testing as per CDPHE's Portable Analyzer Monitoring Protocol of March 2006. 12. Backup system: Spare analyzers provided by the contractor. 13. Compliance shall be demonstrated: Daily Weekly Monthly 4 Other-Quarterly 14. Quality Assurance/Quality Control: A quality assurance/quality control plan for the portable monitor is attached for Division review. The plan is not attached,but will be submitted to the Division by QAQC procedures as specified by the portable monitor manufacturer and the test method will be followed and documented for each measurement ***** Any test value over the emission limit shall be reported as an excess emission. ***** Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-503 Colorado Department of MONITORING CONTROL SYSTEM PARAMETERS OR Rev 06-95 Public Health and Environment OPERATING PARAMETERS OF A PROCESS Air Pollution Control Division 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 I. Facility name:Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-104 4. Unit identification code: C-151 5. Pollutant(s)being monitored: Nitrogen Oxides and Carbon Monoxide 6. Name of manufacturer: Unknown 7. Model number: Unknown 8. Is this an existing system? - Yes No 9, Resew cd far Intuit: use 10. Describe the method of monitoring: The Air Fuel Ratio millivolt reading will be monitored and recorded monthly.During quarterly portable analyzer testing activities,the Air Fuel Ratio millivolt reading will also be monitored and recorded.Millivolt recordings are recorded on a facility logsheet and compared to manufacturer recommended operating conditions. 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. -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 - The Mr Fuel Ratio millivolt reading and operating range will be maintained according to manufacturer's specifications. Specifications will be maintained onsite and available for review upon request. 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 • Mr Fuel Ratio millivolt reading Monthly • Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-506 Colorado Department of Public Health and Environment FUEL SAMPLING AND ANALYSIS Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-104 4. Unit identification code: C-151 5. Pollutant being monitored: Nitrogen Oxides,Carbon 6. Fuel being sampled:Natural gas used to fuel the Monoxide and Volatile Organic Compounds compressor engine 7. List the ASTM or EPA fuel sample collecting and analyzing methods used: The BTU content of the natural gas used to fuel the engine will be verified using GPA 2261 analysis or an equivalent methodology 8. Is this an existing FSA system? J Yes No 9. Implementation Date: 10. Automated sampling 81 Manual sampling 11. Backup system? 12. Compliance shall be demonstrated: Daily Weekly Monthly \/Other—specify Semi-annually 13. Quality Assurance/Quality Control: The FSA system certification is attached for Division review. • The FSA system is not certified,but the certification package was submitted to the Division on The FSA system certification will be submitted to the Division by the date shown in our monitoring/compliance plan. A Quality Assurance/Quality Control plan for the fuel sampling program is attached for Division review. The QA/QC plan is not attached,but will be submitted to the Division by DCP Midstream uses an internal analytical laboratory for fuel sampling and analysis.A database is utilized to track fuel composition.The operation of this database includes fuel system certification and quality assurance quality control. 14. Attach a schematic of the FSA system showing the sample acquisition point and the location of the machine that produces the daily, weekly,or monthly composite fuel sample. ***** Any composite sample over the emission limit shall be reported as an excess emission. ***** I Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of BY RECORDKEEPING Rev 06-95 Public Health and Environment 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:Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-104 4. Unit identification code: C-151 5. Pollutant(s)being monitored:Nitrogen Oxides,Carbon 6.Material or parameter being monitored and recorded: Monoxide,Volatile Organic Compounds, Hazardous Air Calculation of engine emissions,engine fuel consumption, Pollutants engine hours of operation,air fuel ratio controller millivolt reading. Natural gas is the only fuel allowed to be combusted in the engine. 7. Method of monitoring and recording(see information on back of this page): DCP Midstream records and monitors facility-wide fuel consumption and fuel BTU content.DCP Midstream uses engine hours to determine the fuel consumption for each unit.Engine operating hours are used to calculate actual emissions for the monthly 12-month rolling totals and tracking report.The air fuel ratio controller millivolt is a visual reading that is recorded monthly and during portable analyzer monitoring events.Only natural gas is used as fuel for the engine, therefore,compliance with the 20%opacity limit is presumed. 8. List any EPA methods used: • 9. Is this an existing method of demonstrating 10. Start date: On-going compliance? No \/ Yes 11. Backup system: 12 a. Data collection frequency: Daily Weekly 'Monthly Batch(not to exceed monthly) Other-specify 12 b. Compliance shall be demonstrated: Daily Weekly 'IMonthly 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 Midstream currently conducts recordkeeping for the Marla Compressor Station.DCP Midstream uses a internal database spreadsheet to record monitoring data,calculate emissions and maintain a 12-month rolling total of pollutant emissions. 14. A proposed format for the compliance certification report and excess emission report is attached. DCP Midstream currently submits compliance certification reports and excess emissions reports to the Colorado Air Pollution Control for this facility as required. The format for these submittals can be found on previous submittals from DCP Midstream. ***** 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. • 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:Marla Compressor Station 2.Facility identification code: CO 1230243 3. Stack identification code: P-104 4. Unit Identification code: C-151 5.Pollutant(s)or Parameter(s)being monitored: Opacity of exhaust. 6. Description of the method of monitoring: Because natural gas fuel is the only fuel being used,compliance with the 20%opacity limit set forth by Condition 1.3 of Operating Permit 95 OPWE020 and Condition 3 of Construction Permit Ol WE0501 shall be presumed. • 7. Compliance shall be demonstrated: (Specify the frequency with which compliance will be demonstrated) • • Operating Permit Application EMISSION UNIT HAZARDOUS AIR POLLUTANTS FORM 2000-600 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-104 4. Unit identification code:C-151 5. Unit material description:Natural Gas 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor refertinces. Attached X ;Acttrl1_;mk.ton: Data i•.for calendar year It) Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name Quantity Arlo. Quantity Measurement Oita Units 50-00-0 Formaldehyde 0.25 TPY 67-56-1 Methanol 0.08 TPY 75-07-0 Acetaldehyde .: . 0.07 TPY 107-02-8 Acrolein 0.07 TPY 71-43-2 Benzene 0.04 TPY • 108-88-3 Toluene 0.01 TPY 1330-20-7 Xylene 2 0.00 TPY 100-41-4 Ethylbenzene 0.00 TPY 110-54-3 n-Ilcsane 0.00 TPY 540-84-1 224-'TMP • 0.00 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. • • 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:Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code: P-104 4. Unit identification code:C-151 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached X Air pollutant Actual Potential to emit Maximum allowable Quantity .Lr , TPY U TPY Particulates(TSP) PM-10 0.48 T In Nitrogen oxides 14.27 I PY 1.0 6 14.27 Volatile organic compounds 9.99 TPY 0.7 6 9.99 Carbon monoxide 28.54 TPY 2.0 6 28.54 Lead TPY Sulfur dioxide 0.03 TPY 'Dotal reduced sulfur TPY Reduced sulfur compounds TPY Hydrogen sulfide TPY Sulfuric Acid Mist . . .... TPY Fluorides TPY TPY TPY TPY TPY Units(U)should be entered as follows: =lb/hr 2=lb/mmBTU 3=grains dscf 4=lb/gallon 5=ppmdv 6=gram/HP-hour 7=11Vmmscf 8=other(specify) 9=other(specify) 10=other(specify) • Operating Permit Application FORM 2000-604 APPLICABLE REQUIREMENTS AND 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: Marla Compressor Station 2.Facility identification code: CO 1230243 3. Stack identification code: P-104 4.Unit identification code: C-151 5. Pollutant 6. Colorado Air Quality 7. 8. Limitation 9. Compliance Regulations State Status or Only IN OUT Construction Permit Number Nitrogen Oxides 01WE0501 14.27 tpy X (April 2011 Minor Mod) Carbon Monoxide 01WE0501 28.54 tpy X (April 2011 Minor Mod) VOC 01WE0501 9.99 tpy X (April 2011 Minor Mod) Natural Gas Fuel Use 01WE0501 84.48 MMscf/yr X Consumption (April 2011 Minor Mod) Opacity 01WE0501 20 percent X HAPs Operating Permit# Each individual HAP 8.0 tpy X • 95OPWE020 and Total HAPs 20.0 tpy 10.Other requirements(e.g.,malfunction reporting,special operating conditions from an State Only Compliance existing permit such as material usage,hours of operation,etc.) Status IN OUT Portable Monitoring X Engine Maintenance,Control of Emissions from Stationary Engines(NSCR and X AFRC) BTU Content of Natural Gas Verification X Air/Fuel Ratio Controller Recordkeeping X Operation and Maintenance Plan X Compliance Assurance Monitoring X ****USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** • Operating Permit Application PERMIT SHIELD PROTECTION FORM 2000-605 Colorado Department of Public Health and Environment IDENTIFICATION Rev 06-95 Air Pollution Control Division • SEE INSTRUCTIONS ON REVERSE SIDE 1.Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Specify Emission Source: P-104 4. Do not use 5.Pollutant, 6. Colorado Air Quality 7. Equipment, Regulations State or Only Process NA • 8.Other requirements(e.g., malfunction reporting, special operating conditions State Only from an 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 • �erating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 lorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE I.Facility name:Marla Compressor Station 2.Facility identification code:CO 1230243 3.Stack identification code:P-104 4.Unit identification code:C-151 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. X 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 Actions Deadline 1. • 2. 3. Progress reports will be submitted: Start date: and every six(6)months thereafter • • Marla Compressor Station Title V Operating Permit Application Forms C-166/P-109 Waukesha 7044 GSI 123/0243/059 The Following Forms are Attached: 2000-200 2000-302 2000-400 2000-500 2000-502 2000-503 2000-506 2000-507 2000-508 2000-600 2000-601 2000-604 • 2000-605 2000-606 ID • 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-109 3a. Construction Permit Number: 01WE0503 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 C-166 2000-303 2000-304 2000-305 2000-306 2000-307 5. Stack identified on the plot plan required on Form 2000-101 Ai 6. Indicate by checking: NI I This stack has an actual exhaust point. 1-he[wan-Kier.arc 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 thaUe rued level:Saco) 8. hide d imensida 'otdlet(die*one aid complete): .Cireelar lit( ) Recesistuar —10401(fCCt).,.,.:Wtdth(frct)`, • 9. &aust tow rats Normal 9662 (ACID _LOOS): Veloeitrl *05 (I?P4 stack Tat 10, E.chattst gas (�; 1 ( u.r l i - Doas',mce ' r*Attire t7 Yes No d If"Yes",,exhaust's k ' Mama_percent teens 12; gamest gas *soar.'. 41JP 13 ist(dsatatt' its s . attY•obsrt9tetictntod,efieeflows • t the aichaust.gases=fiauathi` tea" 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. Colorado• mg Permit Application INTERNAL COMBUSTION ENGINE OPERATION FORM 2000-302 Department of Rev 06-95 Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code: P-109 4. Engine(Unit)code:C-166 4a.Date first placed in service: 2001 Date last modified: 02/20/2009 5. Engine use:Powering a natural gas compressor 6. Engine Features: 2-Cycle d 4-Cycle Spark-ignition Diesel \I Standard rich burn Standard lean burn Air/fuel ratio controller Turbocharger Low-NOx design Other(Describe): 7.Emission controls: No of Yes- Attach control device form g Non-Selective catalytic reduction Three-way catalyst Selective catalytic reduction Ammonia injected J Oxidation catalyst Other: 8. Manufacturer:Waukesha 9. Model No:L-7044 GSI S/N:C-13857/1 10. Max Fuel Design Rate: 13.21 mmBTU/hr 11. Horsepower Max Design: Site: 1680 12. Heat Rate: 7,860 BTU/HP-hr 13. Operating Temp:Min. Max. 'E 40 14.Fuels: Primary Fuel Backup Fuel#1 Fuel Type: Natural Gas Heating Value BTU/SCF 1200 Sulfur Content (Wt.%) 0(0%H2S) Ash Content, (Wt.%) N/A Moisture Content (%) 0 Maximum Hourly Consumption(Ft3,gal) 11,004 scf/hr Maximum Yearly Consumption(Ft3,gal) 96.40 MMscf/yr NOTE: Data entry below is NOT OPTIONAL if parametric monitoring is used for compliance demonstration Operatiog� Lo'tr►: R E M RKS 15. 'Pa�mc4ers High Ignition Timing(degrees) Speed ....:... ....:.. Intake Air T Ali and Fuel:Manifold ndiaust�r 1 englgaure •Waste Gate: on, ' .. • d • Fuel'Regdlator 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. ***** Operating blic Health and Permit Application CONTROL EQUIPMENT-MISCELLANEOUS FORM 2000-400 Colorado Department of Pu Environment Rev 06-95 Air Pollution Control Division • SEE INSTRUCTIONS ON REVERSE SIDE l.Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-109 4. Unit identification code: C-166 5. Control device code: C-109 6. Manufacturer and model number: Johnson Mathey 7. Date placed in service: 2001 Date of last modification: 8. Describe the device being used. Non-Selective Catalytic Reduction 9. List the pollutants to be controlled by this equipment and the exl e for each pollutant on the table below. Documentation attached EITHER thepected outletcontro polfficiency concentration OR the control efficiency must be provided. Pollutant 1lli: SIO* Outlet pollutant Control Efficiency tomentsii:on, concentration (%) Y !fit' 1 �. : ^ gr/acf ppmv • NOx 2.0 g/hp-hr VOC CO 1.0 g/hp-hr 2.0 g/hp-hr 10.i)iacuas 1»w co loci d�xnl�be ttdled nr f sa gtrdiap wh i; 1 to be dsl t lLur ` a fincau t i+bt+t rdlo rt a of a,I aX fifes lekrW '„' b S v bk .1: tatw 1be _ attitdvtto$a brc Yn tl � aada dfet of _1* • NOTE: COMPLETION OF INFORMATION IN SHADED AREA OF THIS FORM IS OPTIONAL • Operating Permit Application COMPLIANCE CERTIFICATION-MONITORING AND REPORTING FORM 2000-500 Colorado Department of DESCRIPTION OF METHODS USED Rev 06-95 Public Health and Environment FOR DETERMINING COMPLIANCE Air Pollution Control Division 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 Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-109 4. Unit identification code: C-166 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): J Periodic Emission Monitoring Using Portable Monitors-Form 2000-502 Pollutant(s):Nitrogen Oxides,Carbon Monoxide quarterly monitoring Monitoring Control System Parameters or Operating Parameters of a Process-Form 2000-503 Pollutant(s): • 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): Nitrogen Oxides,Carbon Monoxide and Volatile Organic Compounds Recordkeeping-Form 2000-507 Pollutant(s): Nitrogen Oxides,Carbon Monoxide and Volatile Organic Compounds J Other(please describe)-Form 2000-508 Pollutant(s): Visible Emissions—Opacity 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February 1,2012 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: February 1,2012 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. Operating Permit Application COMPLIANCE DEMONSTRATION BY PERIODIC EMISSION FORM 2000-502 Colorado Department of MONITORING USING PORTABLE MONITORS Rev 06-95 Public Health and Environment Air Pollution Control Division The use of a portable continuous emission monitor(CEM)may be acceptable as a compliance demonstration method. A monitoring plan shall contain the following information: the name and address of the source; the source facility identification code; a general description of the process and the control equipment;the pollutant or diluent being monitored;the manufacturer,model number, and serial number of each portable monitor;the operating principles of each portable monitor; and a schematic of the CEM system showing the sample acquisition point and the location of the monitors while sampling. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-109 4. Unit identification code: C-166 5. Pollutant(s)or diluent(s)being monitored: NOx,CO,and Oz 6.Name of manufacturer: Enerac 7.Model&serial number: 3000E/SN#3E001183E 8. I Is this an existing system? Ai Yes No ■ 10. Type: In situ \Extractive Dilution Other(specify) 11. Very briefly explain the measurement design concept of the monitor: State required portable monitoring is performed on a quarterly basis.Exhaust gas samples are measured with a portable probe and analyzer by extracting a small volume of gas from the stack near the discharge point and analyzing using the • portable unit.The Marla Compressor Facility conducts portable analyzer testing as per CDPHE's Portable Analyzer Monitoring Protocol of March 2006. 12. Backup system: Spare analyzers provided by the contractor. 13. Compliance shall be demonstrated: Daily Weekly Monthly J Other-Quarterly 14. Quality Assurance/Quality Control: A quality assurance/quality control plan for the portable monitor is attached for Division review. The plan is not attached,but will be submitted to the Division by QAQC procedures as specified by the portable monitor manufacturer and the test method will be followed and documented for each measurement ***** Any test value over the emission limit shall be reported as an excess emission. ***** Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-503 Colorado Department of MONITORING CONTROL SYSTEM PARAMETERS OR Rev 06-95 Public Health and Environment OPERATING PARAMETERS OF A PROCESS • Air Pollution Control Division 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-109 4. Unit identification code: C-166 5. Pollutant(s)being monitored: Nitrogen Oxides and Carbon Monoxide 6. Name of manufacturer: Unknown 7. Model number: Unknown 8. Is this an existing system? VYes No 9. Reserccd for future use 10. Describe the method of monitoring: The Air Fuel Ratio millivolt reading will be monitored and recorded monthly. During quarterly portable analyzer testing activities,the Air Fuel Ratio millivolt reading will also be monitored and recorded.Millivolt recordings are recorded on a facility logsheet and compared to manufacturer recommended operating conditions. 11. Backup system: 0 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 - . The Air Fuel Ratio millivolt reading and operating range will be maintained according to manufacturer's specifications. Specifications will be maintained onsite and available for review upon request. 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 • Air Fuel Ratio millivolt reading Monthly • Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-506 Colorado Department of Public Health and Environment FUEL SAMPLING AND ANALYSIS Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-109 4. Unit identification code: C-166 5. Pollutant being monitored: Nitrogen Oxides,Carbon 6.Fuel being sampled: Natural gas used to fuel the Monoxide and Volatile Organic Compounds compressor engine 7. List the ASTM or EPA fuel sample collecting and analyzing methods used: The BTU content of the natural gas used to fuel the engine will be verified using GPA 2261 analysis or an equivalent methodology 8. Is this an existing FSA system? 'Yes No 9. Implementation Date: 10. Automated sampling i Manual sampling 11. Backup system? 12. Compliance shall be demonstrated: Daily Weekly _.Monthly J Other—specify Semi-annually 13. Quality Assurance/Quality Control: The FSA system certification is attached for Division review. • The FSA system is not certified,but the certification package was submitted to the Division on The FSA system certification will be submitted to the Division by the date shown in our monitoring/compliance plan. A Quality Assurance/Quality Control plan for the fuel sampling program is attached for Division review. The QA/QC plan is not attached,but will be submitted to the Division by DCP Midstream uses an internal analytical laboratory for fuel sampling and analysis.A database is utilized to track fuel composition.The operation of this database includes fuel system certification and quality assurance quality control. 14. Attach a schematic of the FSA system showing the sample acquisition point and the location of the machine that produces the daily,weekly,or monthly composite fuel sample. ***** Any composite sample over the emission limit shall be reported as an excess emission. ***** • Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of BY RECORDKEEPING Rev 06-95 Public Health and Environment 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:Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-109 4. Unit identification code: C-166 5.Pollutant(s)being monitored:Nitrogen Oxides,Carbon 6. Material or parameter being monitored and recorded: Monoxide,Volatile Organic Compounds, Hazardous Mr Calculation of engine emissions,engine fuel consumption, Pollutants engine hours of operation,air fuel ratio controller millivolt reading. Natural gas is the only fuel allowed to be combusted in the engine. 7. Method of monitoring and recording(see information on back of this page): DCP Midstream records and monitors facility-wide fuel consumption and fuel BTU content.DCP Midstream uses engine hours to determine the fuel consumption for each unit.Engine operating hours are used to calculate actual emissions for the monthly 12-month rolling totals and tracking report.The air fuel ratio controller millivolt is a visual reading that is recorded monthly and during portable analyzer monitoring events.Only natural gas is used as fuel for the engine, therefore,compliance with the 20%opacity limit is presumed. 8. List any EPA methods used: • 9. Is this an existing method of demonstrating 10. Start date: On-going compliance? No J Yes 11. Backup system: 12 a. Data collection frequency: Daily Weekly -4 Monthly Batch(not to exceed monthly) Other-specify 12 b. Compliance shall be demonstrated: Daily Weekly iMonthly 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 Midstream currently conducts recordkeeping for the Marla Compressor Station.DCP Midstream uses a internal database spreadsheet to record monitoring data,calculate emissions and maintain a 12-month rolling total of pollutant emissions. 14. A proposed format for the compliance certification report and excess emission report is attached. DCP Midstream currently submits compliance certification reports and excess emissions reports to the Colorado Mr Pollution Control for this facility as required.The format for these submittals can be found on previous submittals from DCP Midstream. ***** 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. • 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-109 4.Unit Identification code: C-166 5. Pollutant(s)or Parameter(s)being monitored: Opacity of exhaust. 6.Description of the method of monitoring: Because natural gas fuel is the only fuel being used,compliance with the 20%opacity limit set forth by Condition 1.3 of Operating Permit 95 OPWE020 and Condition 3 of Construction Permit 01WE0503 shall be presumed. • 7. Compliance shall be demonstrated: (Specify the frequency with which compliance will be demonstrated) I Operating Permit Application 2000-600 EMISSION UNIT HAZARDOUS AIR POLLUTANTS FORM Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE I. Facility name: Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code: P-109 4. Unit identification code: C-166 5. Unit material description: Natural Gas 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor referinces. Attached X Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name Quantity Meastnement Quantity Measurement Units Units 50-00-0 Formaldehyde 0.28 TPY 67-56-1 Methanol 0.09 TPY 75-07-0 Acetaldehyde 0.08 TPY 107-02-8 Acrolein 0.08 TPY • 71-43-2 Benzene 0.05 TPY • 108-88-3 Toluene 0.02 TPY 1330-20-7 Xylene 0.01 TPY 100-41-4 Ethylbenzene r,w 0.00 TPY 110-54-3 n-Hexane 0.00 TPY 540-84-1 224-TMP 0.00 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. Operating Permit Application SI 1111 Colorado Department of Public Health and EnvironmentEMI S ON UNIT CRITERIA AIR POLLUTANTS FORM 2000-601(19-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code: P-109 4. Unit identification code:C-166 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached X Air pollutant Acted• . Potential to emit Maximum allowable Quantity Y1. ; TPY U TPY •Particulates(TSP) TPY PM-10 • 0.55 TPY ...: Nitrogen oxides 32.44 TPY 2.0 6 32.44 Volatile organic compounds 16.22 TPY 1.0 6 16.22 Carbon monoxide 32.44 TPY 2.0 6 32.44 Lead TPY Sulfur dioxide 0.03 TPY • •otal reduced sulfur TPY • Reduced sulfur compounds TPY Hydrogen sulfide TPY Sulfuric Acid Mist TPY Fluorides TPY TPY TPY TPY TPY Units(U)should be entered as follows: =lb/hr 2—lb/mmBTU 3=grains/dsef 4=lb/gallon 5=ppmdv 6-gram/HP-hour 7=lb/mmscf • 8=other(specify) 9=other(specify) 10=other(specify) 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:Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-109 4. Unit identification code: C-166 5.Pollutant 6. Colorado Air Quality 7. 8. Limitation 9. Compliance Regulations State Status or Only IN OUT Construction Permit Number Nitrogen Oxides 01WE0503 32.44 tpy X Carbon Monoxide 01WE0503 32.44 tpy X VOC 01WE0503 16.22 tpy X Natural Gas Fuel Use 01WE0503 96.40 MMscf/yr X Consumption (April 2011 Minor Mod) Opacity 01WE0503 20 percent X HAPs Operating Permit# Each individual HAP 8.0 tpy X 95OPWE020 and Total HAPs 20.0 tpy • 10. Other requirements(e.g.,malfunction reporting, special operating conditions from an State Only Compliance existing permit such as material usage,hours of operation,etc.) Status IN OUT Portable Monitoring X Engine Maintenance,Control of Emissions from Stationary Engines(NSCR and X AFRC) BTU Content of Natural Gas Verification X Air/Fuel Ratio Controller Recordkeeping X Operation and Maintenance Plan X Compliance Assurance Monitoring X ****USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** • Operating Pennit Application PERMIT SHIELD PROTECTION FORM 2000-605 Colorado Department of Public Health and Environment IDENTIFICATION Rev 06-95 Air Pollution Control Division • SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Marla Compressor Station 2. Facility identification code: CO 1230243 3. Specify Emission Source: P-109 4. Do not use 5.Pollutant, 6. Colorado Air Quality 7. Equipment, Regulations State or Only Process NA S 8. Other requirements(e.g.,malfunction reporting, special operating conditions State Only from an 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 • Ak crating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 orado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE l.Facility name:Marla Compressor Station 2.Facility identification code:CO 1230243 3.Stack identification code:P-109 4.Unit identification code:C-166 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. X 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 Actions Deadline 1. • 2. 3. Progress reports will be submitted: Start date: and every six(6)months thereafter • • Marla Compressor Station Title V Operating Permit Application Forms C-174/P-110 Waukesha 7044 GSI 123/0243/060 The Following Forms are Attached: 2000-200 2000-302 2000-400 2000-500 2000-502 2000-503 2000-506 2000-507 2000-508 2000-600 2000-601 2000-604 • 2000-605 2000-606 • 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 I. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-110 3a.Construction Permit Number:01WE0504 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 C-174 2000-303 2000-304 2000-305 2000-306 2000-307 5. Stack identified on the plot plan required on Form 2000-101 \I 6. Indicate by checking: J I This stack has an actual exhaust point. 1 he 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 4L(fest). . _ $: kink dioa>nensions at outlet(cbeC;isne.;aed °t): . . Cut tiler 1:.0 (feet) Rectangular length(feet) width(feet) Exhaust flow rte. Nermsl 9662 (ACFM) MaXimum (ACFM) Vek icity 205 (FPS), 4"Caiculated StackTest 10.1._ Exhaust,gas ten pe*ture(normal) 1152 11. Does process modify ambient:air 'ma**eontent7 Yea. No J If*Yes",exhaust gas moil to content: 1." Normal patent ..Maxim pates c. I2� Exhaust gas discIr direction: -Up Down Hot-1=0W' :. 13. Is this itackoquisogd with a rainb*cr any obstruct tp t o(' the exhaust gases.fsi to stack? at J: s yt t • *****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. . Operating Permit Application INTERNAL COMBUSTION ENGINE OPERATION FORM 2000-302 Colorado Department of Rev 06-95 Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-110 4. Engine(Unit)code: C-174 4a.Date first placed in service: 2001 Date last modified: 11/25/2008 5. Engine use: Powering a natural gas compressor 6. Engine Features: 2-Cycle J 4-Cycle J Spark-ignition Diesel 1 Standard rich burn Standard lean burn 1 Air/fuel ratio controller 1 Turbocharger Low-NOx design Other(Describe): 7. Emission controls: No Ai Yes-Attach control device form J Non-Selective catalytic reduction Three-way catalyst Selective catalytic reduction Ammonia injected 1 Oxidation catalyst Other: 8. Manufacturer: Waukesha 9. Model No: L-7044 GSI S/N: C-13848/1 10. Max Fuel Design Rate: 13.21 mmBTU/hr 11. Horsepower Max Design: Site: 1680 12. Heat Rate: 7,860 BTU/HP-hr 13. Operating Temp: Min. Max. • 14. Fuels: Primary Fuel Backup Fuel#1 Fuel Type: Natural Gas Heating Value BTU/SCF 1200 Sulfur Content (Wt.%) 0(0% H2S) Ash Content, (Wt.%) N/A Moisture Content (%) 0 Maximum Hourly Consumption(Ft3,gal) 11,004 sef/hr Maximum Yearly Consumption(Ft3,gal) 96.4 MMscf/yr NOTE: Data entry below is NOT OPTIONAL if parametric monitoring is used for compliance demonstration 15.OperationaLPaz elers Lo* N Igmtid i Timhsg I�} . a 7 ; , ,w � tr v + . >t .SpCedfItrItfr littabratetM ANI FS( ' » rl t,�; Y1 1S - et400,Itietffl A w t Wiateet t � t 4 fi 4, C f Fu t ltvgu1a#ar Pen ;CPC C 5 1, b Y ***** 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. ***** 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: Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code: P-110 4. Unit iden fication code: C-174 5. Control device code: C-110 6. Manufacturer and model number: Johnson Mathey 7. Date placed in service: 2001 Date of last modification: 8. Describe the device being used. Non-Selective Catalytic Reduction 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 Inletpollacancatrotant . Emi 4fon Outlet pollutant Control p , concentration (%)Efficiency grtaef' PP"' gr/acf ppmv • NOx ., , : .., 2.0 g/hp-hr VOC 1.0 g/hp-hr 2.0 g/hp-hr CO 10.Discuss haw the collected materi l will be bandied for reuse 4x.,",'1 o• sa . . 11.i'tie 4a mid pLa6ottkis. p Its sD�ia ttbm tted t pl '-' 'his p1 6 h t to follo+vriug;', a ofthe i t+idaa* 1#3r"rifle,ceeptmsibk for in n . d t4pt�t b "' -' '. les It�s *t will' • ' itends rtgfi siddetialdetf ' , l:b� ftp.titi.e..‘0*.g.iiStiolit104,e :ow +dance• .0",� > ' pTh' .a be"pmeit d<smpeahtne a 0r2, ), 4.AR; condltioft dial w�be i led e wheie tkN plaa:sts +s i> , NOTE: COMPLETION OF INFORMATION IN SHADED AREA OF THIS FORM IS OPTIONAL • Operating Permit Application COMPLIANCE CERTIFICATION-MONITORING AND REPORTING FORM 2000-500 Colorado Department of DESCRIPTION OF METHODS USED Rev 06-95 Public Health and Environment FOR DETERMINING COMPLIANCE Air Pollution Control Division 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 Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-110 4. Unit identification code: C-174 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): J Periodic Emission Monitoring Using Portable Monitors-Form 2000-502 Pollutant(s): Nitrogen Oxides,Carbon Monoxide quarterly monitoring Monitoring Control System Parameters or Operating Parameters of a Process-Form 2000-503 Pollutant(s): • Monitoring Maintenance Procedures-Form 2000-504 Pollutant(s): Stack Testing-Form 2000-505 Pollutant(s): J Fuel Sampling and Analysis(FSA)-Form 2000-506 Pollutant(s): Nitrogen Oxides,Carbon Monoxide and Volatile Organic Compounds Recordkeeping-Form 2000-507 Pollutant(s): Nitrogen Oxides,Carbon Monoxide and Volatile Organic Compounds J Other(please describe)-Form 2000-508 Pollutant(s): Visible Emissions—Opacity 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February 1,2012 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: February 1,2012 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 Operating Pennit Application COMPLIANCE DEMONSTRATION BY FORM 2000-503 Colorado Department of MONITORING CONTROL SYSTEM PARAMETERS OR Rev 06-95 Public Health and Environment OPERATING PARAMETERS OF A PROCESS Air Pollution Control Division 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-110 4. Unit identification code: C-174 5. Pollutant(s)being monitored: Nitrogen Oxides and Carbon Monoxide 6. Name of manufacturer: Unknown 7. Model number: Unknown 8. Is this an existing system? 'IYes No 0. Rcscn cd for Iliturc use 10. Describe the method of monitoring: The Air Fuel Ratio millivolt reading will be monitored and recorded monthly.During quarterly portable analyzer testing activities,the Air Fuel Ratio millivolt reading will also be monitored and recorded.Millivolt recordings are recorded on a facility logsheet and compared to manufacturer recommended operating conditions. 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. -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 - The Air Fuel Ratio millivolt reading and operating range will be maintained according to manufacturer's specifications. Specifications will be maintained onsite and available for review upon request. 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 • Air Fuel Ratio millivolt reading Monthly • Operating Pennit Application COMPLIANCE DEMONSTRATION BY PERIODIC EMISSION FORM 2000-502 Colorado Department of MONITORING USING PORTABLE MONITORS Rev 06-95 Public Health and Environment Air Pollution Control Division The use of a portable continuous emission monitor(CEM)maybe acceptable as a compliance demonstration method. A monitoring plan shall contain the following information: the name and address of the source; the source facility identification code;a general description of the process and the control equipment;the pollutant or diluent being monitored; the manufacturer,model number,and serial number of each portable monitor; the operating principles of each portable monitor;and a schematic of the CEM system showing the sample acquisition point and the location of the monitors while sampling. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-110 4. Unit identification code: C-174 5. Pollutant(s)or diluent(s)being monitored: NOx,CO,and O2 6.Name of manufacturer: Enerac 7.Model&serial number: 3000E/SN#3E001183E 8. I Is this an existing system? Yes No 10. Type: In situ Extractive Dilution Other(specify) 11. Very briefly explain the measurement design concept of the monitor: State required portable monitoring is performed on a quarterly basis.Exhaust gas samples are measured with a portable probe and analyzer by extracting a small volume of gas from the stack near the discharge point and analyzing using the • portable unit.The Marla Compressor Facility conducts portable analyzer testing as per CDPHE's Portable Analyzer Monitoring Protocol of March 2006. 12. Backup system: Spare analyzers provided by the contractor. 13. Compliance shall be demonstrated: Daily Weekly Monthly 4 Other-Quarterly 14. Quality Assurance/Quality Control: A quality assurance/quality control plan for the portable monitor is attached for Division review. The plan is not attached,but will be submitted to the Division by QAQC procedures as specified by the portable monitor manufacturer and the test method will be followed and documented for each measurement ***** Any test value over the emission limit shall be reported as an excess emission. ***** • • Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-506 Colorado Department of Public Health and Environment FUEL SAMPLING AND ANALYSIS Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-110 4.Unit identification code: C-174 5. Pollutant being monitored: Nitrogen Oxides,Carbon 6.Fuel being sampled:Natural gas used to fuel the Monoxide and Volatile Organic Compounds compressor engine 7. List the ASTM or EPA fuel sample collecting and analyzing methods used: The BTU content of the natural gas used to fuel the engine will be verified using GPA 2261 analysis or an equivalent methodology 8. Is this an existing FSA system? J Yes No 9. Implementation Date: 10. Automated sampling J Manual sampling 11. Backup system? 12. Compliance shall be demonstrated: _ Daily Weekly Monthly J Other—specify Semi-annually 13. Quality Assurance/Quality Control: The FSA system certification is attached for Division review. • The FSA system is not certified,but the certification package was submitted to the Division on The FSA system certification will be submitted to the Division by the date shown in our monitoring/compliance plan. A Quality Assurance/Quality Control plan for the fuel sampling program is attached for Division review. The QA/QC plan is not attached,but will be submitted to the Division by DCP Midstream uses an internal analytical laboratory for fuel sampling and analysis.A database is utilized to track fuel composition. The operation of this database includes fuel system certification and quality assurance quality control. 14. Attach a schematic of the FSA system showing the sample acquisition point and the location of the machine that produces the daily, weekly,or monthly composite fuel sample. ***** Any composite sample over the emission limit shall be reported as an excess emission. ***** • Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of BY RECORDKEEPING Rev 06-95 Public Health and Environment IDAir Pollution Control Division Recordkeeping maybe 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-110 4. Unit identification code: C-174 5.Pollutant(s)being monitored: Nitrogen Oxides,Carbon 6. Material or parameter being monitored and recorded: Monoxide,Volatile Organic Compounds,Hazardous Air Calculation of engine emissions,engine fuel consumption, Pollutants engine hours of operation,air fuel ratio controller millivolt reading. Natural gas is the only fuel allowed to be combusted in the engine. 7. Method of monitoring and recording(see information on back of this page): DCP Midstream records and monitors facility-wide fuel consumption and fuel BTU content.DCP Midstream uses engine hours to determine the fuel consumption for each unit. Engine operating hours are used to calculate actual emissions for the monthly 12-month rolling totals and tracking report.The air fuel ratio controller millivolt is a visual reading that is recorded monthly and during portable analyzer monitoring events.Only natural gas is used as fuel for the engine, therefore,compliance with the 20%opacity limit is presumed. 8. List any EPA methods used: • 9. Is this an existing method of demonstrating 10. Start date: On-going compliance'? No J Yes 11. Backup system: 12 a. Data collection frequency: Daily Weekly 1 Monthly Batch(not to exceed monthly) Other-specify 12 b. Compliance shall be demonstrated: Daily Weekly lMonthly 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 Midstream currently conducts recordkeeping for the Marla Compressor Station. DCP Midstream uses a internal database spreadsheet to record monitoring data,calculate emissions and maintain a 12-month rolling total of pollutant emissions. 14. A proposed format for the compliance certification report and excess emission report is attached. DCP Midstream currently submits compliance certification reports and excess emissions reports to the Colorado Air Pollution Control for this facility as required.The format for these submittals can be found on previous submittals from DCP Midstream. ***** 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. • Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-508 Colorado Department of Public Health and EnvironmentBY OTHER METHODS Rev 06-95 Air Pollution Control Division 1. Facility Name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-110 4.Unit Identification code: C-174 5. Pollutant(s)or Parameter(s)being monitored: Opacity of exhaust. 6. Description of the method of monitoring: Because natural gas fuel is the only fuel being used,compliance with the 20%opacity limit set forth by Condition 1.3 of Operating Permit 95 OPWE020 and Condition 3 of Construction Permit 01WE0504 shall be presumed. 411, 7. Compliance shall be demonstrated: (Specify the frequency with which compliance will be demonstrated) • • Operating Permit Application EMISSION UNIT HAZARDOUS AIR POLLUTANTS FORM 2000-600 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-110 4. Unit identification code: C-174 5. Unit material description: Natural Gas 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor referinces. Attached X Pollutant CAS Common or Generic Actual emissions - Allowable OR Potential to emit Pollutant Name Quantity M8a6tll Quantity Measurement {J Units 50-00-0 Formaldehyde 018 TPY 67-56-1 Methanol 0.09 TPY 75-07-0 Acetaldehyde 0.08 TPY 107-02-8 AcroleinI 0.08 TPY • 71-43-2 Benzene 0.05 TPY 108-88-3 Toluene 0.02 TPY 1330-20-7 Xylene 0.01 TPY 100-41-4 Ethylbenzene 0.00 TPY 110-54-3 n-Hexane ,i '. 0.00 TPY 540-84-1 224-TMP 0.00 TPY TPY TPY r TPY TPY TPY TPY �.xK_ TPY 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 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE I. Facility name:Maria Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code:P-110 4. Unit identification code:C-174 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached X Air pollutant - Actual Potential to emit Maximum allowable t3►. !.1 . • TPY U TPY Particulates(TSP) ,: TPY PM-10 0.55 TPY Nitrogen oxides 32.44 TPY 2.0 6 32.44 Volatile organic compounds 1 16.22 I l'Y 1.9 6 16.22 :. ... Carbon monoxide "' 32.44 I PY 2.0 6 32.44 Lead TPY Sulfur dioxide 0.03 TPY otal reduced sulfur TPY Reduced sulfur compounds TPY Hydrogen sulfide TPY Sulfuric Acid Mist TPY Fluorides TPY TPY TPY TPY . f ,.: . TPA" Units(U)should be entered as follows: =Ib/hr 2=Ib/mmBTU 3=grains/dscf 4=lb/gallon 5=ppmdv 6—gram/HP-hour 7=Ilkinntscf 411 8=other(specify) 9=other(specify) 10=other(specify) 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: Marla Compressor Station 2.Facility identification code: CO 1230243 3. Stack identification code: P-110 4.Unit identification code: C-174 5.Pollutant 6.Colorado Air Quality 7. 8. Limitation 9. Compliance Regulations State Status or Only IN OUT Construction Permit Number Nitrogen Oxides 01WE0504 32.44 tpy X Carbon Monoxide 01WE0504 32.44 tpy X VOC 01WE0504 16.22 tpy X Natural Gas Fuel Use 01WE0504 96.40 MMscf/yr X Consumption (April 2011 Minor Mod) Opacity 01WE0504 20 percent X HAPs Operating Permit# Each individual HAP 8.0 tpy X 95OPWE020 and Total HAPs 20.0 tpy • 10. Other requirements(e.g.,malfunction reporting,special operating conditions from an State Only Compliance existing permit such as material usage,hours of operation,etc.) Status IN OUT Portable Monitoring X Engine Maintenance,Control of Emissions from Stationary Engines(NSCR and X AFRC) BTU Content of Natural Gas Verification X Air/Fuel Ratio Controller Recordkeeping X Operation and Maintenance Plan X Compliance Assurance Monitoring X ****USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** • Operating Permit Application PERMIT SHIELD PROTECTION FORM 2000-605 Colorado Department of Public Health and Environment IDENTIFICATION Rev 06-95 Air Pollution Control Division • SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Specify Emission Source: P-110 4.Do not use 5. Pollutant, 6. Colorado Air Quality 7. Equipment, Regulations State or Only Process NA • 8. Other requirements(e.g.,malfunction reporting,special operating conditions State Only from an 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 Illielating Pennit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 riomdo Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE l.Facility name:Marla Compressor Station 2.Facility identification code:CO 1230243 3.Stack identification code:P-110 4.Unit identification code:C-174 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. X 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 Actions Deadline 1. • 2. 3. Progress reports will be submitted: Start date: and every six(6)months thereafter • • Marla Compressor Station Title V Operating Permit Application Forms C-176/P-111 Waukesha 7044 GSI 123/0243/061 The Following Forms are Attached: 2000-200 2000-302 2000-400 2000-500 2000-502 2000-503 2000-506 2000-507 2000-508 2000-600 2000-601 • 2000-604 2000-605 2000-606 • • 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-111 3a. Construction Permit Number: 01WE0505 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 C-176 2000-303 2000-304 2000-305 2000-306 2000-307 5. Stack identified on the plot plan required on Form 2000-101 V 6. Indicate by checking: J I This stack has an actual exhaust point. l hcpar nicicN are entered in hem_7-1__ 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. trV6'gtewnt uk, feet); s l `u 'Fr'=' a** ,: Y ?-r`"1(a`s s r�+'i +tit I0 a aT. f A ) s k f :Y0-310413. _, hT t tai � Lkr �� r ' 9 r trier '�{{yy 1140001 �� ' M�Rl�� N x r 2 _ i I ..G `. t� � as ' yy ;y��.�y,, ... w *Sakti's " '�.e d x Gi c? dv,141'..1,,, 'sz d ti x y , the 3' f tia 369F��'r+>w t ! � r ° �r - r '-? °b4 1 '� *****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. • • Operating Permit Application INTERNAL COMBUSTION ENGINE OPERATION FORM 2000-302 Colorado Department of Rev 06-95 Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-111 4. Engine(Unit)code: C-176 4a. Date first placed in service: 02/01/2003 Date last modified: 02/18/2010 5. Engine use: Powering a natural gas compressor 6. Engine Features: 2-Cycle A/ 4-Cycle J Spark-ignition Diesel 1 Standard rich burn Standard lean bum Ai Air/fuel ratio controller Ai Turbocharger Low-NOx design Other(Describe): 7. Emission controls: No J Yes-Attach control device form J Non-Selective catalytic reduction Three-way catalyst Selective catalytic reduction Ammonia injected J Oxidation catalyst Other: S. Manufacturer: Waukesha 9. Model No: L-7044 GS! S/N: C-13858/1 10. Max Fuel Design Rate: 13.21 mmBTU/hr 11. Horsepower Max Design: Site: 1680 12. Heat Rate: 7,860 BTU/HP-hr 13. Operating Temp:Min. Max. °F • 14.Fuels: Primary Fuel Backup Fuel#1 Fuel Type: Natural Gas Heating Value BTU/SCF 1200 Sulfur Content (Wt.%) 0(0%H2S) Ash Content, (Wt.%) N/A Moisture Content (%) 0 Maximum Hourly Consumption(Ft3,gal) 11,004 scf/hr Maximum Yearly Consumption(Ft°,gal) 96.40 MMscf/yr NOTE: Data entry below is NOT OPTIONAL if parametric monitoring is used for compliance demonstration 15 > Lot ��ARn IgoltiOn Tti ltpg{drtgra0t) T cU f}) 4 41— ."� r */e t HE7F11998t } c': Y. R� Fuel ***** 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. ***** 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: is-Ill 4. Unit identification code:C-176 5. Control device code: C-111 6. Manufacturer and model number: Johnson Mathey 7. Date placed in service: 02/01/2003 Date of last modification: 8. Describe[he device being used. Non-Selective Catalytic Reduction 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 Inletpollutant tmi s Outlet pollutant Control Efficiency concentration (%) Bid '_ r t gr/acf ppmv NOx sp 2.0 g/hp-hr VOC 1.• 0 g/hp-hr s r CO 2.0 g/hp-hr 18 Aisc�abs uwthe.oAllati asl �l w N Yr� iidh¢ #ftnC matt Or bav e t t* thta . b is ttu ed die piam p il�R tbfi ltvt fiitioilii,i k t � a. t tndS 4$m4a*,by'tidC �. ...{,� .y��,4:4� yy�y��p��C�ty� V4 �ttl'E�d�r xr�. = K� ' cY� e.''F'I i rrp�.* �J ttl i 4V4 i i' X71 t: t 7.l .yk`- .�yr� i { 5 �('"i4"t" , E .ta- d p. - e ytkotheiga R p:: NOTE: COMPLETION OF INFORMATION IN SHADED AREA OF THIS FORM IS OPTIONAL • Operating Permit Application COMPLIANCE CERTIFICATION- MONITORING AND REPORTING FORM 2000400 Colorado Department of DESCRIPTION OF METHODS USED Rev 06-95 Public Health and Environment FOR DETERMINING COMPLIANCE Air Pollution Control Division 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 Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-111 4. Unit identification code: C-176 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 forms)to this form). Continuous Emission Monitoring(CEM)-Form 2000-501 Pollutant(s): I Periodic Emission Monitoring Using Portable Monitors-Form 2000-502 Pollutant(s): Nitrogen Oxides,Carbon Monoxide quarterly monitoring Monitoring Control System Parameters or Operating Parameters of a Process-Form 2000-503 Pollutant(s): • 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): Nitrogen Oxides,Carbon Monoxide and Volatile Organic Compounds Recordkeeping-Form 2000-507 Pollutant(s): Nitrogen Oxides,Carbon Monoxide and Volatile Organic Compounds J Other(please describe)-Form 2000-508 Pollutant(s): Visible Emissions—Opacity 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February 1,2012 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: February 1,2012 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. • Operating Permit Application COMPLIANCE DEMONSTRATION BY PERIODIC EMISSION FORM 2000-502 Colorado Department of MONITORING USING PORTABLE MONITORS Rev 06-95 Public Health and Environment Air Pollution Control Division The use of a portable continuous emission monitor(CEM)may be acceptable as a compliance demonstration method. A monitoring plan shall contain the following information: the name and address of the source; the source facility identification code;a general description of the process and the control equipment;the pollutant or diluent being monitored;the manufacturer,model number,and serial number of each portable monitor; the operating principles of each portable monitor;and a schematic of the CEM system showing the sample acquisition point and the location of the monitors while sampling. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-111 4. Unit identification code: C-176 5. Pollutant(s)or diluent(s)being monitored: NOx,CO,and Ot 6.Name of manufacturer: Enerac 7.Model& serial number:3000E/SN#3E001183E 8. I Is this an existing system? 4 Yes No 10. Type: In situ Extractive Dilution Other(specify) 11. Very briefly explain the measurement design concept of the monitor: State required portable monitoring is performed on a quarterly basis. Exhaust gas samples are measured with a portable probe and analyzer by extracting a small volume of gas from the stack near the discharge point and analyzing using the • portable unit.The Marla Compressor Facility conducts portable analyzer testing as per CDPHE's Portable Analyzer Monitoring Protocol of March 2006. 12. Backup system: Spare analyzers provided by the contractor. 13. Compliance shall be demonstrated: Daily Weekly Monthly 4 Other-Quarterly 14. Quality Assurance/Quality Control: A quality assurance/quality control plan for the portable monitor is attached for Division review. The plan is not attached,but will be submitted to the Division by QAQC procedures as specified by the portable monitor manufacturer and the test method will be followed and documented for each measurement ***** Any test value over the emission limit shall be reported as an excess emission. ***** • Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-503 Colorado Department of MONITORING CONTROL SYSTEM PARAMETERS OR Rev 06-95 Public Health and Environment OPERATING PARAMETERS OF A PROCESS • Air Pollution Control Division 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-111 4. Unit identification code: C-176 5. Pollutant(s)being monitored: Nitrogen Oxides and Carbon Monoxide 6. Name of manufacturer: Unknown 7. Model number: Unknown 8. Is this an existing system? -\./Yes No y. Rc _rccd fir future use 10. Describe the method of monitoring: The Air Fuel Ratio millivolt reading will be monitored and recorded monthly. During quarterly portable analyzer testing activities,the Air Fuel Ratio millivolt reading will also be monitored and recorded.Millivolt recordings are recorded on a facility logsheet and compared to manufacturer recommended operating conditions. 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. -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 - The Air Fuel Ratio millivolt reading and operating range will be maintained according to manufacturer's specifications. Specifications will be maintained onsite and available for review upon request. 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 • Air Fuel Ratio millivolt reading Monthly • Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-506 Colorado Department of Public Health and Environment FUEL SAMPLING AND ANALYSIS Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE I. Facility name: Marla Compressor Station 2.Facility identification code: CO 1230243 3. Stack identification code: P-111 4. Unit identification code: C-176 5.Pollutant being monitored: Nitrogen Oxides,Carbon 6. Fuel being sampled: Natural gas used to fuel the Monoxide and Volatile Organic Compounds compressor engine 7. List the ASTM or EPA fuel sample collecting and analyzing methods used: The BTU content of the natural gas used to fuel the engine will be verified using GPA 2261 analysis or an equivalent methodology 8. Is this an existing FSA system? 4 Yes No 9. Implementation Date: 10. Automated sampling 4 Manual sampling 11. Backup system? 12. Compliance shall be demonstrated: Daily Weekly Monthly 4 Other—specify Semi-annually 13. Quality Assurance/Quality Control: The FSA system certification is attached for Division review. • The FSA system is not certified,but the certification package was submitted to the Division on The FSA system certification will be submitted to the Division by the date shown in our monitoring/compliance plan. A Quality Assurance/Quality Control plan for the fuel sampling program is attached for Division review. The QA/QC plan is not attached,but will be submitted to the Division by DCP Midstream uses an internal analytical laboratory for fuel sampling and analysis.A database is utilized to track fuel composition.The operation of this database includes fuel system certification and quality assurance quality control. 14. Attach a schematic of the FSA system showing the sample acquisition point and the location of the machine that produces the daily,weekly, or monthly composite fuel sample. ***** Any composite sample over the emission limit shall be reported as an excess emission. ***** • Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of BY RECORDKEEPING Rev 06-95 Public Health and Environment 0 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 I. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-111 4. Unit identification code: C-176 5.Pollutant(s)being monitored: Nitrogen Oxides,Carbon 6. Material or parameter being monitored and recorded: Monoxide,Volatile Organic Compounds,Hazardous Air Calculation of engine emissions,engine fuel consumption, Pollutants engine hours of operation,air fuel ratio controller millivolt reading. Natural gas is the only fuel allowed to be combusted in the engine. 7. Method of monitoring and recording(see information on back of this page): DCP Midstream records and monitors facility-wide fuel consumption and fuel BTU content.DCP Midstream uses engine hours to determine the fuel consumption for each unit.Engine operating hours are used to calculate actual emissions for the monthly 12-month rolling totals and tracking report.The air fuel ratio controller millivolt is a visual reading that is recorded monthly and during portable analyzer monitoring events.Only natural gas is used as fuel for the engine, therefore,compliance with the 20%opacity limit is presumed. 8. List any EPA methods used: • 9. Is this an existing method of demonstrating 10. Start date: On-going compliance? No J Yes 11. Backup system: 12 a. Data collection frequency: Daily Weekly \I 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 Midstream currently conducts recordkeeping for the Marla Compressor Station.DCP Midstream uses a internal database spreadsheet to record monitoring data,calculate emissions and maintain a 12-month rolling total of pollutant emissions. 14. A proposed format for the compliance certification report and excess emission report is attached. DCP Midstream currently submits compliance certification reports and excess emissions reports to the Colorado Air Pollution Control for this facility as required.The format for these submittals can be found on previous submittals from DCP Midstream. 4. ****# 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. • Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-508 Colorado Department of Public Health and EnvironmentBY OTHER METHODS Rev 06-95 Air Pollution Control Division 1. Facility Name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-111 4. Unit Identification code: C-176 5. Pollutant(s)or Parameter(s)being monitored: Opacity of exhaust. 6.Description of the method of monitoring: Because natural gas fuel is the only fuel being used,compliance with the 20%opacity limit set forth by Condition 1.3 of Operating Permit 95 OPWE020 and Condition 3 of Construction Permit 01 WE0505 shall be presumed. • 7. Compliance shall be demonstrated: (Specify the frequency with which compliance will be demonstrated) Operating Permit Application 2000-600 EMISSION UNIT HAZARDOUS AIR POLLUTANTS FORM Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Marla Compressor Station 2 Facility identification code: CO 1230243 3. Stack identification code:P-111 4. Unit identification code:C-176 5. Unit material description: Natural Gas 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor references. Attached X Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name QuatitY Measurement Quantity Measurement Units Units 50-00-0 Formaldehyde - 0.28 TPY • �� 67-56-1 Methanol 0.09 TPY 75-07-0 Acetaldehyde 0.08 TPY 107-02-8 Acrolein 0.08 TPY 71-43-2 Benzene 0.05 TPY • 108-88-3 Toluene 0.02 TPY 1330-20-7 Xylene 0.01 TPY 100-41-4 Ethylbenzene 0 00 TPY 110-54-3 n-Hexane 0.00 TPY 540-84-1 224-TMP • 0.00 TPY TPY TPA" TPY :.......r..:..... ,,:.•..:: TPY . � ...,a .\ 4 TPY TPY • TPY TPY 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:Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code: P-111 4. Unit identification code:C-176 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached X Air pollutant Actual Potential to emit Maximum allowable qty U TPY U TPY Particulates(TSP) TPY PM-10 0.55 TPY Nitrogen oxides 32.44 TPY 2.0 6 32.44 Volatile organic compounds . : _ : .:. 16.22 TPY 1.0 6 16.22 Carbon monoxide 32.44 TPY 2.0 6 32.44 Lead TPY Sulfur dioxide 0.03 TPY illkotal reduced sulfur _. , TPY Reduced sulfur compounds - • TPY Hydrogen sulfide TPY Sulfuric Acid Mist TPY Fluorides TPY TPY i • .:., ; - TPY I.I,Y Units(U)should be entered as follows: =lb/hr 2=lb/mmBTU 3=grains/dscf 4=lb/gallon 5=ppmdv 6=gram/HP-hour 7=lb/mmscf R=other(specify) 9=other(specify) I0=other(specify) 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-111 4.Unit identification code: C-176 5. Pollutant 6. Colorado Air Quality 7. 8. Limitation 9. Compliance Regulations State Status or Only IN OUT Construction Permit Number Nitrogen Oxides 01WE0505 32.44 tpy X Carbon Monoxide 01WE0505 32.44 tpy X VOC 01WE0505 16.22 tpy X Natural Gas Fuel Use 01WE0505 96.40 MMscf/yr X Consumption (April 2011 Minor Mod) Opacity 01WE0505 20 percent X HAPs Operating Permit# Each individual HAP 8.0 tpy X 95OPWE020 and Total HAPs 20.0 tpy • 10.Other requirements(e.g.,malfunction reporting,special operating conditions from an State Only Compliance existing permit such as material usage,hours of operation,etc.) Status IN OUT Portable Monitoring X Engine Maintenance,Control of Emissions from Stationary Engines(NSCR and X AFRC) BTU Content of Natural Gas Verification X Air/Fuel Ratio Controller Recordkeeping X Operation and Maintenance Plan X Compliance Assurance Monitoring X ****USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** • Operating Permit Application PERMIT SHIELD PROTECTION FORM 2000-605 Colorado Department of Public Health and Environment IDENTIFICATION Rev 06-95 Air Pollution Control Division • SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Specify Emission Source: P-111 4.Do not use 5. Pollutant, 6.Colorado Air Quality 7. Equipment, Regulations State or Only Process NA • 8. Other requirements(e.g.,malfunction reporting,special operating conditions State Only from an 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 orating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 lorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE l.Facility name:Marla Compressor Station 2.Facility identification code:CO 1230243 3.Stack identification code:P-111 4.Unit identification code:C-176 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. X 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 Actions Deadline 1. • 2. 3. Progress reports will be submitted: Start date: and every six(6)months thereafter • • Marla Compressor Station Title V Operating Permit Application Forms TEG Dehydrator P-112 0123/0243/062 The Following Forms are Attached: 2000-200 2000-307 2000-400 2000-401 2000-403 2000-500 2000-503 2000-506 2000-507 2000-508 2000-600 • 2000-601 2000-604 2000-605 2000-606 0 • 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-112 3a. Construction Permit Number: 01WE0506 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 P-112 5. Stack identified on the plot plan required on Form 2000-101 V 6. Indicate by checking: V This stack has an actual exhaust point. l lie parameters are entered in Item. 7-I 3. 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. a +. '`ia ._Deg4, t at fi 3S'" sa k'C `r �yy�,� 'el. IfIK —ff � K "'e r 's' �' rr�,_,y `F,eA"I � rt� �p�;. w w t '�} l� �A€.i€et� {�.# Ye"MNtks Y ' s.'� ) •* b °t�. r 'R' 'h �t -'w" rtit 'I`a 6p �`'�� z '! � 4��.#5+ �� '� �j hN yy ^a r f',' t "+'- a 3 Ir}k6 s xl p{t `�,.�" n� .yy'a • ;27k ,� 3� ) 5kx S l _ n g ays r gsc c 'w 4 „,YY Yy ' • i t' p s E x3 4D �} Xx " h � 3`� � y c z F r i 1 S r $ u.vn ri k ° Z f+ x" 5t a. <'.#ri 1yj * % '�k- 3 t5 a`t t n ! r4'5'k'.ftti•"317r a r t `4a'n T''° 'K '� i it 'yYr"t( '#' li i • r! TI: r !, "S„ t� � , r4z ar „ �� "w €r€x s•2�av a.�t��z„ ,�rD �-* p0n g,^�,,-° � � e *****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. • • Operating Permit Application FORM 2000-307 GLYCOL DEHYDRATION UNIT Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-112 4. Dehydrator(Unit)code: 5. Unit description: Triethylene glycol dehydrator for dehydration of inlet wet gas stream 6. Indicate the dehydrator control technology status. Uncontrolled X Controlled If the dehydrator is controlled,enter the control device number(s)from the appropriate forms: 2000-400 2000-403 X 7. Manufacturer: unknown 9. Regenerator heater design rate or maximum continuous rating (mmBTU/hr): 0.6 8. Model&serial number: TBD • 10. Date first placed in service: November 2005 Date of last modification: 11. Flash Tank: x Yes No Flash tank vented to: atmosphere X recycled 12. Glycol Circulation rate: 6.25 gallons per minute(maximum) gallon per pound of H2O OR 13. Pipeline Capacity: (mmscf/day):45.0 14. Glycol Type: X Triethylene Glycol Ethylene Glycol Other(specify) 15. Glycol Make-up Rate(gallons/year): 16. Computer model input&output printout attached X Glycalc 4.0 results 17. Gas Pressure(psi): 900 18. Gas Temperature( F): 80 19. Gas composition test results VOC BTEX HEXANE Test date:02/2009 value units value units value units 8.89 Volume% 0.08 Volume% 0.107 Volume% • Operating Penn lie Health and it Application CONTROL EQUIPMENT-MISCELLANEOUS FORM 2000-400 Colorado Depnrlment of Pnb Environment Rev 06-95 Air Pollution Control Division • SEE INSTRUCTIONS ON REVERSE SIDE L Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identificationdevice codNAe: P-112 4.Unit identification code: TEC Dehydrator 5. Control code: 6. Manufacturer and model number: 7. Date placed in service: November 2005 Date of last modification: 8. Describe the device being used. The emissions from the still vent are routed to a condenser then an enclosed flare.Emissions from the Flash tank are recycled for fuel gas. 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 In1etp t ,�O/ Outlet pollutant Control <.' concentration Efficiency (%) cY1%) I ', gr/acf ppmv • VOCE 95% 14 boat polio adtt w11be Of; Ord t ##a 11 bt�t7t'aNrf�+ , - 5�� )Y..�f 5e 4 � 4' � r f r'f� d 'i a -, 4s altSniks plandee na -Sl. tbmitte lmt4the „ Itis 1hC �xb nottld. limited td t 00 85 , t1��VFllbro � �4 '4�1�tis�t�(� C „ �, '> � 0 'nom'.° %� aadttt<a t>a�wtHs • .r NOTE: COMPLETION OF INFORMATION IN SHADED AREA OF THIS FORM IS OPTIONAL Operating Permit Application CONTROL EQUIPMENT-CONDENSERS FORM 2000-401 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE Section A I.Facility name:Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code: P-112 4. Unit identification code:TEG Dehydrator 5. Control device code:C-112 6. Manufacturer and model number: 7. Date first placed in service: May 1,2005 Date last modified: 8. Describe the condenser used. _attach dianraa:of the s\'stimm. The emissions from the still vent are routed to a condenser then an enclosed flare. Emissions from the flash tank are recycled for fuel gas. A condenser control efficiency is not claimed. 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 Outlet pollutant Control Efficiency(%) concentration capita concentration effic8epzy ''PPmv . ppmv • 10. Discuss how the collected materlal will be handled if t...grouse or Emissions from the fisligibliiik lu'e cycled for fuel•gns. , ;! 11. Prepare a malfunction prevention and abatement:plan for this pollution control system.The plan does rt4: have to be submitted with the application. It ittOggested the plem*lode,but not be limited to following: at..:.. Identification of the individuals(s),by title,respgaailtle for utepcc tit4g,maintaining and repairing this device. b: .(qtperation*ariables such as temperature that will be monitored in Order to detect a malfunction or : ,1 agh,thecorrect that°perariting range detailed of and a description of monitoring otr . : ..b ee proceduresused to ehew'compliance. of monitoring equipment will bep ed(temperature sensors,pressure sensclrsi OEMs). ikon schedule and ite fs or condthons:that will be inspected ' e.. •:::::1@ierelithis plan available forieview? Section B The following questions must be answered by sources installing new equipment or existing Units that cannot document control efficiency of this device by other means. 12. ' :'.1t:yesage specific beat of the condensing g 13. Pressure drop range across the coolant(psis): ttrieditia (iTtfilll : 14. ,.'Mass llp'w rate of condensing medium 15. Temperatures of the condensing medium(EF): (1b1hi T(inlet) T(outlet) 16. dolts ofthe condensing 17. Mass flow rate of the vapor stream medium. 18., Average specific heat of the vapor 19. Inlet and outlet temperature of the vapor stream(EF) *pain(B'FU/1biEIt):; . T(inlet) T(outlet) 20: H Aka- of the device(fl 2): 21. Heat transfer coefficient(BTU/f /hr/EF) • Operating Permit Application CONTROL EQUIPMENT Form 2000-403 Colorado Department of CATALYTIC OR THERMAL OXIDATION Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE Section A 1. Facility name: Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code:P-112 4. Unit identification code:Dehy Condenser&Flare 5. Control device code:C-112 6. Manufacturer and model number: 7. Date placed in service:05/01/2005 Date last modified: 8- Describe the oxidation system. Au4cli a di:uram of the system. The condenser and flare will control the emissions of VOCs and HAPs at 95%efficiency. 9.List the pollutants to be controlled by this equipment and the expected control efficiency for each pollutant on the table below. 4 Documentation attached EITHER the outlet pollutant concentration OR the control efficiency must be provided. Pollutant Inlet pollutant concentration Outlet pollutant concentration Control Efficiency(%) gr/act • ppanv g/hp-hr ppmv Emission Pollutant Capture . Destruction VOC HAPs (Refer to GlyCalc 4.0) .. . 10: Check one: Catalytic I Thermal oxidizer 1:1: Discuss how the ttpeatcatalyst will be handled for reuse or disposal. 111 • 12. Prepttili;kbahon fievaootion lmki elbatenncrtt plan for tbts;poison control system:Theoicdoea>toli>rg to be submitted with thettppbication It is suggeitett.thaplan include,but not be limited to.the following: ir Identification.of the mdmduttls(s),by t e tesj,onsibte for inspecing..nsai lining and &t1 device b. Opetagen viaiablea such as tie that 011 be monitored in order to detect t malfunction oibiatibrOgh,the **Pet ape g thosevariablm, ; •OOSIOkwon of monitoring or surveillance eduteiii* ill be used to sbowoompliance: • c: An inspection schedule and items or eo #hat Will be inspected. catalytic;papdizem discuss the*placement and/....regeneration schedule for the bed and bavietaken to ensure the bbd`s. its expected of J!!�.. p �8�t� � lie.: . . is this platavailable for revielw?; Section B The following questions must be answered by sources installing new equipment or existing Units which cannot document control efficiency of this device by other means.(Catalytic/Thermal dependent on item 10) ( cox Thermal oxidation 1#a: Operating temperature(EF)- :. . b. Operating temperature(EF): Miin- Max, Min 14a. Catalyst bed.Volume(f )'' b. Combustion chamber volume(ft`): 15a Gas volumetric flow rate atcatmbystion conditions b. Maximum gas velocity through the device(ft./sec): �. E 16aL'••' Tye ofliml used: ••. b. Type of fuel used:natural gas r .. 17a. Max ft nee rate(BTU/114) b. Maximum fuel used(BTU/Hr): 18a. Type and volume of catalyst utsd(f ): 19a. Residence time(seconds): b. Residence time(seconds): • Operating permit Application COMPLIANCE CERTIFICATION-MONITORING AND REPORTING FORM 2000-500 Colorado Department of DESCRIPTION OF METHODS USED Rev 06-95 Public Health and Environment FOR DETERMINING COMPLIANCE Air Pollution Control Division 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 Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-112 4. Unit identification code: TEG Dehydrator 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) N/ Monitoring Control System Parameters or Operating Parameters of a Process-Form 2000-503 Pollutant(s): VOC • 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):VOC,Benzene,Toluene,n-hexane,Xylene Recordkeeping-Form 2000-507 Pollutant(s): VOC,Benzene,Toluene,n-hexane,Xylene J Other(please describe)-Form 2000-508 Pollutant(s):VOC,Benzene,Toluene,n-hexane,Xvlene 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February 1,2012 of the year following the Operating Permit renewal. Compliance monitoring reports will be submitted to the Division according to the following schedule: Start date: February 1,2012 of the year following the Operating Permit renewal. 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. • Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-503 Colorado Department of MONITORING CONTROL SYSTEM PARAMETERS OR Rev o6-95 Public Health and Environment OPERATING PARAMETERS OF A PROCESS Air Pollution Control Division 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-112 4.Unit identification code: TEG Dehydrator,condenser& flare 5. Pollutant(s)being monitored: VOC,Benzene,Toluene,Ethylbenzene,n-Hexane and Xylene 6. Name of manufacturer: 7. Model number: 8. I Is this an existing system? J Yes No 9. _ i scr�cd icr future uNc 10. Describe the method of monitoring: Combustion Log: A daily log continuous log is kept showing that any time the TEG dehydrator is operating,the flare is also operating.This will ensure that volatile gases are combusted when introduced to the burner combustion chamber. Glycol recycle rate is less than or equal to 6.25 gallons per minute recorded by operators to limit water removal and production from unit by design. The flare is enclosed,has no visible emissions and will be visually observed on a • daily basis to determine whether it is operating properly. 11. Backup system: Assume max pump rate and design rate 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 - J The presence of a pilot flame in the flare is monitored daily by visual observation. Glycol recycle rate is also recorded manually by an operator on a daily basis.QA/QC checked by periodic review of log by Supervisory personnel. 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 • Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-506 Colorado Department of Public Health and Environment FUEL SAMPLING AND ANALYSIS Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-112 4. Unit identification code: TEG Dehydrator 5. Pollutant being monitored: VOC,Benzene,Toluene, 6. Fuel being sampled: Process Natural Gas to Dehy Ethylbenzene,n-Hexane,Xylene 7. List the ASTM or EPA fuel sample collecting and analyzing methods used: Extended Gas Analysis ASTM D6730 8. Is this an existing FSA system'? 'IYes No 9. Implementation Date: 10. Automated sampling -\/ Manual sampling 11. Backup system? 12. Compliance shall be demonstrated: Daily Weekly Monthly X Other—annual 13. Quality Assurance/Quality Control: The FSA system certification is attached for Division review. The FSA system is not certified,but the certification package was submitted to the Division on The FSA system certification will be submitted to the Division by the date shown in our monitoring/compliance plan. A Quality Assurance/Quality Control plan for the fuel sampling program is attached for Division review. The QA/QC plan is not attached,but will be submitted to the Division by Annual sampling completed by contractors who follow QA/QC requirements specified in test method and performed by the lab during analysis. 14. Attach a schematic of the FSA system showing the sample acquisition point and the location of the machine that produces the daily, weekly,or monthly composite fuel sample. Gas sampling is completed manually using a pressurized gas cylinder. Sample is a wet gas grab sample taken in-line prior to flashing and the dehydrator unit. ***** Any composite sample over the emission limit shall be reported as an excess emission. ***** • Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of BY RECORDKEEPING Rev 06-95 Public Health and Environment • Air Pollution Control Division Recordkeeping maybe 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 I. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-112 4. Unit identification code: TEG Dehydrator 5. Pollutant(s)being monitored: 6. Material or parameter being monitored and recorded: VOC,Benzene,Toluene,Ethylbenzene,n-Hexane,Xylene Gas throughput,Rolling(12)Month Totals,Glycol Recirculation Rate,hours of TEG operation 7. Method of monitoring and recording(see information on back of this page): Emissions of air pollutants will be calculated using a rolling 12-month total and compliance determined with annual limits. The rolling 12-month total is calculated every month based on the previous twelve months of data. VOC and HAP emissions will be calculated monthly using GlyCalc 4.0. TEG recirculation rate,flash tank temperature and pressure,wet gas inlet temperature and pressure will be monitored weekly and entered into the GlyCalc 4.0 model. The condenser outlet temperature(daily highest value)will be monitored daily and entered into the GlyCalc 4.0 model. Natural gas processed by the TEG unit shall be tracked by flow meters and recorded monthly. An inlet gas sample will be collected annually and analyzed for an extended analysis. The TEG unit hours of operation and days operated will be monitored monthly and recorded. The days of operation will be used to calculate an average daily gas throughput to be entered into GlyCalc 4.0 model runs. The maximum lean glycol pumping rate will not exceed 6.25 gallons per minute and will be recorded weekly. • 8. List any EPA methods used: None 9. Is this an existing method of demonstrating 10. Start date: November 2005 compliance? No J Yes 11. Backup system: Assume maximum values for recordkeeping analysis in case of missing values 12 a. Data collection frequency: Daily Weekly \I Monthly Batch(not to exceed monthly) Other-specify 12 b. Compliance shall be demonstrated: Daily Weekly iMonthly 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 Midstream currently maintains recordkeeping with this facility using a spreadsheet to calculate emissions and record monitoring data. 14. A proposed format for the compliance certification report and excess emission report is attached. DCP Midstream currently submits compliance certification reports and excess emissions reports to the Colorado Mr Pollution Control Division for this facility. 0 ***** 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. • 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-112 4.Unit Identification code: TEG Dehydrator 5. Pollutant(s)or Parameter(s)being monitored: VOC,Benzene,Toluene, Ethylbenzene,n-Hexane,Xylene; Gas throughput; Glycol Recirculation Rate 6. Description of the method of monitoring: A GLYCaIc 4.0 modeling analysis will be completed monthly using the most recent gas analysis,giving a monthly emission estimate.The glycol circulation rate will be monitored by an individual meter. • 7. Compliance shall be demonstrated: (Specify the frequency with which compliance will be demonstrated) The recordkeeping will show that compliance has been demonstrated through the comparison of GLYCaIc modeled 12- month rolling emission estimates to the annual limits in the permit.The recordkeeping will also demonstrate the throughput and glycol circulation rate are within the permitted limits. • Operating Permit Application EMISSION UNIT HAZARDOUS AIR POLLUTANTS FORM 2000-600 Colorado Department of Public Health and Environment Rcv o6-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code:P-112 4. Unit identification code:TEG Dehydrator 5. Unit material description: Triethylene glycol(TEG)Dehydrator used for dehydration of inlet wet gas stream. 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor references. Attached X Actual Emissions Data is for calendar year Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name Qe ty Measur Mena Quantity Measurement Units':. Units 71-43-2 Benzene 0.31 TPY l0S-88-3 Toluene 0.51 TPY 100-41-4 Ethylbenzene 0.02 TPY 1330-20-7 Xylene 0.25 TPY 110-54-3 n-Hexane 0.06 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. I • 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: Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code:P-112 4. Unit identification code:TEG Dehydrator 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached X Air pollutant Acttli0l Potential to emit Maximum allowable Qt>tasnisty. ': U TPY U TPY Particulates(TSP) l PY PM-10 TPY Nitrogen oxides TPY Volatile organic compounds 2.82 TPY CLYCaIc 2.82 Carbon monoxide TPY Lead TPY Sulfur dioxide TPY otal reduced sulfur I P Y • Reduced sulfur compounds TPY Hydrogen sulfide TPY Sulfuric Acid Mist TPY Fluorides TPY TPY TPY TPY" TPY Units(U)should be entered as follows: =lb/hr 2=lb/mmBTU 3=grains/dscf 4=lb/gallon 5=ppmdv 6=gram/HP-hour 7=lb/mmscf • 8=other(specify) 9=other(specify) 10=other(specify) 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 0 SEE INSTRUCTIONS ON REVERSE SIDE 1.Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-112 4. Unit identification code: TEG Dehydrator Form 2000-307 5. Pollutant 6. Colorado Air Quality 7. 8. Limitation 9. Compliance Regulations State Status or Only IN OUT Construction Permit Number VOC 01WE0506 E0506 2.82 tpy X 71-43-2 Benzene 0.31 tpy X 108-88-3 Toluene 0.51 tpy X 100-41-4 Ethylbenzene 0.02 tpy X 1330-20-7 Xylene 0.25 tpy X 110-54-3 n-Hexane 0.06 tpy X • 10.Other requirements(e.g.,malfunction reporting, special operating conditions from an State Only Compliance existing permit such as material usage,hours of operation, etc.) Status IN OUT TEG days and hours of operation,throughput of natural gas X Rolling 12-month emissions totals,recordkeeping requirements X Reporting/Compliance testing(annual extended gas analysis) X Reg.7 Emission Control Requirements(90% reduction of VOCs) X X Glycol circulation rate,flash tank temperature&pressure,wet gas inlet temperature X • and pressure,condenser outlet temperature ****USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT** • Operating Permit Application PERMIT SHIELD PROTECTION FORM 2000405 Colorado Department of Public Health and Environment IDENTIFICATION Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Marla Compressor Station 2.Facility identification code: CO 1230243 3. Specify Emission Source: P-112 4. Do not use 5.Pollutant, 6. Colorado Air Quality 7. State Only Equipment, Regulations or Process • 8. Other requirements(e.g.,malfunction reporting,special operating State Only conditions from an 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 • •crating 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 I.Facility name:Marla Compressor Station 2.Facility identification code:CO 1230243 3.Stack identification code:P-112 4.Unit identification code:TEG Dehydrator 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. X 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 Actions Deadline 1. • 2. 3. Progress reports will be submitted: Start date: February 1,2012 and every six(6)months thereafter Marla Compressor Station Title V Operating Permit Application Forms TEG Dehydrator P-113 0123/0243/063 The Following Forms are Attached: 2000-200 2000-307 2000-400 2000-401 2000-403 2000-500 2000-503 2000-506 2000-507 2000-508 • 2000-600 2000-601 2000-604 2000-605 2000-606 S • 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 I. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-113 3a.Construction Permit Number: 05WE0579 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 P-113 5. Stack identified on the plot plan required on Form 2000-101 V 6. Indicate by checking: V This stack has an actual exhaust point. 111e:pal ,Ire 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 en is required for Item 7. 7 {r g I F +„ Ya s▪ " t `p T, t h '� Wpa� ", ,'= ;a`v'+ �In?^N' .vtsee-`�� Ly• H6 yV° a{ '' r •: ,�,JJ .-^+� '7. . i f� ��v9t..Cia ,kq r nl 5� 5 it: 4+ rii+r ; rA.'":1.. 4-4:,;',.,vt `Y 'F s'+6 ` c 5'n @k ;,,,Lt..;t a;i'ww' ( e { { y it 11,...''�'rr.` q? <;t , 1,� � r I s ' d tjr . , ".. 1 d;,.u. '{,; «,M g f r t „� ...+,44 m p ;1;:.V!,;.,:'..-4:'‘ t'b" esr k u;y�.r,. ,j yr a ` a. ro e+ ..;,,,L,*,,,,.S.'r' ,„ tilgg "PAY .4xkti t i. 0. 1rc qY� � 7A a �"y rd�>; � � "ti � s P rax h� rv�"u�.��,; Sr't F °yr,�vr a '�Q�,..k34 t'"fi „a14 °1I i E �'� is k3f�,v" ' tS^f'�" w.r I �� h c tS w, i" 1 p r ti >Ik ll 4 ' :,'7'e,''''''.4'n s ri a.%)44, ,,d.,r';',,"'",' * F h `'" `- ',, y P 't9! Tr r a €fiin. ^"',�q.�,° 'i, ,r�e,�, ,v $', a k .r.v '4T x `y Y s '•v b4 {.,. ` x c3 fib �' ✓2` t' y�,�,,s„�. �' 'Fr, �vr � a�a,�7��. cx � t ,�a,?� `�` 1.'., m.wa��,s v�� ' � " � to 5 . I: t r yif: .4rGI* 1 2.,w dp . .n ' `r t a ✓$fw ' �i s ys° ,N^ Y war,,x r." s S f r h't5s ��y.. y ' ,. c wa , ngo- .r ,:. 1 ryk vS a isigaay. r +gt e",.'✓ ,. , v u:asr S 3 �+a A'4�' +� "«' � .-�k1�" ' x s�,a �' k e y y 4 4-0,4a4-‘4 )k' k i ��hDt�l � � two �,t+a §T# sc p Ir mY^ r tl` g' rk'3: +• a s'75 a t .s ,y1y 4',n il � c C ��' ,'$;t �s 1-iae+ d' � � � i x x "'Yr' s Rt _��':� �v *****Complete the appropriate Air Permit Application Form.s(s)2000-300,301,302,303,304,***** 305,306,or 307 for each Unit exhausting through this stack. • • 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:Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-113 4. Dehydrator(Unit)code: 5. Unit description: Triethylene glycol dehydrator for dehydration of inlet wet gas stream 6. Indicate the dehydrator control technology status. Uncontrolled X Controlled If the dehydrator is controlled,enter the control device number(s)from the appropriate forms: 2000-400 2000-403 X 7. Manufacturer: unknown 9. Regenerator heater design rate or maximum continuous rating (mmBTU/hr): 0.6 8. Model&serial number: TBD 10. Date first placed in service: November 2005 Date of last modification: 11. Flash Tank:x Yes No Flash tank vented to: atmosphere X recycled 12. Glycol Circulation rate: 6.25 gallons per minute(maximum) gallon per pound of H2O OR 13. Pipeline Capacity: (mmscf/day): 45.0 14. Glycol Type: x Triethylene Glycol Ethylene Glycol Other(specify) 15. Glycol Make-up Rate(gallons/year): 16. Computer model input&output printout attached X Glycalc 4.0 results 17. Gas Pressure(psi): 900 18. Gas Temperature( F): 80 19. Gas composition test results VOC BTEX HEXANE Test date: 02/2009 value units value units value units 8.89 Volume % 0.08 Volume% 0.107 Volume • Operating Permit Application CONTROL EQUIPMENT-MISCELLANEOUS FORM 2000-400 Colorado Department of Public Health and Environment Rcv 06-95 Air Pollution Control Division •SEE INSTRUCTIONS ON REVERSE SIDE . Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-113 4.Unit identification code: TEG Dehydrator 5. Control device code:NA 6. Manufacturer and model number: 7. Date placed in service: November 2005 Date of last modification: 8. Describe the device being used. The emissions from the still vent are routed to a condenser then an enclosed flare.Emissions from the flash tank are recycled for fuel gas. 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 pollutmd l'�IniSeia Outlet pollutant Control n concentration Efficiency - tare: (%) efiiOien- • gr/act` p gr/acf ppmv VOC 95% 10. 13 t v haw the collected mat�altnli be ha•ndled for reuse 0r dial. ittp b ink are recycled V irgil • n. Plant*thta t system nit p4na dpea tzct to be emitted with applieati it°is the pint inclede,'tiu t not be Iimiiodioibe a 'donna***tsf#1 a divitktag4O, ,responsible for andxqt ieg e. dt vie Baal as t lllbe ,end ted-m #octet t malfunction 0rbtea t 4 the t t'pCt a_teranng Pane attheee variables,and a�' idn of moaito$ng ntbm �o ►t*ft'mieiau apiwaneer, a, `' of thing a111� C ' lsr!sesttte moots, isj • d.. .A'a Ara itractr lay mtwilt beia q .: f. #ere in 'nian avol•bk for maim NOTE: COMPLETION OF INFORMATION IN SHADED AREA OF THIS FORM IS OPTIONAL Operating Permit Application CONTROL EQUIPMENT-CONDENSERS FORM 2000-401 Colorado Department of Public Health and Environment Rev 06-95 • Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE Section A 1.Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-113 4. Unit identification code: TEG Dehydrator 5. Control device code: C-113 6. Manufacturer and model number: 7. Date first placed in service: November 2005 Date last modified: 8. Describe the condenser used. Attach a diaantm of the sv stem_ The emissions from the still vent are routed to a condenser then an enclosed flare. Emissions from the flash tank are recycled for fuel gas. A condenser control efficiency is not claimed. 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 Inletpcltttiant Emission Outlet pollutant Control Efficiency(%) concentration capture concentration efciency ppmv ppmv • 10. IAtecu9e lmw ihC atallec$ s7W.ile Imd.far reuse or disposal. " from the basilisk are aetYded for tai Bra. Ii. PA Cs Ida:ter this¢aiit'}t��u�tC�� aia;$ t t et4 have to be submitted withte appl�ictltwo. It is the plant 'a a bnt 4ptb,C<I 16Dt* . , a onc'ebe * 14a}.byt , foti a 1s'`c de. b. taps vatid es sash tat Warfaeteatatlatt wall be"ennead in er4r-*Seet'ar081 , pp tr"" bealktl mugb,the eaaaeetopeatiog range otlhesewati5_hles,and a notailt4‘40,1011041001#0404P) sattveliltatulee pr that Win be tared to show Cimipltance. c, 'WbaR}peof ' will be provided(teraperatu+eaBfla0la,i sc s,C-- d A$liwiarentutiebtattneland*war conditions that still be ins my t e. While is this plea feereview? Section B The following questions must be answered by sources installing new equipment or existing Units that cannot document control efficiency of this device by other means. 12. Aver a iftc heat of t e g 13. Pressure drop range across the coolant(pain): nSiU u.(B`1'G3l +I F) 14, Masa new rata CO Ig me(iam 15. Temperatures of the condensing medium(EF): ( T(inlet) T(outlet) • lmti ttton oftkte pin8. 17. Mass lhtw rate of the vlapatr stream( I* 18. Aarattne sp eirta berates vapor 19. Inlet and outlet temperature of the vapor stream(EF) Meant OrtthibiOn T(inlet) T(outlet) 20.` lteaitsansfer area ottht device(f12); 21. Heat bander eordneket:8Tl7/#/btiEF) Operating Permit Application CONTROL EQUIPMENT Form 2000-403 Colorado Department of CATALYTIC OR THERMAL OXIDATION Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE Section A 1. Facility name:Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code:P-113 4. Unit identification code: Dehy Condenser&Flare 5. Control device code:C-113 6. Manufacturer and model number: 7. Date placed in service:05/01/2005 Date last modified: 8. Describe the oxidation system. litacb a diallram oI'tlle syslcm. The condenser and flare will control the emissions of VOCs and HAPs at 95%efficiency. 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 concentration. Outlet pollutant concentration Control Efficiency(%) gr/acf ppasv g/hp-hr ppmv Pollutant Destruction VOC :..:... .,. 95% HAPs (Refer to GlyCalc 4.0) _ . • 10: Check one: Catalytic Thermal oxidizer 11. Discuss how the spent catalyst will be handled for reuse or disposal i2 .Prterare it malfunction prevention and abatement planplanforthi4ollution control systean The plan does not hate to4be tatithitieti'Witli the;application. it is suggested the plan include,.hut notbe":limited to the f0lloiving; t1 • Identification of the indixviduals(s),by tide,responalble for inspeoriag,maintaining and rap e$this device. b. Operation variables such as temperature that will be monitored in order to detects Malfunction or ieakthrougb,die. I.correct operating:range of these variables,-and a detailed - utted; description of monitoring or s >Ylan've that will be Mind* 'last show compliance. c. A inspections edule and items or conditions that *awned.ned. For catalytic oxidize c;discuss the replacement •:≥ d/or regeneration schedule for the bedund steps you have taken to ensile the bed's prOPerfonetioningthroughout its"pained lifetime . d. Where*this plan available for review? Section B The following questions must be answered by sources installing new equipment or existing Units which cannot document control efficiency of this device by other means.(Catalytic/Thermal dependent on item 10) Catalytic oxidation =>. Thermal oxidation 13a Operating teanpesani: : b Operating temperature(EF): Max Max Min 14a. Catalyst bed volume(ft): b. Combustion chamber volume(f13): 154. Gas volumetric flow rate at combustioorieonditiot b. Maximum gas velocity through the device(ft./sec): (ACS): 16a. Type of fuel used: b. Type of fuel used:natural gas 17a. Max fuel use rate($Tl.IfHr): b. Maximum fuel used(BTU/Hr): iSa.. Type and volume of catalyst used(f e): i9a. Residence time(seconds): b. Residence time(seconds): • Operating Permit Application COMPLIANCE CERTIFICATION-MONITORING AND REPORTING FORM 2000-500 Colorado Department of DESCRIPTION OF METHODS USED Rev 06-95 Public Health and Environment FOR DETERMINING COMPLIANCE Air Pollution Control Division 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 Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-113 4. Unit identification code: TEG Dehydrator 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) J Monitoring Control System Parameters or Operating Parameters of a Process-Form 2000-503 Pollutant(s): VOC Monitoring Maintenance Procedures-Form 2000-504 Pollutant(s): Stack Testing-Form 2000-505 Pollutant(s): \i Fuel Sampling and Analysis(FSA)- Form 2000-506 Pollutant(s):VOC,Benzene,Toluene,n-hexane,Xylene Recordkeeping-Form 2000-507 Pollutant(s): VOC,Benzene,Toluene,n-hexane,Xylene J Other(please describe)-Form 2000-508 Pollutant(s): VOC,Benzene,Toluene,n-hexane,Xvlene 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February 1,2012 of the year following the Operating Permit renewal. Compliance monitoring reports will be submitted to the Division according to the following schedule: Start date: February 1,2012 of the year following the Operating Permit renewal. 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. • Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-503 Colorado Department of MONITORING CONTROL SYSTEM PARAMETERS OR Rev 06-95 Public Health and Environment OPERATING PARAMETERS OF A PROCESS Air Pollution Control Division 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 I. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-113 4.Unit identification code: TEG Dehydrator,condenser& flare 5. Pollutant(s)being monitored: VOC, Benzene,Toluene,Ethylbenzene,n-Hexane and Xylene 6. Name of manufacturer: 7. Model number: 8. I Is this an existing system? I Yes No 9. Reserved for future use 10. Describe the method of monitoring: Combustion Log: A daily log continuous log is kept showing that any time the TEG dehydrator is operating, the flare is also operating.This will ensure that volatile gases are combusted when introduced to the burner combustion chamber. Glycol recycle rate is less than or equal to 6.25 gallons per minute recorded by operators to limit water removal and production from unit by design. The flare is enclosed,has no visible emissions and will be visually observed on a • daily basis to determine whether it is operating properly. 11. Backup system: Assume max pump rate and design rate 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 - The presence of a pilot flame in the flare is monitored daily by visual observation. Glycol recycle rate is also recorded manually by an operator on a daily basis.QA/QC checked by periodic review of log by Supervisory personnel. 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 • • Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-506 Colorado Department of Public Health and Environment FUEL SAMPLING AND ANALYSIS Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-113 4. Unit identification code: TEG Dehydrator 5. Pollutant being monitored: VOC,Benzene,Toluene, 6. Fuel being sampled: Process Natural Gas to Dehy Ethylbenzene,n-Hexane,Xylene 7. List the ASTM or EPA fuel sample collecting and analyzing methods used: Extended Gas Analysis ASTM D6730 8. Is this an existing FSA system? -Yes No 9. Implementation Date: 10. Automated sampling 1 Manual sampling 11. Backup system? 12. Compliance shall be demonstrated: Daily Weekly Monthly X Other—annual 13. Quality Assurance/Quality Control: The FSA system certification is attached for Division review. • The FSA system is not certified,but the certification package was submitted to the Division on The FSA system certification will be submitted to the Division by the date shown in our monitoring/compliance plan. A Quality Assurance/Quality Control plan for the fuel sampling program is attached for Division review. The QA/QC plan is not attached,but will be submitted to the Division by Annual sampling completed by contractors who follow QA/QC requirements specified in test method and performed by the lab during analysis. 14. Attach a schematic of the FSA system showing the sample acquisition point and the location of the machine that produces the daily,weekly,or monthly composite fuel sample. Gas sampling is completed manually using a pressurized gas cylinder. Sample is a wet gas grab sample taken in-line prior to flashing and the dehydrator unit. *****Any composite sample over the emission limit shall be reported as an excess emission. ***** • Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of BY RECORDKEEPING Rev 06-95 Public Health and Environment 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-113 4. Unit identification code: TEG Dehydrator 5. Pollutant(s)being monitored: 6. Material or parameter being monitored and recorded: VOC,Benzene,Toluene,Ethylbenzene,n-Hexane,Xylene Gas throughput,Rolling(12)Month Totals,Glycol Recirculation Rate,hours of TEG operation 7. Method of monitoring and recording(see information on back of this page): Emissions of air pollutants will be calculated using a rolling 12-month total and compliance determined with annual limits. The rolling 12-month total is calculated every month based on the previous twelve months of data. VOC and HAP emissions will be calculated monthly using GlyCalc 4.0. TEG recirculation rate,flash tank temperature and pressure,wet gas inlet temperature and pressure will be monitored weekly and entered into the GlyCalc 4.0 model. The condenser outlet temperature(daily highest value)will be monitored daily and entered into the GlyCalc 4.0 model. Natural gas processed by the TEG unit shall be tracked by flow meters and recorded monthly. An inlet gas sample will be collected annually and analyzed for an extended analysis. The TEG unit hours of operation and days operated will be monitored monthly and recorded. The days of operation will be used to calculate an average daily gas throughput to be entered into GlyCalc 4.0 model runs. The maximum lean glycol pumping rate will not exceed 6.25 gallons per minute and will be recorded weekly. • 8. List any EPA methods used: None 9. Is this an existing method of demonstrating 10. Start date: November 2005 compliance? No Af Yes 11. Backup system: Assume maximum values for recordkeeping analysis in case of missing values 12 a. Data collection frequency: Daily Weekly -Ni Monthly Batch(not to exceed monthly) Other-specify 12 b. Compliance shall be demonstrated: Daily Weekly 4Monthly 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 Midstream currently maintains recordkeeping with this facility using a spreadsheet to calculate emissions and record monitoring data. 14. A proposed format for the compliance certification report and excess emission report is attached. DCP Midstream currently submits compliance certification reports and excess emissions reports to the Colorado Air Pollution Control Division for this facility. • ***** 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. • 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: Marla Compressor Station 2.Facility identification code: CO 1230243 3. Stack identification code: P413 4.Unit Identification code: TEG Dehydrator 5.Pollutant(s)or Parameter(s)being monitored:VOC,Benzene,Toluene, Ethylbenzene, n-Hexane,Xylene; Gas throughput; Glycol Circulation Rate 6. Description of the method of monitoring: A GLYCaIc 4.0 modeling analysis will be completed monthly using the most recent gas analysis,giving a monthly emission estimate.The glycol circulation rate will be monitored by an individual meter. 11. 7. Compliance shall be demonstrated: (Specify the frequency with which compliance will be demonstrated) The recordkeeping will show that compliance has been demonstrated through the comparison of GLYCaIc modeled 12- month rolling emission estimates to the annual limits in the permit.The recordkeeping will also demonstrate the throughput and glycol circulation rate are within the permitted limits. I Operating Permit Application EMISSION UNIT HAZARDOUS AIR POLLUTANTS FORM 2000-600 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code: P-113 4. Unit identification code: TEG Dehydrator 5. Unit material description: Triethylene glycol(TEG)Dehydrator used for dehydration of inlet wet gas stream. 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor references. Attached X Actual Emissions Data is for calendar year Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name Quantity Measurement Quantity Measurement Units Units 71-43-2 Benzene 0.31 TPY 108-88-3 Toluene 0.51 TPY Yi. 100-41-4 Ethylbenzene ,` ' 0.02 TPY lk r 1330-20-7 Xylene ' : .°: .` 0.25 TPY 110-54-3 n-Hexane 0.06 TPY r. • `• TPY TPY TPY TPY TPY j4. 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. • Operating Pirmit 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:Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code: P-113 4. Unit identification code:TEG Dehydrator 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached X Air pollutant Actual ... Potential to emit Maximum allowable U. TTY• 1 t l'Y Particulates(TSP) TPY PM-10 • .. . TPY Nitrogen oxides TPY Volatile organic compounds 2.82 TPY GLYCaIc 2.132 . . .. Carbon monoxide .,. •.�: TPY Lead TPY Sulfur dioxide TPY otal reduced sulfur T PY Reduced sulfur compounds 1 PY Hydrogen sulfide TPY Sulfuric Acid Mist TPY Fluorides TPY 1";: TPY TPY TPY TPl' Units(U)should be entered as follows: l=lb/hr 2=lbimmBTU 3=grainsidscf 4=lbi gallon 5=ppmdv 6=gram/HP-hour 7=lbimmscf A=other(specify) 9=other(specify) 10=other(specify) 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 I.Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-113 4.Unit identification code: TEG Dehydrator Form 2000-307 5.Pollutant 6. Colorado Air Quality 7. 8.Limitation 9. Compliance Regulations State Status or Only IN OUT Construction Permit Number VOC 05WE0579 2.82 tpy X 71-43-2 Benzene 0.31 tpy X 108-88-3 Toluene 0.51 tpy X 100-41-4 Ethyibenzene 0.02 tpy X 1330-20-7 Xylene 0.25 tpy X 110-54-3 n-Hexane 0.06 tpy X • 10. Other requirements(e.g.,malfunction reporting, special operating conditions from an State Only Compliance existing permit such as material usage,hours of operation, etc.) Status IN OUT TEG days and hours of operation,throughput of natural gas X Rolling 12-month emissions totals,recordkeeping requirements X Reporting/Compliance testing(annual extended gas analysis) X Reg.7 Emission Control Requirements(90%reduction of VOCs) X X • Glycol circulation rate,flash tank temperature& pressure,wet gas inlet temperature X and pressure,condenser outlet temperature ****USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT** Operating Pennit Application PERMIT SHIELD PROTECTION FORM 2000-605 Colorado Department of Public Health and Environment IDENTIFICATION Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1.Facility name: Marla Compressor Station 2.Facility identification code: CO 1230243 3. Specify Emission Source: P-113 4.Do not use 5. Pollutant, 6. Colorado Air Quality 7. State Only Equipment, Regulations or Process NA • L 8. Other requirements(e.g.,malfunction reporting,special operating State Only conditions from an 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 • emting Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 olorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE l.Facility name:Marla Compressor Station 2.Facility identification code:CO 1230243 3.Stack identification code:P-113 4.Unit identification code:TEG Dehydrator 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. X 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 Actions Deadline • 2. 3. Progress reports will be submitted: Start date: February 1,2012 and every six(6)months thereafter • • Marla Compressor Station Title V Operating Permit Application Forms Equipment Fugitive Leaks P-106 0123/0243/056 The Following Forms are Attached: 2000-200 2000-306 2000-500 2000-502 2000-504 2000-507 2000-600 2000-601 2000-604 2000-605 2000-606 • 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-106 3a. Construction Permit Number: 01WE0502 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 5. Stack identified on the plot plan required on Form 2000-101 6. Indicate by checking: Ai I This stack has an actual exhaust point. t he paran-R ier arc entered in I terns 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. 1)ischote height abovevouttd,leve:_{feet) $. ingilledimpngltms ak ttuti e`heek ea a and colylete): A,. • atop*, (feet) R ,—.-l.01;110101-04,1-4,19,1h ) . • 9 #tcwtote: • Normal_,�,..,(Accm) nittexititute ,. Velocity (FPS) '4 Caleilab‘ Stack Test ; a5 : 10. 11. ¢a" est as 11101fle`00111ent' "Yet-" .k - . s, = If W$0.t*ltaelat,gas sly 40 ia* i w+� As u r c y r • �' J ` i 13. I cki401PPO wiw r tray 0°1411 -10 WI 4±ec*0°,40 , *acids' ge stat&sJetela Yna llo ., *****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. • 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3.Stack identification code: P-106 4. Process(Unit)code: Fugitives 5. Unit description: Fugitive VOC Emissions from Equipment Leaks 6. Indicate the control technology status. X Uncontrolled Controlled If the process is controlled, enter the control device code(s) from the appropriate form(s): 2000-400 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: 09/25/2001 Date of last modification: 9. Normal operating schedule: 24 hrs./day 7 days/wk. 8,760 hours/yr. 10. Describe this process(please attach u Claw (ilaeram at the process). Attached?X Fugitive emissions are from equipment leaks during normal operations, including leaks from flanges,connectors,valves,seals, and other equipment 11. List the types and amounts of raw materials used in this process. Material Storage/material Actual.usage Units Maximum usage Units handling process • Natural Gas 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 NA 13.Process fuel usage: Type of fuel Maximum heat input to Actual usage lints Maximum usage Units process million BTU/hr. NA • • 14. Describe any fugitive emissions associated with this process, such as outdoor storage piles,unpaved roads, open conveyors,etc.:Fugitive emissions are from equipment leaks during normal operations, including leaks from flanges, connectors,valves,seals,and other equipment ***** 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. ***** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** • • • Operating Permit Application COMPLIANCE CERTIFICATION-MONITORING AND REPORTING FORM 2000-500 Colorado Department of DESCRIPTION OF METHODS USED Rev 06-95 Public Health and Environment FOR DETERMINING COMPLIANCE Air Pollution Control Division 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 l. Facility name Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-106 4. Unit identification code: Fugitives 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): VOC Monitoring Control System Parameters or Operating Parameters of a Process-Form 2000-503 Pollutant(s): • J Monitoring Maintenance Procedures-Form 2000-504 Pollutant(s):VOC Stack Testing-Form 2000-505 Pollutant(s): Fuel Sampling and Analysis(FSA)-Form 2000-506 Pollutant(s): VOC Recordkeeping-Form 2000-507 Pollutant(s):VOC Other(please describe)-Form 2000-508 Pollutant(s): 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February 1,2012 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 1,2011 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. • Operating Pennit Application COMPLIANCE DEMONSTRATION BY PERIODIC EMISSION FORM 2000-502 Colorado Department of MONITORING USING PORTABLE MONITORS Rev 06-95 Public Health and Environment Air Pollution Control Division The use of a portable continuous emission monitor(CEM)may be acceptable as a compliance demonstration method. A monitoring plan shall contain the following information: the name and address of the source;the source facility identification code;a general description of the process and the control equipment; the pollutant or diluent being monitored;the manufacturer,model number, and serial number of each portable monitor;the operating principles of each portable monitor; and a schematic of the CEM system showing the sample acquisition point and the location of the monitors while sampling. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-106 4. Unit identification code: Fugitives 5. Pollutant(s)or diluent(s)being monitored: VOCs 6.Name of manufacturer: NA 7.Model& serial number:NA 8. I Is this an existing system? Ai Yes No 10. Type: In situ Extractive Dilution Other(specify) AVOs,see below 11. Very briefly explain the measurement design concept of the monitor: At the Marla Compressor Facility,only the fuel conditioning skid will be subject to an NSPS KKK applicability evaluation as the rest of the equipment at the facility is not associated. Since the throughput of the fuel skid is less than 10 MMSCFD, • NSPS KKK regulations do not apply.The fuel conditioning skid will be subject to weekly audio,visual,and olfactory inspections(AVOs)(see e.g.,Section 60.482-2(a)(2)for pumps in light liquid service—the fuel conditioning skid will have a pump in light liquid service). DCP will conduct weekly AVOs for the entire facility as a best management practice. 12. Backup system:NA 13. Compliance shall be demonstrated: Daily Weekly Monthly 4 Other-Quarterly 14. Quality Assurance/Quality Control: A quality assurance/quality control plan for the portable monitor is attached for Division review. The plan is not attached,but will be submitted to the Division by QAQC procedures as specified by the Marla O&M Plan will be followed and documented for each AVO monitoring event. ***** Any test value over the emission limit shall be reported as an excess emission. ***** • Operating Pennit Application COMPLIANCE DEMONSTRATION BY FORM 2000-504 Colorado Department of Public Health and Environment MONITORING MAINTENANCE PROCEDURES Rev 06-95 Air Pollution Control Division • The monitoring of a maintenance procedure may be acceptable as a compliance demonstration method provided a correlation between the procedure and the emission rate of a particular pollutant is established. VOC leak detection programs or fugitive dust control programs are examples of procedures that could be monitored. The correlation shall be established using test data. This correlation shall constitute the certification of the monitoring system. It should be attached for Division approval. If it is not attached,please submit it within 60 days of the startup of the monitoring program. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-106 4. Unit identification code: Fugitives 5. Pollutant(s)being monitored: Fugitive VOC 6. Procedure being monitored: VOC leak detection program 7. Is this an existing maintenance procedure? 8. Implementation date: 09/25/2001 X Yes No 9. Describe the method of monitoring: At the Marla Compressor Facility,only the fuel conditioning skid will be subject to an NSPS KKK applicability evaluation as the rest of the equipment at the facility is not associated. Since the throughput of the fuel skid is less than 10 MMSCFD,NSPS KKK regulations do not apply.The fuel conditioning skid will be subject to weekly audio,visual,and olfactory inspections(AVOs)(see e.g.,Section 60.482-2(a)(2)for pumps in light liquid service—the fuel conditioning skid will have a pump in light liquid service). DCP will conduct weekly AVOs for the entire facility as a best management practice. 10. Compliance shall be demonstrated: Daily Ni Weekly Monthly Other—specify 11. Quality Assurance/Quality Control:• The monitoring program shall be subject to appropriate performance specifications,calibration requirements,and quality assurance procedures. A quality assurance/quality control plan for the monitoring program is attached for Division review. The plan is not attached,but will be submitted to the Division by . ***** Any failure to fulfill a maintenance requirement shall be reported as an excess emission. ***** • Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of BY RECORDKEEPING Rev 06-95 Public Health and Environment • 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: Marla Compressor Station 2. Facility identification code: CO 1230243 3. Stack identification code: P-106 4. Unit identification code: Fugitives 5.Pollutant(s)being monitored: VOCs 6.Material or parameter being monitored and recorded: VOC emission leaks from inline service equipment including connectors,flanges,open ended lines,pump seals,valves and other types of connections. 7. Method of monitoring and recording(see information on back of this page): DCP Midstream will maintain a component record count.A plant inlet gas analysis(extended analysis)will be performed annually as per ASTM Method D6730. VOC emissions are calculated by multiplying the component count,the VOC percentage,the EPA emission factor and 8760 hrs/yr. DCP Midstream monitors facility-wide inline service equipment(connectors,flanges,open ended lines,pump seals,valves and other types)for VOC leaks on a weekly basis by using audio,visual,and olfactory inspections(AVOs). 8. List any EPA methods used: • 9. Is this an existing method of demonstrating 10. Start date: 09/25/2001 compliance? No -\/ Yes 11. Backup system: 12 a. Data collection frequency: Daily 1 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 Midstream currently conducts recordkeeping for the Marla Compressor Station and maintains weekly AVO inspections and documentation of service equipment repairs. DCP Midstream uses an internal database to ensure the recordkeeping in being conducted on the proper frequency and the correct information is being gathered. 14. A proposed format for the compliance certification report and excess emission report is attached. DCP Midstream currently submits compliance certification reports and excess emissions reports to the Colorado Air Pollution Control for this facility as required.The format for these submittals can be found on previous submittals from DCP Midstream. • ***** 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. Operating Permit Application EMISSION UNIT HAZARDOUS AIR POLLUTANTS FORM 2000-600 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division ipSEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code: P-106 4. Unit identification code: Fugitives 5. Unit material description:Natural Gas 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor references. Attached X 1c tuai E:;aissiou,5 J)ata is for calendar .ear J.9 Pollutant CAS Common or GenericAct*Etta Allowable OR Potential to emit Pollutant Name Qum': ; '' Mew` Quantity Measurement [3tts Units 71-43-2 Benzene 0.02 TPY • 108-88-3 Toluene 0.02 TPY 100-41-4 Ethylbenzene 0.00 TPY 1330-20-7 Xylene r 0.00 TPY 110-54-3 n-Hexane 0.00 TPY TOTAL RAPS 0.05 TPY TPY • TPY TPY TPY TPY '' � : TPY • TPY TPY TPY : .. TPY ' .. TPY a , TPY •. _ TPY TPY TPY 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 (19-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Marla Compressor Station 2. Facility identification code:CO 1230243 3. Stack identification code:P-106 4. Unit identification code: Fugitives 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached X Air pollutant Actual Potential to emit Maximum allowable Quantity U TPY U TPY Particulates(TSP) TPY PM-10 l.PY Nitrogen oxides 1 PY Volatile organic compounds 36.02 TPY EPA-453/12- 36.02 95-1117 Carbon monoxide I PY Lead I PY Sulfur dioxide , TPY gootal reduced sulfur TPY Reduced sulfur compounds TPY Hydrogen sulfide TPY Sulfuric Acid Mist TPY Fluorides TPY TPY • TPY - TPY TPY - t Units(U)should be entered as follows: I =lb/hr 2=lb/mtnBTU 3=grains/dscf 4=lb/gallon 5=pptndv 6=grant/HP-hour 7=lb/mmscf • 8=other(specify) 9=other(specify) 10=other(specify) 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: Marla Compressor Station 2.Facility identification code: CO 1230243 3. Stack identification code: P-106 4.Unit identification code: Fugitives 5.Pollutant 6. Colorado Air Quality 7. 8. Limitation 9. Compliance Regulations State Status or Only IN OUT Construction Permit Number VOC 01WE0502& 36.02 X Colorado Regulation No.3, Part A, Section I.B.36.h and Part C,Section III.B.7 and (Minor Mod from August 7, 2009) • 10. Other requirements(e.g.,malfunction reporting,special operating conditions from an State Only Compliance existing permit such as material usage,hours of operation,etc.) Status IN OUT Annual gas analysis(extended analysis) X Recordkeeping Requirements,initial component count,tally of all component additions X and deletions and a running tally maintained. Maintain records of startups shutdowns and malfunctions. X Maintain emission estimates of VOCs per component and weight%VOC content of X gas stream • **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT**** • Operating Permit Application PERMIT SHIELD PROTECTION FORM 2000-605 Colorado Department of Public Health and EnvironmentIDENTIFICATION Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1.Facility name: Marla Compressor Station 2.Facility identification code: CO 1230243 3. Specify Emission Source: P-106 4.Do not use 5. Pollutant, 6. Colorado Air Quality 7. Equipment, Regulations State or Only Process N/A • 8. Other requirements(e.g.,malfunction reporting,special operating conditions State Only from an 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 • �erating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Iorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE I.Facility name:Marla Compressor Station 2.Facility identification code:CO 1230243 3.Stack identification code:P-106 4.Unit identification code:Fugitives 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. X 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 Actions Deadline 1. • 2. 3. Progress reports will be submitted: Start date: and every six(6)months thereafter • • Appendix B Emissions Calculations • a n . 121 , 555555.--00 f o e g%tioa+rl_, l S °000000 0 0 0 _ . . .. 00 m = a mom ___ ik a m o r o o r o 544,,,,n , o r N - O o E - vn..� , r o r H fi COeoo0oo00o T. o o e $ E LT. r„ c00000000 0 o R- , ooa00000 e o 0 VH - °0000000 e o o c 3 0000° .. e ti m — 0 a o - o o — — ; -- s e e 3 o -- a o - a• - m eo.oAwc o Q m __ _ _ Ee ,n ,n M M a 8 _ F's :“000 o �, ., F e a �¢2 6 „rte;,- 505 _ e _ 7 E 4¢`<` et — 7 e �0 00000000 o 0 o r $ '; ..6„, „, ° 0 00 0 e e 5 e e � 00 6 ' °0 0 0 0 0 0 0 e 0 t F .. — rt . . C E„ 00000000 0 0 o e e r z z ouuoc� '_ to _oa:M;.; _ - a = S c _ 6r U r, o' $ o 2 Q �3 3 5 5 3 3. n..8 - v E Eoo3o_= g € , € w° �_2. m-LLuN-'No 0 x 5 .5 5 5 __ _ n m;.'2' AL IA F "M x , se,- .vg, IA di Engine Emission Calculations • Maria Compressor Station DCP Midstream,LP Waukesha L 7042 GSI Engine C-148 4 Stroke,Rich Burn,with NSCR Unit Rating: 1,478 hp BSFC: 7,830 btu/hp-hr Maximum Heat Input: 11.57 mmbtu/hr Operating Schedule: 8,760 hr/yr FHV: 1,200 btu/scf Maximum Fuel Use: 84.48 mmscf/yr Criteria Pollutant Emission Calculations Uncontrolled Controlled Emission Factors Emissions Emission Factors Potential Emissions Pollutant Ib/MMBTU (ton/yr) lb/MMBTU (ton/yr) NOx° 11.0 g/bhp-hr 3.10 156.99 3.0 g/bhp-hr 0.84 42.82 CO° 8.0 g/bhp-hr 2.25 114.18 3.0 g/bhp-hr 0.84 42.82 VOC° 1.5 q/bhp-hr 0.42 21.41 1.0 g/bhp-hr 0.28 14.27 SO2b 5.88E-04 lb/mmBtu 5.88E-04 0.03 5.88E-04 lb/mmBtu 5.88E-04 0.03 PM° 9.50E-03 lb/mmBtu 9.50E-03 0.48 9.50E-03 lb/mmBtu 9.50E-03 0.48 e Manufacturer's emissions factors b Uncontrolled emission factors from 4-stroke,Rich-burn(45RB)engines from AP-42,Chapter 3,Table 3.2-3,(7/00). Non-Criteria Reportable Pollutant Calculations Potential Control Controlled Emissions Efficiency Emissions De Minimis` • Pollutant HAP Emission factors b Data Source pbtyr) % (lb tyr) Bin (Ib/yr) 1,1,2,2-Telrachloroelhane 2.53E-0516/mmBtu EPA 2.56 50% 1.28 A 50 1,1,2-Trichloroethane <1.53E-05 lb/mmBtu EPA <1.55 50% 0.78 A 50 1,1 Dichloroethane <1.13E-05 lb/mmBtu EPA <0.36 50% 0.18 B 500 1,2 Dichloroethane <1.13E-05 lb/mmBtu EPA <0.36 50% 0.18 A 50 1,2 Dichloropropane <1.30E-05 lb/mmBtu EPA <0.41 50% 0.20 A 50 1,3-Butadiene 6.63E-04 lb/mmBtu EPA 67.21 50% 33.61 A 50 1,3-Dichloropropene <1.27E-05 lb/mmBtu EPA <1.29 50% 0.64 A 50 Acetaldehyde 2.79E-03 lb/mmBtu EPA 282.85 50% 141.42 A 50 Acrolein 2.63E-03 lb/mmBtu EPA 266.63 50% 133.31 A 50 Benzene 1.58E-03 lb/mmBtu EPA 160.18 50% 80.09 A 50 Carbon Tetrachloride <1.77E-05 lb/mmBtu EPA <1.79 50% 0.90 A 50 Chlorobenzene <1.29E-05 lb/mmBtu EPA <1.31 50% 0.65 A 50 Chloroform <1.37E-05 lb/mmBtu EPA <1.39 50% 0.69 A 50 Ethylbenzene <2.48E-05 lb/mmBtu EPA <2.51 50% 1.26 C 1000 Ethylene Dibromide <2.13E-05 lb/mmBtu EPA <2.16 50% 1.08 A 50 Formaldehyde 2.05E-02 lb/mmBtu EPA 2078.28 76% 498.79 A 50 Methanol 3.06E-03 lb/mmbtu EPA 310.22 50% 155.11 C 1000 Methylene Chloride 4.12E-05 lb/mmBtu EPA 4.18 50% 2.09 A 50 Naphthalene <9.71E-05lb/mmBtu EPA <9.84 50% 4.92 C 50 PAH 1.41E-04 lb/mmBtu EPA 14.29 50% 7.15 A 50 Styrene <1.19E-05 lb/mmBtu EPA <1,21 50% 0.60 C 1000 Toluene 5.58E-04 lb/mmBtu EPA 56.57 50% 28.28 C 1000 Vinyl Chloride <7.18E-06 lb/mmBtu EPA <0.73 50% 0.36 A 50 Xylenes(m,p,o) 1.95E-04 lb/mmBtu EPA 19.77 50% 9.88 C 1000 - TOTAL 0.0324537 lb/mmBtu - <3288 <1103 -- — ° Uncontrolled emission factors from 4-stroke,Rich-burn(4SRB)engines from AP-42,Chapter 3,Table 3.2-3,(7/00). ° Deminimis levels for reportable non-criteria pollutants,per Colorado Regulation No.3. • DCP Midstream,LP 4/27/2011 Engine Emission Calculations Marla Compressor Station • DCP Midstream,LP Waukesha L 7042 GSI Engine C-135 4 Stroke,Rich Burn,with NSCR Unit Rating: 1.478 hp BSFC: 7,830 btu/hp-hr Maximum Heat Input: 11.57 mmbtu/hr Operating Schedule: 8.760 hr/yr FHV: 1,200 btu/scf Maximum Fuel Use: 84.48 mmscf/yr Criteria Pollutant Emission Calculations Uncontrolled Controlled Emission Factors Emissions Emission Factors Potential Emissions Pollutant lb/MMBTU (ton/yr) lb/MMBTU (ton/yr) NOx° 11.0 g/bhp-hr 3.10 156.99 2.0 g/bhp-hr 0.56 28.54 CO° 8.0 q/bhp-hr 2.25 114.18 3.0 g/bhp-hr 0.84 42.82 VOC a 1.5 g/bhp-hr 0.42 21.41 1.0 g/bhp-hr 0.28 14.27 502° 5.88E-04 lb/mmBtu 5.88E-04 0.03 5.88E-04 lb/mmBtu 5.88E-04 0.03 PM° 9.50E-03 lb/mmBtu 9.50E-03 0.48 9.50E-03 lb/mmBtu 9.50E-03 0.48 a Manufacturer's emissions factors °Uncontrolled emission factors from 4-stroke.Rich-burn(4SRB)engines from AP-42,Chapter 3,Table 3.2-3,(7/00). Non-Criteria Reportable Pollutant Calculations Potential Control Controlled Emissions Efficiency Emissions De Minimis` • Pollutant HAP Emission factors° Data Source (lb/yr) % (lb/yr) Bin (lb/yr) 1,1,2,2-Tetrachloroethane 2.53E-05 lb/mmBtu EPA 2.56 50% 1.28 A 50 1,1,2-Trichloroethane <1.53E-05 lb/mmBtu EPA <1.55 50% 0.78 A 50 1,1 Dichloroethane <1.13E-05 lb/mmBtu EPA <0.36 50% 0.18 B 500 1,2 Dichloroethane <1.13E-05 lb/mmBtu EPA <0.36 50% 0.18 A 50 1,2 Dichloropropane <1.30E-05 lb/mmBtu EPA <0.41 50% 0.20 A 50 1,3-Butadiene 6.63E-04 lb/mmBtu EPA 67.21 50% 33.61 A 50 1,3-Dichloropropene <1.27E-05 lb/mmBtu EPA <1.29 50% 0.64 A 50 Acetaldehyde 2.79E-03 lb/mmBtu EPA 282.85 50% 141.42 A 50 Acrolein 2.63E-03 lb/mmBtu EPA 266.63 50% 133.31 A 50 Benzene 1.58E-03 lb/mmBtu EPA 160.18 50% 80.09 A 50 Carbon Tetrachloride <1.77E-05 lb/mmBtu EPA <1.79 50% 0.90 A 50 Chlorobenzene <1.29E-05 lb/mmBtu EPA <1.31 50% 0.65 A 50 Chloroform <1.37E-05 lb/mmBtu EPA <1.39 50% 0.69 A 50 Ethylbenzene <2.48E-05 lb/mmBtu EPA <2.51 50% 1.26 C 1000 Ethylene Dibromide <2.13E-05 lb/mmBtu EPA <2.16 50% 1.08 A 50 Formaldehyde 2.05E-02 lb/mmBtu EPA 2078.28 76% 498.79 A 50 Methanol 3.06E-03 lb/mmBtu EPA 310.22 50% 155.11 C 1000 Methylene Chloride 4.12E-05 lb/mmBtu EPA 4.18 50% 2.09 A 50 Naphthalene <9.71E-05 lb/mmBtu EPA <9.84 50% 4.92 C 50 PAH 1.41E-04 lb/mmBtu EPA 14.29 50% 7.15 A 50 Styrene <1.19E-O5 lb/mmBtu EPA <1.21 50% 0.60 C 1000 Toluene 5.58E-O4 lb/mmBlu EPA 56.57 50% 28.28 C 1000 Vinyl Chloride <7.18E-06 lb/mmBtu EPA <0.73 50% 0.36 A 50 Xylenes(m,p,o) 1.95E-04 lb/mmBtu EPA 19.77 50% 9.88 C 1000 TOTAL 0.0324537 lb/mmBtu — <3288 <1103 -- — °Uncontrolled emission factors from 4-stroke,Rich-burn(4SRB)engines from AP-42,Chapter 3.Table 3.2-3,(7/00). Deminimis levels for reportable non-criteria pollutants,per Colorado Regulation No.3. • DCP Midstream,LP 4/27/2011 Engine Emission Calculations Marla Compressor Station • DCP Midstream,LP Waukesha L 7042 GSI Engine C-151 4 Stroke,Rich Burn,with NSCR Unit Rating: 1.478 hp BSFC: 7,830 btu/hp-hr Maximum Heat Input: 11.57 mmbtu/hr Operating Schedule: 8,760 hr/yr FHV: 1,200 btu/scf Maximum Fuel Use: 84.48 mmscf/yr Criteria Pollutant Emission Calculations Uncontrolled Controlled Emission Factors Emissions Emission Factors Potential Emissions Pollutant Ib/MMBTU (ton/yr) lb/MMBTU (ton/yr) NOx' 11.0 g/bhp-hr 3.10 156.99 1.0 g/bhp-hr 0.28 14.27 CO a 8.0 g/bhp-hr 2.25 _ 114,18 2.0 g/bhp-hr 0.56 28.54 VOC° 1.5 g/bhp-hr 0,42 21.41 0.7 q/bhp-hr 0.20 9.99 SO26 5,88E-04 lb/mmbtu 5.88E-04 0.03 5.88E-04 lb/mmBtu 5.88E-04 0.03 PM° 9.50E-03 lb/mmbtu 9.50E-03 0.48 9.50E-03 lb/mmBtu 9.50E-03 0,48 ' Manufacturer's emissions factors °Uncontrolled emission factors from 4-stroke,Rich-burn(4SRB)engines from AP-42,Chapter 3,Table 3.2-3,(7/00). Non-Criteria Reportable Pollutant Calculations Potential Control Controlled Emissions Efficiency Emissions De Minimis c • Pollutant HAP Emission factors b Data Source (lb/yr) % (lb/yr) Bin (Ib/yr) 1,1,2,2-Telrachloroethane 2.53E-05 lb/mmBtu EPA 2.56 50% 1.28 A 50 1,1,2-Trichloroethane <1.53E-05 lb/mmBtu EPA <1.55 50% 0.78 A 50 1,1 Dichloroethane <1,13E-05 lb/mmBlu EPA <0.36 50% 0.18 B 500 1,2 Dichloroethane <1.13E-05 lb/mmBlu EPA <0.36 50% 0.18 A 50 1,2 Dichloropropane <1.30E-05 lb/mmBtu EPA <0.41 50% 0.20 A 50 1,3-Butadiene 6.63E-04 lb/mmBtu EPA 67.21 50% 33.61 A 50 1,3-Dichloropropene <1.27E-05 lb/mmBtu EPA <1.29 50% 0.64 A 50 Acetaldehyde 2.79E-03 lb/mmBlu EPA 282.85 50% 141.42 A 50 Acrolein 2.63E-03 lb/mmBtu EPA 266.63 50% 133.31 A 50 Benzene 1.58E-03 lb/mmBtu EPA 160.18 50% 80.09 A 50 Carbon Tetrachloride <1.77E-05 lb/mmBtu EPA <1.79 50% 0.90 A 50 Chlorobenzene <1.29E-05 lb/mmBtu EPA <1.31 50% 0.65 A 50 Chloroform <1.37E-05 lb/mmBtu EPA <1.39 50% 0.69 A 50 Ethylbenzene <2.48E-05 lb/mmBtu EPA <2.51 50% 1,26 C 1000 Ethylene Dibromide <2.13E-05 lb/mmBtu EPA <2.16 50% 1.08 A 50 Formaldehyde 2.05E-02 lb/mmBtu EPA 2078.28 76% 498.79 A 50 Methanol 3.06E-03 lb/mmBtu EPA 310.22 50% 155.11 C 1000 Methylene Chloride 4.12E-05 lb/mmBtu EPA 4.18 50% 2.09 A 50 Naphthalene <9.71E-05 lb/mmBlu EPA <9.84 50% 4.92 C 50 PAH 1.41E-04 lb/mmBtu EPA 14.29 50% 7.15 A 50 Styrene <1.19E-05 lb/mmBlu EPA <1.21 50% 0.60 C 1000 Toluene 5.58E-04 lb/mmBtu EPA 56.57 50% 28.28 C 1000 Vinyl Chloride <7.18E-06 lb/mmBlu EPA <0.73 50% 0.36 A 50 Xylenes(m,p,o) 1.95E-04 lb/mmBtu EPA 19.77 50% 9.88 C 1000 TOTAL 0.0324537 lb/mmBtu - <3288 <1103 -- -- °Uncontrolled emission factors from 4-stroke.Rich-burn(4SRB)engines from AP-42,Chapter 3,Table 3.2-3,(7/00). °Deminimis levels for reportable non-criteria pollutants,per Colorado Regulation No.3 • DCP Midstream,LP 4/27/2011 Engine Emission Calculations • Marla Compressor Station DCP Midstream,LP Waukesha L 7044 GSI Engine C-166 4 Stroke,Rich Burn,with NSCR Unit Rating: 1,680 hp BSFC: 7,860 btu/hp-hr Maximum Heat Input: 13.21 mmbtu/hr Operating Schedule: 8,760 hr/yr FHV: 1,200 btu/scf Maximum Fuel Use: 96.40 mmscf/yr i Criteria Pollutant Emission Calculations Uncontrolled Controlled Emission Factors Emissions Emission Factors Potential Emissions - Pollutant lb/MMBTU (ton/yr) lb/MMBTU (ton/yr) NON' 11.0 g/bhp-hr 3.09 178.45 2.0 g/bhp-hr 0.561 32.45 CO° 8.0 9/bhp-hr 2.24 129.78 2.0 g/bhp-hr 0.561 32.45 VOC° 1.5 g/bhp-hr 0.42 24.33 1.0 g/bhp-hr 0.28 16.22 Soi° 5.88E-04 Ib/mmbtu 5.88E-04 0.03 5.88E-04 lb/mmBtu 5.88E-04 0.03 PM° 9.50E-03 Ib/mmbtu 9.50E-03 0.55 9.50E-03 lb/mmBtu 9.50E-03 0.55 a Manufacturers emissions factors b Uncontrolled emission factors from 4-stroke.Rich-burn(4SRB)engines from AP-42,Chapter 3,Table 3.2-3,(7/00). Non-Criteria Reportable Pollutant Calculations Potential Control Controlled Emissions Efficiency Emissions De Minimis` • Pollutant HAP Emission factors° Data Source (Iblyr) % (lb/yr) Bin (Ib/yr) 1,1,2,2-Tetrachloroethane 2.53E-05 Ib/mmBtu EPA 2.93 50% 1.46 A 50 1,1,2-Trichloroethane <1.53E-05 lb/mmBtu EPA <1.77 50% 0.88 A 50 1,1 Dichloroethane <1.13E-05 Ib/mmBtu EPA <0.36 50% 0.18 B 500 1,2 Dichloroethane <1.13E-05 Ib/mmBtu EPA <0.36 50% 0.18 A 50 1,2 Dichloropropane <1.30E-05 Ib/mmBtu EPA <0.41 50% 0.20 A 50 1,3-Butadiene 6.63E-04 lb/mmBtu EPA 76.69 50% 38.35 A 50 1,3-Dichloropropene <1.27E-05 Ib/mmBtu EPA <1.47 50% 0.73 A 50 Acetaldehyde 2.79E-03 lb/mmBtu EPA 322.74 50% 161.37 A 50 Acrolein 2.63E-03 lb/mmBtu EPA 304.23 50% 152.11 A 50 Benzene 1.58E-03 lb/mmBtu EPA 182.77 50% 91.38 A 50 Carbon Tetrachloride <1.77E-05 lb/mmBtu EPA <2.05 50% 1.02 A 50 Chlorobenzene <1.29E-05 lb/mmBtu EPA <1.49 50% 0.75 A 50 Chloroform <1.37E-05 lb/mmBtu EPA <1.58 50% 0.79 A 50 Ethylbenzene <2.48E-05 lb/mmBtu EPA <2.87 50% 1.43 C 1000 Ethylene Dibromide <2.13E-05 lb/mmBtu EPA <2.46 50% 1.23 A 50 Formaldehyde 2.05E-02 lb/mmBtu EPA 2371.35 76% 569.12 A 50 Methanol 3.06E-03 lb/mmBtu EPA 353.97 50% 176.98 C 1000 Methylene Chloride 4.12E-05 Ib/mmbtu EPA 4.77 50% 2.38 A 50 Naphthalene <9.71E-05 lb/mmBtu EPA <11.23 50% 5.62 C 50 PAH 1.41E-04 lb/mmBtu EPA 16.31 50% 8.16 A 50 Styrene <1.19E-05 lb/mmBtu EPA <1.38 50% 0.69 C 1000 Toluene 5.58E-04 lb/mmBtu EPA 64.55 50% 32.27 C 1000 Vinyl Chloride <7.18E-06 lb/mmBtu EPA <0.83 50% 0.42 A 50 Xylenes(m,p,o) 1.95E-04 lb/mmBtu EPA 22.56 50% 11.28 C 1000 TOTAL 0.0324537 lb/mmEttu — <3751 <1259 — — ° Uncontrolled emission factors from 4-stroke,Rich-burn(4SRB)engines from AP-42,Chapter 3,Table 3.2-3,(7/00). ° Deminimis levels for reportable non-criteria pollutants,per Colorado Regulation No.3 0 DCP Midstream,LP 4/27/2011 Engine Emission Calculations Marla Compressor Station • DCP Midstream,LP Waukesha L 7044 GSI Engine C-174 4 Stroke,Rich Burn,with NSCR Unit Rating: 1,680 hp BSFC: 7,860 btu/hp-hr Maximum Heat Input: 13.21 mmbtu/hr Operating Schedule: 8,760 hr/yr FHV: 1,200 btu/scf Maximum Fuel Use: 96.40 mmscf/yr Criteria Pollutant Emission Calculations Uncontrolled Controlled Emission Factors Emissions Emission Factors Potential Emissions - -. Pollutant lb/MMBTU (ton/yr) Ib/MMBTU (ton/yr) NOXa 11.0 g/bhp-hr 3.09 178.45 2.0 g/bhp-hr 0.561 32.45 CO' 8.0 g/bhp-hr 2.24 129.78 2.0 g/bhp-hr 0.561 32.45 VOC° 1.5 g/bhp-hr 0.42 24.33 1.0 g/bhp-hr 0.28 16.22 SO2 b 5.88E-04 lb/mmbtu 5.88E-04 0.03 5.88E-04 lb/mmBtu 5.88E-04 0.03 PM° 9.50E-03 lb/mmbtu 9.50E-03 0.55 9.50E-03 lb/mmBtu 9.50E-03 0.55 ° Manufacturers emissions factors °Uncontrolled emission factors from 4-stroke,Rich-burn(4SRB)engines from AP-42,Chapter 3,Table 3.2-3,(7/00). Non-Criteria Reportable Pollutant Calculations Potential Control Controlled Emissions Efficiency Emissions De Minimis` . Pollutant HAP Emission factors" Data Source (lb/yr) % (lb/yr) Bin (lb/yr) 1,1,2,2-Tetrachloroethane 2.53E-O5 lb/mmBlu EPA 2.93 50% 1.463 A 50 1,1,2-Trichloroethane <1.53E-05 lb/mmBtu EPA <1,77 50% 0.885 A 50 1,1 Dichloroethane <1.13E-05 lb/mmBtu EPA <0.36 50% 0.178 B 500 1,2 Dichloroethane <1.13E-05 lb/mmBtu EPA <0.36 50% 0.178 A 50 1,2 Dichloropropane <1.30E-05 lb/mmBtu EPA <0.41 50% 0.205 A 50 1,3-Butadiene 6,63E-04 lb/mmBtu EPA 76.69 50% 38.347 A 50 1,3-Dichloropropene <1.27E-05 lb/mmBtu EPA <1.47 50% 0.735 A 50 Acetaldehyde 2.79E-03 lb/mmBtu EPA 322.74 50% 161.368 A 50 Acrolein 2.63E-03 lb/mmBtu EPA 304.23 50% 152.114 A 50 Benzene 1.58E-03 lb/mmBtu EPA 182.77 50% 91.384 A 50 Carbon Tetrachloride <1.77E-05 lb/mmBtu EPA <2,05 50% 1.024 A 50 Chlorobenzene <1.29E-05 lb/mmBtu EPA <1,49 50% 0.746 A 50 Chloroform <1,37E-05 lb/mmBtu EPA <1.58 50% 0.792 A 50 Ethylbenzene <2.48E-05 lb/mmBtu EPA <2.87 50% 1.434 C 1000 Ethylene Dibromide <2.13E-05 lb/mmBtu EPA <2.46 50% 1.232 A 50 Formaldehyde 2.05E-02 lb/mmBtu EPA 2371.35 76% 569.125 A 50 Methanol 3,06E-03 lb/mmBtu EPA 353.97 50% 176.984 C 1000 Methylene Chloride 4.12E-05 lb/mmBtu EPA 4.77 50% 2.383 A 50 Naphthalene <9.71E-05 lb/mmBtu EPA <11.23 50% 5.616 C 50 PAH 1.41E-04 lb/mmBtu EPA 16.31 50% 8.155 A 50 Styrene <1.19E-05 lb/mmBtu EPA <1.38 50% 0.688 C 1000 Toluene 5.58E-04 lb/mmBtu EPA 64.55 50% 32.274 C 1000 Vinyl Chloride <7.18E-06 lb/mmBtu EPA <0.83 50% 0.415 A 50 Xylenes(m,p,o) 1.95E-04 lb/mmBtu EPA 22.56 50% 11.278 C 1000 TOTAL 0.0324537 lb/mmBtu — <3751 <1259 — -- °Uncontrolled emission factors from 4-stroke.Rich-burn(4SRB)engines from AP-42,Chapter 3.Table 3.2-3,(7/00). ° Deminimis levels for reportable non-criteria pollutants,per Colorado Regulation No.3. • DCP Midstream,LP 4/27/2011 Engine Emission Calculations Marla Compressor Station • DCP Midstream,LP Waukesha L 7044 GSI Engine C-174 4 Stroke,Rich Burn,with NSCR Unit Rating: 1,680 hp BSFC: 7,860 btu/hp-hr Maximum Heat Input: 13.21 mmbtu/hr Operating Schedule: 8,760 hr/yr FHV: 1,200 btu/scf Maximum Fuel Use: 96.40 mmscf/yr Criteria Pollutant Emission Calculations Uncontrolled Controlled Emission Factors Emissions Emission Factors Potential Emissions Pollutant lb/MMBTU (ton/yr) lb/MMBTU (ton/yr) NOR' 11.0 g/bhp-hr 3.09 178.45 2.0 g/bhp-hr 0.561 32.45 CO° 8.0 q/bhp-hr 2.24 129.78 2.0 g/bhp-hr 0.561 32.45 VOC° 1.5 g/bhp-hr 0.42 24.33 1.0 g/bhp-hr 0.28 16.22 SO2 b 5.88E-04 lb/mmbtu 5.88E-04 0.03 5,88E-04 lb/mmBtu 5.88E-04 0.03 PM° 9.50E-03 lb/mmbtu 9.50E-03 0.55 9.50E-03 lb/mmBtu 9.50E-03 0.55 8 Manufacturer's emissions factors b Uncontrolled emission factors from 4-stroke,Rich-burn(4SRB)engines from AP-42,Chapter 3,Table 3.2-3,(7/00). Non-Criteria Reportable Pollutant Calculations Potential Control Controlled Emissions Efficiency Emissions De Minimis` • Pollutant HAP Emission factors" Data Source (lb/yr) % (lb/yr) Bin (Ib/yr) 1,1,2,2-Tetrachlorcethane 2.53E-05 lb/mmBtu EPA 2.93 50% 1.46 A 50 1,1,2-Trichloroethane <1.53E-05 Ib/mmBtu EPA <1.77 50% 0.88 A 50 1,1 Dichloroethane <1.13E-05 lb/mmBtu EPA <0.36 50% 0.18 B 500 1,2 Dichloroethane <1.13E-05 lb/mmBtu EPA <0.36 50% 0.18 A 50 1,2 Dichloropropane <1.30E-05 lb/mmBtu EPA <0.41 50% 0.20 A 50 1,3-Butadiene 6.63E-04 lb/mmBtu EPA 76.69 50% 38.35 A 50 1,3-Dichloropropene <1.27E-05 lb/mmBtu EPA <1.47 50% 0.73 A 50 Acetaldehyde 2.79E-03 lb/mmBtu EPA 322.74 50% 161.368 A 50 Acrolein 2.63E-03 lb/mmBtu EPA 304.23 50% 152.114 A 50 Benzene 1.58E-03 lb/mmBtu EPA 182.77 50% 91.38 A 50 Carbon Tetrachloride <1.77E-05 lb/mmBtu EPA <2.05 50% 1.02 A 50 Chlorobenzene <1.29E-05 lb/mmBtu EPA <1.49 50% 0.75 A 50 Chloroform <1.37E-05 lb/mmBtu EPA <1.58 50% 0.79 A 50 Ethylbenzene <2.48E-05 lb/mmBtu EPA <2.87 50% 1.43 C 1000 Ethylene Dibromide <2.13E-05 lb/mmBtu EPA <2.46 50% 1.23 A 50 Formaldehyde 2.05E-02 lb/mmBtu EPA 2371.35 76% 569.12 A 50 Methanol 3.06E-03 lb/mmBtu EPA 353.97 50% 176.98 C 1000 Methylene Chloride 4.12E-05 lb/mmBtu EPA 4.77 50% 2.38 A 50 Naphthalene <9.71E-05 lb/mmBtu EPA <11.23 50% 5.62 C 50 PAH 1.41E-04 lb/mmBtu EPA 16.31 50% 8.16 A 50 Styrene <1.19E-05 lb/mmBtu EPA <1.38 50% 0.69 C 1000 Toluene 5.58E-04 lb/mmBtu EPA 64.55 50% 32.27 C 1000 Vinyl Chloride <7.18E-06 lb/mmBtu EPA <0.83 50% 0.42 A 50 Xylenes(m,p,o) 1.95E-04 lb/mmBtu EPA 22.56 50% 11.28 C 1000 TOTAL 0.0324537 lb/mmBtu -- <3751 <1259 — - °Uncontrolled emission factors from 4-stroke,Rich-burn(4SRB)engines from AP-42,Chapter 3,Table 3.2-3,(7/00). °Deminimis levels for reportable non-criteria pollutants,per Colorado Regulation No.3. 0 DCP Midstream,LP 4/27/2011 Triethylene Dehydration Calculations Marla Compressor Station DCP Midstream, LP • Source ID P-112 Stripping Gas? N Y/N Description Dehydration Unit What is Stripping Gas? N/A Manufacturer Stripping Gas Flow Rate N/A scfm Model 45015PV Condenser? Y Y/N Serial# Condenser Temperature 60 deg F Operation Date Condenser Pressure 14.7 psia Operation 8760 hr/yr Flare? Y Y/N Wet Gas Temperature 80 deg F Flare Ambient Air Temp 60 deg F Wet Gas Pressure 900 psig Flare Excess Oxygen 0 % Wet Gas Water Content saturated IbH2O/MMscf Flare Destruction Efficiency 95 Dry Gas Flow Rate 45 MMscfd Dry Gas Water Content 7.0 IbH2O/MMscf Stack Height ft Lean Glycol Water Content 1.5 wt%H2O Stack Temp. deq F Lean Glycol Flow Rate 6.25 qpm Stack Flow acfm Cold Separator? N Y/N Stack Velocity ft/min Cold Separator Temperature N/A deq F Stack Base ft Cold Separator Pressure __ N/A psig Glycol Pump Make&Model Kimray Latitude deq Glycol Pump Type Electric Elec.or Gas Longitude deg Glycol Pump Gas Flow Rate N/A acfm/qpm or Flash Tank? Y Y/N UTM Zone Flash Tank Temperature 250 deg F UTM Northing m Flash Tank Pressure 125 psiq UTM Easting m Flash Tank Control Combustion Datum Total Emissions from GRI-GLYCaIc 4.0 . Uncontrolled Controlled CAS Emissions Emissions Pollutant Number (lb/hr) (lb/yr) (tpy) (lb/hr) (Ib/yr) (tpy) VOC 83.22 729027.80 364.51 0.64 5640.00 2.82 n-hexane 110-54-3 0.72 6309.80 3.15 0.01 122.20 0.06 Benzene 71-43-2 5.57 48833.40 24.42 0.07 620.00 0.31 Toluene 108-88-3 21.36 187093.60 93.55 0.12 1020.00 0.51 Ethylbenzene 100-41-4 1.68 14683.80 7.34 0.00 40.00 0.02 Xylene 1330-20-7 30.91 270786.60 135.39 0.06 500.00 0.25 Total HAP 0.263 2300 1.15 • • Flash Tank Off Gas Stream Detail from GRI-GLYCaIc 4.0 Description Dehy Flash Tank Vent Recycled Vent Flow Rate 156 scf/hr Hours of operation 8760 hr/yr Annual Flow Rate 1.367 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/Ib-mol) (Ib/Ib-mol) (Btu/scf) (Btu/scf) Methane 38.20 0.3820 16.04 6.13 0.2101 1010.0 385.8 Ethane 15.10 0.1510 30.07 4.54 0.1556 1769.6 267.2 Propane 13.30 0.1330 44.10 5.86 0.2010 2516.1 334.6 i-Butane 3.52 0.0352 58.12 2.05 0.0701 3251.9 114.5 n-Butane 6.14 0.0614 58.12 3.57 0.1223 3262.3 200.3 i-Pentane 1.47 0.0147 72.15 1.06 0.0364 4000.9 58.8 n-Pentane 1.60 0.0160 72.15 1.15 0.0396 4008.9 64.1 n-Hexane 0.46 0.0046 86.18 0.40 0.0136 4755.9 21.8 Cyclohexane 0.99 0.0099 84.16 0.83 0.0286 4481.5 44.4 Other Hexanes 0.74 0.0074 86.18 - 0.64 0.0218 4755.9 35.1 Heptanes 0.26 0.0026 100.20 0.26 0.0088 5502.5 14.1 Methylcyclohexane 0.42 0.0042 98.19 0.41 0.0140 5215.7 21.7 2,2,4-Trimethylpentane 0.005 0.0001 114.23 0.01 0.0002 6231.7 0.3 Benzene 2.23 0.0223 78.11 1.74 0.0597 3741.8 83.4 Toluene 0.48 0.0048 92.14 0.45 0.0153 4475.0 21.7 Ethylbenzene 0.004 0.0000 106.17 0.00 0.0001 5222.2 0.2 Xylenes 0.03 0.0003 318.50 0.08 0.0028 5208.8 1.3 Octanes+ 0.001 0.0000 114.23 0.00 0.0000 6248.9 0.1 84.94 0.8494 29.17 1.00 1670 • Condenser Vent Stream Detail from GRI-GLYCaIc 4.0 Description Dehy Condenser Vent Vent Flow Rate 179 scf/hr Hours of operation 8760 hr/yr Annual Flow Rate 1.568 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/Ib-mol) (Ib/Ib-mol) (Btu/scf) (Btu/scf) Methane 6.90 0.0690 16.04 1.11 0.0303 1010.0 69.7 Ethane 10.90 0.1090 30.07 3.28 0.0898 1769.6 192.9 Propane 10.90 0.1090 44.10 4.81 0.1317 2516.1 274.3 i-Butane 2.19 0.0219 58.12 1.27 0.0349 3251.9 71.2 n-Butane 7.12 0.0712 58.12 4.14 0.1134 3262.3 232.3 i-Pentane 1.39 0.0139 72.15 1.00 0.0275 4000.9 55.6 n-Pentane 2.12 0.0212 72.15 1.53 0.0419 4008.9 84.9 n-Hexane 0.69 0.0069 86.18 0.59 0.0162 4755.9 32.7 Cyclohexane 0.96 0.0096 84.16 0.81 0.0221 4481.5 43.0 Other Hexanes 0.93 0.0093 86.18 0.80 0.0221 4755.9 44.4 Heptanes 0.90 0.0090 100.20 0.90 0.0246 5502.5 49.3 Methylcyclohexane 0.90 0.0090 98.19 0.88 0.0242 5215.7 46.8 2,2,4-Trimethylpentane 0.00 0.0000 114.23 0.00 0.0000 6231.7 0.0 Benzene 3.79 0.0379 78.11 2.96 0.0811 3741.8 141.8 Toluene 5.39 0.0539 92.14 4.97 0.1361 4475.0 241.2 Ethylbenzene 0.14 0.0014 106.17 0.15 0.0041 5222.2 7.3 Xylenes 2.29 0.0229 318.50 7.29 0.1998 5208.8 119.3 Octanes+ 0.01 0.0001 114.23 0.01 0.0003 6248.9 0.6 • 57.51 0.5751 36.50 1.00 1707 Triethylene Dehydration Calculations Marla Compressor Station DCP Midstream, LP • Source ID P-113 Stripping Gas? N Y/N Description Dehydration Unit What is Stripping Gas? N/A Manufacturer Stripping Gas Flow Rate N/A scfm Model 45015PV Condenser? Y Y/N Serial# Condenser Temperature 60 deq F Operation Date Condenser Pressure 14.7 psia Operation 8760 hr/yr Flare? Y Y/N Wet Gas Temperature 80 deq F Flare Ambient Air Temp 60 deq F Wet Gas Pressure 900 psig Flare Excess Oxygen 0 % Wet Gas Water Content saturated IbH2O/MMscf Flare Destruction Efficiency 95 % Dry Gas Flow Rate 45 MMscfd Dry Gas Water Content 7.0 IbH2O/MMscf Stack Height ft Lean Glycol Water Content 1.5 wt%H2O Stack Temp. deg F Lean Glycol Flow Rate 6.25 qpm Stack Flow acfm Cold Separator? N Y/N Stack Velocity ft/min Cold Separator Temperature N/A deq F Stack Base ft Cold Separator Pressure N/A psig Glycol Pump Make&Model Kimray Latitude deg Glycol Pump Type Electric Elec.or Gas Longitude deg Glycol Pump Gas Flow Rate N/A acfm/qpm or Flash Tank? Y Y/N UTM Zone Flash Tank Temperature 250 deq F UTM Northing m Flash Tank Pressure 125 psig UTM Easting m Flash Tank Control Combustion Datum Total Emissions from GRI-GLYCaIc 4.0 • Uncontrolled Controlled CAS Emissions Emissions Pollutant Number (lb/hr) (Ib/yr) (tpy) (lb/hr) (Ib/yr) (tpy) VOC 83.22 729027.80 364.51 0.64 5640.00 2.82 n-hexane 110-54-3 0.72 6309.80 3.15 0.01 122.20 0.06 Benzene 71-43-2 5.57 48833.40 24.42 0.07 620.00 0.31 Toluene 108-88-3 21.36 187093.60 93.55 0.12 1020.00 0.51 Ethylbenzene 100-41-4 1.68 14683.80 7.34 0.00 40.00 0.02 Xylene 1330-20-7 30.91 270786.60 135.39 0.06 500.00 0.25 Total HAP 0.263 2300 1.15 • Flash Tank Off Gas Stream Detail from GRI-GLYCaIc 4.0 • Description Dehy Flash Tank Vent Recycled Vent Flow Rate 156 scf/hr Hours of operation 8760 hr/yr Annual Flow Rate 1.367 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/Ib-mol) (Ib/Ib-mol) (Btu/scf) (Btu/scf) Methane 38.20 0.3820 16.04 6.13 0.2101 1010.0 385.8 Ethane 15.10 0.1510 , 30.07 4.54 0.1556 1769.6 267.2 Propane 13.30 0.1330 44.10 5.86 0.2010 2516.1 334.6 i-Butane 3.52 0.0352 58.12 2.05 0.0701 3251.9 114.5 n-Butane 6.14 0.0614 58.12 3.57 0.1223 3262.3 200.3 i-Pentane 1.47 0.0147 72.15 1.06 0.0364 4000.9 58.8 n-Pentane 1.60 0.0160 72.15 1.15 0.0396 4008.9 64.1 n-Hexane 0.46 0.0046 86.18 0.40 0.0136 4755.9 21.8 Cyclohexane 0.99 0.0099 84.16 0.83 0.0286 4481.5 44.4 Other Hexanes 0.74 0.0074 86.18 0.64 0.0218 4755.9 35.1 Heptanes 0.26 0.0026 100.20 0.26 0.0088 5502.5 14.1 Methylcyclohexane 0.42 0.0042 98.19 0.41 0.0140 5215.7 21.7 2,2,4-Trimethylpentane 0.005 0.0001 114.23 0.01 0.0002 6231.7 0.3 Benzene 2.23 0.0223 78.11 1.74 0.0597 3741.8 83.4 Toluene 0.48 0.0048 92.14 0.45 0.0153 4475.0 21.7 Ethylbenzene 0.004 0.0000 106.17 0.00 0.0001 5222.2 0.2 Xylenes 0.03 0.0003 318.50 0.08 0.0028 5208.8 1.3 Octanes+ 0.001 0.0000 114.23 0.00 0.0000 6248.9 0.1 84.94 0.8494 29.17 1.00 1670 Condenser Vent Stream Detail from GRI-GLYCaIc 4.0 • Description Dehy Condenser Vent Vent Flow Rate 179 scf/hr Hours of operation 8760 hr/yr Annual Flow Rate 1.568 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/Ib-mol) (lb/lb-mol) (Btu/scf) (Btu/scf) Methane 6.90 0.0690 16.04 1.11 0.0303 1010.0 69.7 Ethane 10.90 0.1090 30.07 , 3.28 0.0898 1769.6 192.9 Propane 10.90 0.1090 44.10 4.81 0.1317 2516.1 274.3 i-Butane 2.19 0.0219 58.12 1.27 0.0349 3251.9 71.2 n-Butane 7.12 0.0712 58.12 4.14 0.1134 3262.3 232.3 i-Pentane 1.39 0.0139 72.15 1.00 0.0275 4000.9 55.6 n-Pentane 2.12 0.0212 72.15 1.53 0.0419 4008.9 84.9 n-Hexane 0.69 0.0069 86.18 0.59 0.0162 4755.9 32.7 Cyclohexane 0.96 0.0096 84.16 0.81 0.0221 4481.5 43.0 Other Hexanes 0.93 0.0093 86.18 0.80 0.0221 4755.9 44.4 Heptanes 0.90 0.0090 100.20 0.90 0.0246 5502.5 49.3 Methylcyclohexane 0.90 0.0090 98.19 0.88 0.0242 5215.7 46.8 2,2,4-Trimethylpentane 0.00 0.0000 114.23 0.00 0.0000 6231.7 0.0 Benzene 3.79 0.0379 78.11 2.96 0.0811 3741.8 141.8 Toluene 5.39 0.0539 92.14 4.97 0.1361 4475.0 241.2 Ethylbenzene 0.14 0.0014 106.17 0.15 0.0041 5222.2 7.3 Xylenes 2.29 0.0229 318.50 7.29 0.1998 5208.8 119.3 Octanes+ 0.01 0.0001 114.23 0.01 0.0003 6248.9 0.6 57.51 0.5751 36.50 1.00 1707 Fugitive Emissions From Equipment Leaks Marla Compressor Station • DCP Midstream,LP Component Type Light Uqt W. Gee Total Connections 454 s 556 1010 Flanges 37 295 327 Open-Ends 0 0 Pumps 25 0 25 Valves 734 815 1549 "Others' 11 53 64 TOTALS . 195E, - 1.',,......17R[:.:::; 2079 il610ib4'" im�alen Mliula► siuf Emission a. Pallltl/(Ill Plato Ras Ito* Kato � N �[i1dd Oaia F WNW t;as 0041180INNrtTip. • :III'. be .f,..,...S'.0=1 MOW ONl tor Connections 0.0002 0.0002 0.210 0.24 0.92 1.07 Flanges 0.0001 0.0004 0.008 0.25 0.03 1.11 Open-Ends 0.0014 0.0020 0.000 0.00 0.00 0.00 Pumps 0.0130 0.0024 0.715 0.00 3.13 0.00 Valves 0.0025 0.0045 4.037 8.07 17.68 35.34 "Others" 0.0075 0.0088 0.182 1.03 0.79 4.49 4201 y Gas Analysis tool.Wt MoM!i r, •..,;1.:" Wt.% ZOrlrcMd Gee ConeStiv nt 1b morel. 0.101%,.;..... • —Oast (Wt%) • ' '...,.111,1• - Me:iare 16.01 74.730 11.9643 54.97 58.33% Et a n e 30.02 13.082 3.9273 18.04 _ 19.15% Tot.Meth/Eth - 87.813 15.8916 73.0 77.48% Propane 44.03 6.041 2.6599 12.22 12.97% i-Butane 58.04 0.689 0.3997 1.84 1.95% n-Butane 58.04 1.629 0.9456 4.34 4.61% i-Pentane 72.05 0.308 0.2216 1.02 1.08% n-Pentane 72.05 0.303 0.2182 1.00 1.06% Other Hexanes+ 86.06 0.188 0.1620 0.74 0.79% n-Hexane 86.00 0.000 0.0000 0.00 0.00% Borzene 78.11 0.009 0.0068 0.03 0.03% Toluene 92.14 0.005 0.0049 0.02 0.02% Ethybenzene 106.17 0.000 0.0002 0.00 0.00% Xylenes 106.17 0 001 0.0008 0.00 0.00% Total VOC 9.173 4.6197 21.22 - 22.52% Carbon Dioxide 43.99 2.560 1.1261 5.17 Helium 4.00 0.010 0.0004 0.00 Oxygen 31.98 0.000 0.0000 0.00 Nitroen 28.02 0.460 0.1259 0.59 MJ $8100 / NOTE:Analyses based on C6 analyses from each location. The worst case C6+values were taken from an extended anlaysis at Scott Booster Station. Those vaiues were combined with the individual gas analyses and then normalized to come up with a worst case a DCP Mdstream,LP 4/27/2011 Gas Service Speciation Light Liquid Service Specladon • • EIW!lIOE Ibtp Weeks,Pens Component WlIEe% Wier- 1B! Component %PIM% MOO Wy Nitrogen 0.0000 0.00 WOW, 0.00 0.00 Methane 58.33% 5.5952 24.51 Methane 0.00 0.00 Carbon Dioxide 0.0000 0.0000 Carbon Goode 0.00 000 Ethane 19 15% 1.8360 8.0446 Ethane 0.00 000 Hydrogen Sulfide 0.00% 0.0000 0.0000 Hydrogen Sulfide 0.00 0.00 Propane 12.97% 12439 5.4483 Propane 99.94% 5.15 22.55 l-Butane 195% 0.1869 0.8188 i-Butane 0.00 0.00 n-Butane 461 0 0.4422 1.9369 n-Butane 0.00 0.00 I-Pentane 1.08% 0.1036 0.4540 i-Pentane 0.00 0.00 n-Pentane 1.06% 0.1020 0.4469 n-Pentane 0.00 0.00 Other Hexanese 0.79% 0.0157 0.3318 Other Hexanes, 0.00 0.00 n-Hexane 0.00% 0.0000 00000 n-Hexane 000% 0.00 0.00 Benzene 0.03% 00032 0.0139 Benzene 003% 0.00 0.01 Toluene 0.02% 00023 0.0100 Toluene 002% 0.00 0.01 Ethylbenzene 0.00% 0.0001 0.00043 EthNbenzene 0.00% 0.00 0.00 Xylene(m,9,o) 000% 0.0004 0.0017 Xylenes0,p,o) 0.00% 0.00 0.00 TO 0 0.0261 T . 0.07 2. 040 011 22.50 TOW 9 42.01 MOM 5.15 +.56 TOM*Nadeau Total Emissions P46&AM Grand Totals NOW.:...: kt5. Meths _..IIMIY. 65! Total HAP% 0.01 0.04 0.01 90 0.05 Total VOC 7.31 32.02 8.22 12,040 36.02 n-Hexane 0.00 000 0.00 0 0.00 Benzene 0.00 002 0.01 48 0.02 Toluene 000 0.02 0.00 35 0.02 Ethylbenzene 000 0.00 0.00 2 0.00 Xylenes 0.00 0.00 0.00 6 0.00 ei component ooum bayed upon API Publlcauon eves(Table 41.nd API Puutr.don 4015(Table s) BI EPA am legion factors obtained from P.ctop0I lo.Eampm nt L.ala EmISSIOn.EellnI•48^EPA Publlcauon no.4s3taaswT • • DCP Mldsceam.LP 4/27/2011 Insignificant Emissions Marla Compressor Station • DCP Midstream,LP NCO CO VOC Daus$tldu h,slgecad Plc (ten) goy) Wh) Peewee 1,000 gal,Methanol tank Regulation No.3.Part A.Section II.D.1.a --- --- 0.02 TANKS 4.0.9d 300 bbl Methanol tank Regulation No.3,Part A,Section II D.1.a --- -- 0.20 TANKS 4.0.9d 1.000 gal Lube oil tank Regulation No.3,Part C,Section II.E.3.aaa --- --- neq. 210 bbl,Lube oil tank Regulation No.3,Part C.Section II.E.3.aaa -- -- neg. 1,000 gal TEG glycol tank Regulation No.3,Part A,Section IID.1.a --- --- neg. 1,000 gal Norkool glycol tank Regulation No.3.Part A,Section II.D.1.a --- --- neq. 20 bbl slop oil tank Regulation No.3,Part A,Section II.D.1.a --- --- neg. 30,000 gal Pressurized Condensate Storage Tank Regulation No.3,Part A,Section II.D.1 zz -- --- neg. N/A-Not a source of emissions 30,000 gal Pressurized Condensate Storage Tank Regulation No.3,Part A,Section II.D.1 n --- -- neg. N/A-Not a source of emissions Pressunzed Condensate Truck Loadout Regulation No.3,Part A,Section IID.1.a --- --- 0.33 Engineering Estimate Dehy Reboiler H-112 Regulation No.3,Part A.Section II.D.1.a 0.36 0.30 0.02 AP-42 Section 1.4,Table 1.4-1 Dehy Reboiler H-113 Regulation No.3,Part A,Section IID.1 0.42 0.35 0.02 AP-42 Section 1.4,Table 1.4-2 20 bbl,Stormwater tank Regulation No.3,Part A,Section II.D.1.a -- -- neg. 80 bbl,Stormwater tank Regulation No.3,Part A,Section II.D.1.a -- -- neg. 80 bbl,Stormwater tank Regulation No.3,Part A,Section IID.1 --- --- neg. 80 bbl,Stormwater tank Regulation No.3,Part A.Section II.D.La -- -- neg. 80 bbl,Stormwater tank Regulation No.3,Part A,Section IID.1 --- --- neg. 80 bbl,Produced Water Tank Regulation No.3,Part A,Section II.D.1.a -- — 0.10 PS Memo 09-02 80 bbl,Produced Water Tank Regulation No.3,Part A,Section IID.1 --- --- 0.10 PS Memo 09-02 80 bbl,Produced Water Tank Regulation No.3.Part A.Section II.D.1.a -- — 0.10 PS Memo 09-02 80 bbl,Produced Water Tank Regulation No.3,Part A,Section II.D.1 --- --- 0.10 PS Memo 09-02 110 bbl,Produced Water Tank Regulation No.3,Part A,Section II.D.1.a -- — 0.10 PS Memo 09-02 TNRCC Flares and Vapor Oxidizers,Table 4 Condenser Combustor Regulation No.3,Part A,Section IID.1 0.43 1.52 --- Flare Factors 0-148 vent blowdown Regulation No.3.Part A,Section II.D.La -- — 0.18 Engineering Estimate C-135 vent blowdown Regulation No.3,Part A,Section IID.1 --- --- 0.18 Engineering Estimate C-151 vent blowdown Regulation No.3,Part A.Section II.D.1.a -- — 0.18 Engineering Estimate C-166 vent blowdown Regulation No.3,Part A,Section IID.1 --- -- 0.18 Engineering Estimate C-174 vent blowdown Regulation No.3,Part A,Section II.0.1.a --- -- 0.18 Engineering Estimate C-176 vent blowdown Regulation No.3,Part A,Section II.D.1.a --- -- 0.18 Engineering Estimate Total Insignificant Emissions 1.21 2.18 2.18 • 'There is a blowdown vent for each compressor so each is a separate emission point with estimated emissions of 0.18 tpy VOC each • 0 N • N a rtz x c w a n n o 0 0 .2t...66666 E w a, ^ 2 O_ O O O 0 0 0 ` in N 0 w O 0 0 0 0 0 `O m m m 0 0 c r) v O v O v1 n h b h 0 O v)O h n n e v)o N 0 000) 00 Q - q0) 000000000000000000 oN n a o 0 o w a :222P2'222222:422222w m m m a w o m w( V O 2. T_T T_T N F , ) • > ' C v: N 17< O ��.. W v d . . .. . ,- ,-0,- UJ'. �-4J N(V r r t7 Ip N r-N ,- N L Qvv. ee 0 m m m m m m 0 a a a a f H H H H F N Q Q Q p O V V d C O V C V d d d<< V V d a V<C V d d O 0 0 0 0 ' .-- 0 C C C00000 = 000000 = 0000 m `0 0 0 0 `o_ t: 02299 CC 22 .9202922292222222 0 O N N N N N Ny WOW oONin Nt/)W N N N N0NNWf/1N N V) y dN Nd N Nd N N dN N N N N N Nd Nd N N N N N N N N N N q d d W d d d d d d d d d d d d d d d d d d d d P 04 << a < 0 C << < < < << < <<<< < <<< < C4 < << < Q :E :65, U U ' t t t t t u u u u u u u o o t t G t t t t e 0.- -5-4-_-U � 32M222 '622222 2222222M222E222222 2 ill t22222 2 2 2 2 m t 2 2 2 2 M 222222222222222222 o 222=m uaaan .t U , aaaaa aaaaaaaaanaaaaaaan a e . 0)O,-0 o O C) m N o `r°' O 0 0 0 0 0 0 m o 0 0 0 0 00 o a o 0 0 0 0 0 0 0 0 0 0 = . o0r ryo Co .'4 o Co 'm ww w wcj ww wwww w wwww wwwwwww 01- t• 0 CCO40 —. .1?—.0o N d <0oo00d t0 °JN.dO OC)OJNO do N u O O a E 'E N 1� N N r' 66 ..-.- 6 t7 °J c 't w W w v v v v v v v v v v v v v v v v v v a z a — m o O T m w a O f.1 . _v 0) C C O 0) E m W N N q I d 1 y T O W C 0 uJ E - v m m m m c 0 ° I- 0 a w c m zd CVC � v '6 NJ V = vt $ wi C i E • m m E .. , .m. m o '? � F,-.`.1230, 0c m m 5 o J K a ` m w 0) . .m. 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SCl 1C 0 0 V ; O-S e O 000 2 0 q N 1J o (02 N %f�aaamm mmmoplLu =a 0- r O pt 0 O 2O 0 D a Oa U oz O> w a 2 mmOWz ca ter- ZC O Pressurized Condensate Truck Loadout Emissions Marla Compressor Station DCP Midstream,LP • Calculation of VOC Emissions from Truck Loading Hoses Assumptions: There are two hoses connected to each truck during loadout. Liquid Hose Diameter = 2 inches(average) Vapor Hose Diameter = 2 inches(worst case) 'Liquid Hose Length = 1 feet(average) 'Length accounts for length of 'Vapor Hose Length = 1 feet(worst case) isolation valve on pressurized hose. Liquid Hose Volume = 0.0218 cubic feet Vapor Hose Volume = 0.0218 cubic feet Specific Gravity of liquid loaded Vapor Molecular Weight of liquid loaded Ibs/Ibmol Each truck is pressurized to storage tank pressure as listed below. Condensate Tank Pressure= 97.0 psig 109.2 psia Each condensate tank truck has a capacity of 7000 gallons per load. Tot volume of products loaded/year and tot.loadout events/year as listed below. Product Gallon/Month Loads/Month Condensate 432,203 61.74 Annual throughput of 2.8 MMgal/yr 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(psia) V=volume of hoses(cubic feet) n=number of Ibmoles of product in hoses R=Universal Gas Constant=10.73 cubic feet'psi/Ibmole'deg R • T=ave.loadout temp. = 60 deg F = 519.67 deg R Vapor Density n(Ibmoie/ft3) MW(Ib/Ibmole) Vapor Density(lb/63) Condensate 0.0196 ' 32.4 = 0.6345 Liquid Density of Density Liquid Density Specific Gravity Water(lb/gal) (gal/ft3) (Ib/ft3) Condensate 0.65 8.3300 7.48 40.50 VOC Emissions from Liquid Hoses Loaded Liq.Density Hose Vol. Loads Per Emission Emission Product Ib/ft3 ft3/loatl Month Iblmonth Iton/month) Condensate 40.50 0.0218 61.74 54.53 0.03 Total 54.53 0.03 VOC Emissions from Vapor Return Hoses Loaded Vap.Density Hose Vol. Loads Per Emission Emission Product Ib/ft3 ft3/load Month Ib/month Iton/monthl Condensate 0.6345 0.0218 61.74 0.85 0.00 Total -- -- -- 0.85 0.00 MONTHLY VOC EMlSS8ONS FROM NM LOADING RACK Made Compressor Station Hose Emissions From Condensate Loading= 0.03 ton/month Tot Loadout Emiss= 0.33 tpy • Compressor Blowdown Emissions Marla Compressor Station DCP Midstream,LP (bftxmole) (Vol%) Oblibutere t3as} OM%) Carbon Dioxide 44.0 2.560 1.13 5.18 Helium 4.0 0.010 0.00 0.00 Oxygen 32.0 0.000 0.00 0.00 Nitrogen 28.0 0.460 0.13 0.59 Methane 16.0 74.730 11.96 54.96 Ethane 30.0 13.082 3.92 18.04 Propane 44.0 6.041 2.66 12.22 i-Butane 58.0 0.689 0.40 1.84 n-Butane 58.0 1.629 0.94 4.34 i-Pentane 72.0 0.308 0.22 1.02 n-Pentane 72.0 0.303 0.22 1.00 Other Hexanes+ 86.0 0.188 0.16 0.74 n-Hexane 86.0 0.000 0.00 0.00 Benzene 78.1 0.009 0.01 0.03 Toluene 92.1 0.005 0.00 0.02 Ethylbenzene 106.2 0.000 0.00 0.00 Xylenes 106.2 0 001 0.00 0.00 total 100.0 3t.* I90.0 V0C wt% 21.22 % . Methane Wt% 54.97 CO2 Wt% 5.17 % Volume of Gas Released (2.5 mcf @ 60 psi for each compressor) Volume @ 60 psi 2500 cubic feet/vent/event Vent toniblewdown #iyr YPY VOC Engine C-148 0.07 12 0.18 Engine C-135 0.07 12 0.18 Engine C-151 0.07 12 0.18 Engine C-166 0.07 12 0.18 Engine C-174 0.07 12 0.18 Engine C-176 0.07 12 0.18 • Produced Water Emissions Marla Compressor Station DCP Midstream,LP Produced Water Emission based on PS Memo 09-02 Based on two 210-bbl water tanks 3,750 bbl/yr` lblyr ton/yr VOC 983 0.491 Benzene 26 0.013 n-hexane 83 0.041 Produced water Emission Factors PS 09-02 VOC 0.262 Ib/bbl Benzene 0.007 Ib/bbl n-hexane 0.022 Ib/bbl • 0 Condenser Combustion Device Marla Compressor Station • DCP Midstream,LP Source ID Included with Tanks and Loadout Stack Height ft Description Combustor Stack Temp. deg F Manufacturer Unknown Stack Flow acfm Model Unknown Stack Velocity ft/min Serial# Unknown Stack Base ft Manufacture Date Unknown Latitude deg Fuel Heat Value 1040 Btu/scf Longitude deg Pilot Flow Rate 25 scf/hr or Pilot Heat Input 0.03 MMBtu/hr UTM Zone Pilot Potential Operation 8760 hr/yr UTM Northing Pilot Potential Fuel Usage 0.22 MMscf/yr UTM Easting m Destruction Efficiency 95% Datum Emissions from Pilot Combustion Emission Source of CAS Factor Emission Pollutant Number (lb(MMssf) Abler) (Etlyr) (tort/yr) Factor NOx 100 0.01 87.60 0.05 AP-42' CO 84 0.01 87.60 0.05 AP-42' VOC 5.5 0.01 87.60 0.05 AP-42' SO2 0.6 0.01 87.60 0.05 AP-42' PM 7.6 0.01 87.60 0.05 AP-42' 2-Methyl naphthalene 91-57-6 2.40E-05 0.0001 0.8760 0.0005 AP-42' 3-Methylchloranthrene , 56-49-5 1.80E-06 0.0001 0.8760 0.0005 AP-42' 7,12-Dimethylbenz(a)anthracene 1.60E-05 0.0001 0.8760 0.0005 AP-42' Acenaphthene 83-32-9 1.80E-06 0.0001 0.8760 0.0005 AP-42' Acenaphthylene 208-96-8 1.80E-06 0.0001 0.8760 0.0005 AP-42' Anthracene 120-12-7 2.40E-06 0.0001 0.8760 0.0005 AP-42' • Benz(a)anthracene 56-55-3 1.80E-06 0.0001 0.8760 0.0005 AP-42' Benzene 71-43-2 2.10E-03 0.0001 0.8760 0.0005 AP-42' Benzo(a)pyrene 50-32-8 1.20E-06 0.0001 0.8760 0.0005 AP-42' Benzo(b)fluoranthene 205-99-2 1.80E-06 0.0001 0.8760 0.0005 AP-42' Benzo(q,h,i)perylene 191-24-2 1.20E-06 0.0001 0.8760 0.0005 AP-42' Benzo(k)fluoranthene 205-82-3 1.80E-06 0.0001 0.8760 0.0005 AP-42' Chrysene 218-01-9 1.80E-06 0.0001 0.8760 , 0.0005 AP-42' Dibenzo(a,h)anthracene 53-70-3 1.20E-06 0.0001 0.8760 0.0005 AP-42' Dichlorobenzene 25321-22-6 1.20E-03 0.0001 0.8760 0.0005 AP-42' Fluoranthene 206-44-0 3.00E-06 0.0001 0.8760 0.0005 AP-42' Fluorene 86-73-7 2.80E-06 0.0001 0.8760 0.0005 AP-42' Formaldehyde 50-00-0 7.50E-02 0.0001 0.8760 0.0005 AP-42' n-Hexane 110-54-3 1.80E+00 0.0001 0.8760 0.0005 AP-42' Indeno(1,2,3-c,d)pyrene 193-39-5 1.80E-06 0.0001 0.8760 0.0005 AP-42' Naphthalene 91-20-3 6.10E-04 0.0001 0.8760 0.0005 AP-42' Phenanthrene 85-01-8 1.70E-05 0.0001 0.8760 0.0005 AP-42' Pyrene 129-00-0 5.00E-06 0.0001 0.8760 0.0005 AP-42' Toluene 108-88-3 3.40E-03 0.0001 0.8760 0.0005 AP-42' Arsenic 7440-38-2 2.00E-04 0.0001 0.8760 0.0005 AP-42' Beryllium 7440-41-7 1.20E-05 0.0001 0.8760 0.0005 AP-42° Cadmium 7440-43-9 1.10E-03 0.0001 0.8760 0.0005 AP-42' Chromium 7440-47-3 1.40E-03 0.0001 0.8760 0.0005 AP-42° Cobalt 7440-48-4 8.40E-05 0.0001 0.8760 0.0005 AP-42° Manganese 7439-96-5 3.80E-04 0.0001 0.8760 0.0005 AP-42° Mercury 7439-97-6 2.60E-04 0.0001 0.8760 0.0005 AP-42° Nickel 7440-02-0 2.10E-03 0.0001 0.8760 0.0005 AP-42' Selenium 7782-49-2 2.40E-05 0.0001 0.8760 0.0005 AP-42° Total HAPs 0.0033 28.9080 0.0165 'EPA AP-42,Volume I,Fifth Edition,July 1998,Table 1.4-1 'EPA AP-42,Volume I.Fifth Edition,July 1998,Table 1 4-2 'EPA AP-42,Volume I,Fifth Edition,July 1998,Table 1.4-3 0 °EPA AP-42,Volume I,Fifth Edition,July 1998,Table 1.4-4 Condenser Combustion Device • Marla Compressor Station Continued Vents to Combustion Device Flow Rate Operation Flow Rate Heat Value Heat Rate Vent Stream (scf/hr) (hr/yr) (MMscf/yr) (Btuisct) (MMBtu/yr) Triethylene Dehy Vent Stream P-112 179.00 8760 1.57 1707 2676.6 Triethylene Dehy Vent Stream P-113 179.00 8760 1.57 1707 2676.6 Note Flow rates and heat value are from GlyCalc 4.0 emission model Emissions from Combustin Vent Gas NOx NOx CO CO Vent Stream (lb/hr) (tpy) (lb/hr) (roy) Triethylene Dehy Vent Stream P-112 0.043 0.189 0.168 O 736 Triethylene Dehy Vent Stream P-113 0.043 0.189 0.168 0.736 Total 0.09 0.38 0.34 1.47 Note'.NOx emission factor,0.138 IbiMMBtu.and CO emission factor,0 5401NMMBtu,from TNRCC Flares and Vapor Oxidizers,Table 4 Flare Factors Total Emissions t40* N0* CO... CO. V0C V0C Vent Stream ... Obibrf NM @ask'. OS fitinwl (*py} Triethylene Dehy Vent Stream P-112 0.053 0.239 0.178 0.786 SeeTank Calcs Triethylene Dehy Vent Stream P-113 0.043 0.189 0.168 O 736 See Loading Calcs Total 0.10 0.43 0.35 1.52 Note both TEG Dehydrator vent streams go through one combustor,emissions from the pilot light are included in TEG Dehydrator vent stream br wrote P r 12. • Marla Compressor Station Summary of GHG Emissions DCP Midstream,LP Sources CO2. Combustion Sources 38983.4 Blowdowns 63.6 Rod Packing Venting 14,700.25 Total CO2e PTE 53,747 S • DCP Midstream,LP 4/28/2011 • Marla Compressor Station Compressor Blowdown Emissions DCP Midstream,LP Gas Con iaont R41711010 (Vot%) , (!pantie Gas) (Wt%) Carbon Dioxide 44.0 2.515 1.11 5.05 Helium 4.0 0.000 0.00 0.00 Oxygen 32.0 0.000 0.00 0.00 Nitrogen 28.0 0.389 0.11 0.50 Methane 16.0 74.941 11.99 54.73 Ethane 30.0 13.266 3.98 18.17 Propane 44.0 5.285 2.33 10.61 i-Butane 58.0 0.664 0.39 1.76 n-Butane 58.0 1.471 0.85 3.89 i-Pentane 72.0 0.351 0.25 1.15 n-Pentane 72.0 0.348 0.25 1.14 Other Hexanes+ 86.0 0.566 0.49 2.22 n-Hexane 86.0 0.107 0.09 0.42 Benzene 78.1 0.015 0.01 0.05 Toluene 92.1 0.036 0.03 0.15 Ethylbenzene 106.2 0.002 0.00 0.01 Xylenes 106.2 0.027 0.03 0.13 Tcital > 100.0 21.9 10110 • VOC wt% 22.82 Methane Wt% 57.95 CO2 Wt% 5.04 % Volume of Gas Released (2.5 mcf @ 60 psi for each compressor, 2 vents per compressor) Volume @ 60 psi 2500 cubic feet/vent/event Vott tOnAJAN It #'htr; TPY VQC _g 'wrists, r IPY CO2' TPY c 2e Engine C-148 0.07 12 0.20 0.50 0.04 10.6 Engine C-135 0.07 12 0.20 0.50 0.04 10.6 Engine C-151 0.07 12 0.20 0.50 0.04 10.6 Engine C-166 0.07 12 0.20 0.50 0.04 10.6 Engine C-174 0.07 12 0.20 0.50 0.04 10.6 Engine C-176 0.07 12 0.20 0.50 0.04 10.6 Total CO2e 63.6 • DCP Midstream, LP 4/28/2011 ri C 0 0 0 o N• • O 2 t 00 V) a = (p (6 co N E LL O .o d f LU n U) CO N N ^ N r M V 4� N N- 7 M C co O O on N j Ol W C M M 0) " J To C @ ict O E C r O 0 N N M N F 0 N N 15, n O N- C O O O O co M N- (p N.-: co N V C J. 7 O D) N m V (0 N co r • E LLJN- C NJ O N 7 ^ O r co L o r0 CD E la r O O 0 co C = _ i L L L L L .C L L L '5, 'N O O O 0 O U 7 > > > > > > > ` o N N 2 M O O co mCOCO mmm CO CO CO r to E LL LO O O • 2 2 2 2 2 2 2 2 2 4- 2 w Y o O (0 CO LO L LO N N N CO O O N M N r M M M O r (O M N r cp r 0 Loo - N U U U Q N 0 N 0 a ti ti ti C c N U Oa U U Q y y CC r n o Ct 0 0 CA O. a O 1 J C N M O J j (n CO 0) V) J O = LL LL o co co co a a0i v°) E a) do a d >. >. >, m rn rn rn 0• C `7 > O. co M (n COO 'Cr CD 0 2 N N N o co d d E • G o o tl Li LL Ex w O in v m U U U U U U @@ LL 0 LL LL Ln U 7 0 ._ — — — U U U U v m a t = E c c c c c c c E "5 E N 2N - a V �V 7 d iv o V li o c °c c °c °c °c w w o 0 0 di = 500 LLD- WU WLLJLIJWF- F- o_ o_ a :° 0 Z 0 1_ as p ri ri co o N Cl N N pó W Q0 N- N V --. 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Appendix C Current APENs APENs for engines C-148, C-135, C-166, C-174, and C-176 are from the 4/28/2011 Minor Modification APEN for engine C-151 is from the 4/28/2011 AOS APENs for glycol dehydrators P112 and P113 are from the 4/9/2010 Minor Modification APEN for the fugitive emissions P106 is from the 9/7/2009 Minor Modification chC DCP Midstream 370 17th Street,Suite 2500 Denver,CO 80202 Midstream. 303-595-3331 • April 28, 2011 Hand Delivered Mr. Matt Burgett Colorado Department of Public Health and Environment APCD-SS-B 1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 SUBJECT: Marla Compressor Station Operating Permit 95OPWE020 Minor Modification Mr.Burgett: DCP Midstream, LP(DCP) is requesting a minor modification for the Title V Operating Permit(95OPWE020) at the Marla Compressor Station (Marla). The minor modification request pertains to the current compressor engine • fuel consumption and compliance emission factors and will not change short or long term total emission limitations. DCP is requesting to revise the natural gas heating value as expressed in BTU/SCF and the brake specific fuel consumption(BSFC) BTU/hp-hr for each of the engines operating at Marla. The BTU value of the fuel gas has been steadily increasing as the aging fuel conditioning unit is not operating quite as efficient as it once was. Also, DCP is providing revised manufacturer fuel consumption values for each of the six compressor engines at the Marla facility which will more accurately represent actual operation of the engines. Previous permitting application documents for Marla recorded a natural gas value of 1,040 BTU/SCF.DCP is requesting to change the natural gas heating value to 1,200 BTU/SCF. Also, per the attached manufacture specifications, DCP would like to set the BSFC value to 7,830 BTU/hp-hr for the Waukesha 7042 engines and 7,860 BTU/hp-hr for the Waukesha 7044 engines. This will affect fuel consumption and slightly change the compliance emission factors for each engine. Short and long term emissions will not change with these modifications. A listing of the requested permitted emission factors (controlled)and fuel consumption ratings are provided a: S April 28,2011 Page 2 of 2 AIRS Point Description Requested New Requested Compliance Annual Emission Number/Facility BSFC and Fuel Emission Factor Limitations ID Usage 052/C-148 (P-102) Waukesha 7,830 btu/hp-hr NOx - 0.84 lb/mmbtu(3.0 g/bhp-hr) NOx - 42.82 tpy 7042 GSI 84.48 mmscf/yr CO - 0.84 lb/mmbtu(3.0 g/bhp-hr) CO - 42.82 tpy 1478 hp VOC -0.28 lb/mmbtu(1.0 g/bhp-hr) VOC - 14.27 tpy 053/C-135 (P-103) Waukesha 7,830 btu/hp-hr NOx - 0.56 lb/mmbtu(2.0 g/bhp-hr) NOx - 28.54 tpy 7042 GSI 84.48 mmscf/yr CO - 0.84 lb/mmbtu(3.0 g/bhp-hr) CO - 42.82 tpy 1478 hp VOC -0.28 lb/mmbtu(1.0 g/bhp-hr) VOC - 14.27 tpy Note:NOx emission factor adjusted to meet Colorado Regulation 7 requirements, previous AOS submitted to CDPIIE on 4/4/10. 054/C-151(P-104) Waukesha 7,830 btu/hp-hr NOx - 0.28 lb/mmbtu(1.0 g/bhp-hr) NOx - 14.27 tpy 7042 GSI 84.48 mmscf/yr CO - 0.56 lb/mmbtu(2.0 g/bhp-hr) CO - 28.54 tpy 1478 hp VOC -0.20 lb/mmbtu(0.7 g/bhp-hr) VOC -9.99 tpy Note:NOx emission factor adjusted to meet Colorado Regulation 7 requirements, AOS submitted to CDPHE on 4/28/11. 059/C-166(P-109) Waukesha 7,860 btu/hp-hr NOx - 0.56 lb/mmbtu(2.0 g/bhp-hr) NOx - 32.45 tpy 060/C-174(P-110) 7044 GSI 96.40 mmscf/yr CO - 0.56 lb/mmbtu(2.0 g/bhp-hr) CO - 32.45 tpy 061/C-176(P-111) 1680 hp VOC -0.28 lb/mmbtu(1.0 g/bhp-hr) VOC - 16.22 tpy Supporting documentation for this Minor Modification includes the following: • • A check for$764.50 for 5 APEN fees(Note the APEN fee for engine C-151 is being submitted with the AOS for that engine that is being submitted at the same time as this submittal. A copy of that check and APEN is provided with this submittal); • New APENs for each permitted compressor engine; • Engine emission calculation sheets for criteria pollutants and hazardous air pollutants; and • Revised Waukesha manufacturer engine ratings and fuel consumption graphs for Waukesha 7042 GSI and Waukesha 7044 GSI compressor engines. DCP is requesting these changes under a Minor Modification to Title V Operating Permit 95OPWE020. Since Operating Permit Minor Modification Application forms have not been developed,this letter serves as the application. A signed responsible official certification form is attached for this minor modification application. Should you have any questions regarding this minor modification request,please contact me at(303)605-1716 or wdhill@dcpmidstream.com. Sincerely, DCP Midstream,LP Wesley Hill Senior Environmental Specialist Attachments • 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 be used to process this application. This certification conforms with Regulation No. 3,Part C, Section X.D.3(5 CCR 1001-5). Joseph Kuchinski Vice President,Area Operations North Printed or Typed Name Title , ,aMli a ; 1 �bJJ � ot � J o of Responsible Official Date • • Check for APEN Filing Fees • $764.50 • • Revised APEN Forms • • • U A V N 0 o `o_ Elid ! '0v c ate, u c u c u>. E um '—y�' 6. C N N J c U , 2, E <n .n .n o O c " ta7 U c •• c oco c c F_ a ° c c Q °_' u �E ° ` 3 w a a t O u F 7 %< e o c O. c ._ t° c w e .E o c o c J y W F L' a. 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Z o i € 6 m u G •u O x u u ❑ w < ao u U ❑ W u — u rn V V] V] V) DCP Midstream 370 17th Street,Suite 2500 Denver,CO 80202 Midstream,. 303-595-3331 • April 28, 2011 Hand Delivered Mr. Matt Burgett Operating Permit Unit Supervisor Colorado Department of Public Health and Environment APCD-SS-B 1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Re: Execution of Alternate Operating Scenario (AOS)—Marla Compressor Station Operating Permit No.95OPWE020 AIRS ID 123/0243/054 Engine C-151 Dear Mr. King: This letter and the attached revised APEN provide the formal notification required under Operating Permit 95OPWE020 for the replacement of engine C-151 (AIRS ID 123/0243/054) with a like-kind engine at the Marla Compressor Station. A $152.90 check is attached for the APEN filing fee. Compressor engine C-151 is identified in the operating permit as a 1,478 hp,Waukesha L7042 GSI engine. • The serial number of the old engine was 898468 and the serial number of the replacement engine is C-12843/1. The replacement engine commenced operation on April 27, 2011 and was tested on April 28, 2011, using a portable analyzer to measure NOx and CO emissions. The results of the portable analyzer test showed that the engine is in compliance with the current emission limits. A field log is maintained to document all like-kind engine replacements. Both the test results and copy of the field log are provided with this submittal. Note that the APEN for this AOS was included in the April 28, 2011 Minor Modification to revise the natural gas heating value and brake specific fuel consumption and the TV permit renewal. Please feel free to contact me at(303) 605-1716 with any questions regarding the use of the AOS to account for the above mentioned like- kind engine replacement at the Marla Compressor Station. Sincerely, DCP Midstream, LP Wesley Hill Senior Environmental Specialist Attachments O. u y V O C _ Y ° C _ • 0 In III in 6 v U L 6 �� O A v� E a _ a N [� N - v1 V [- S �. U Q C m s T 0) E m y r, M m F m0 — O n n 0 m p R c w u N w N c J U o ca V _ c o o O 0 -, - N 0.1 L (_J ,J ., L G M e rl o .� cv d K ° t > ° a La w .� _ as v c P a m c ^ — `� c c p _ n .. .. i co _ _ = o _� u r .. o E E C A _ .c u _ �. C N • .7,, E '7 on v} Z G � u u IL E ov, v c c E n v, • • o c. ."� ^r, > ≥ " m » r. LE c- 2 ro C. C U U N C c a 3 A fn E v p c u 1.. - 2 n o m m ro `- m 0 °u' > o s E3 a - c -o -7 ° tit C ` a r - w 3. A Z v .. c30 " " u ca u ` on o U u a o '7 c o s j o 0 0- d Fy m 7 'E na a o E C C _ N F J m o c P. o >' u u Q C ct `u' u a F v o <, .� v o cr v aPi s0.' w 0 'm n' 9 > v v a r. 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O 0 0 w Q '" idler DCP Midstream 370 17th Street,Suite 2500 _ m Denver,CO 80202 • ��+++M am 303-595-3331 April 1, 2010 UPS Tracking No: 1Z F46 915 37 1001 144 7 Mr.Jim King Colorado Department of Public Health and Environment APCD-SS-B 1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 SUBJECT: Marla Compressor Station Operating Permit 95OPWE020 Minor Modification Mr. King: DCP Midstream,LP(DCP)is requesting a change to the language in the Title V Operating Permit 95OPWE020 for the Marla Compressor Station(Marla). The May 1,2007 operating permit Compliance Assurance Monitoring (CAM)plan specifies that a thermocouple must be used as the • indicator on the flare to detect the presence of a flame. Please replace the language in Appendix H of the CAM Plan, Section II. Monitoring Approach I with the following text, "The Indicator Measurement Approach for the flare states that "Presence of a flame is continuously monitored with thermocouple" to"Presence of a flame is continuously monitored with thermocouple or equivalent technology".. DCP proposes to use a flame monitoring system in place of a thermocouple as an indicator for detecting the presence of a flame on the flare. Attached are the manufacturer specifications on the Iris flame monitoring system. Iris Model 806 uses an ultraviolet light that works as effective as a thermocouple to monitor the presence of a flame on the flare.The IRIS monitor has been certified by the Canadian Standards Association(CSA)as well as being recognized by the National Recognized Testing Laboratories(NRTL/C). Each system consists of a viewing Head mounted on the burner front and connected to a Signal Processor which contains signal processing circuitry,a remote meter drive,a multi-contact Flame Relay,and a Self-Checking Relay. The"Device senses heat and when there is an absence of a flame,then an alarm is sent to the control room". Because the Iris Flame Monitoring System meets all CAM requirements,DCP is requesting to have the flexibility to use Flame monitoring system in place of a thermocouple. DCP is requesting these changes under a Minor Modification to 95OPWE020. Since Operating Permit Minor Modification Application forms have not been developed,this letter serves as the application. A signed responsible official certification form is attached for this minor modification application. • • Should you have any questions regarding this minor modification request, please contact me at(303) 605-1716 or wdhill@dcpmidstream.com. Sincerely, DCP Midstream,LP Wesley Hill Senior Environmental Specialist Attachment • • • 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 be used to process this application. This certification conforms with Regulation No. 3,Part C, Section X.D.3 (5 CCR 1001-5). 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UPS Tracking No: 1Z F46 915 01 9552 3202 April 9, 2010 Mr. Jim Geier Colorado Department of Public Health and Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 SUBJECT: Marla Compressor Station Operating Permit 95OPWE020 Addendum to August 7, 2009 Minor Modification Mr. Geier: On August 7,2009,DCP Midstream,LP (DCP) submitted a request for a minor modification to the Marla Compressor Station Title V Operating Permit 95OPWE020 to update the fugitive emissions from equipment leaks. As requested,this letter is an addendum to that submittal to incorporate a few changes to existing permit conditions for the tri-ethylene glycol(TEG) • dehydration units P-112 and P-113. Since Operating Permit Minor Modification Application forms have not been developed, this letter in addition to the August 7th submittal serve as the application. DCP would like to have the monthly gas processing limits removed from the two TEG dehydration units P-112 and P-113. Typically, monthly limits are only imposed on sources for the first 12 months of operation and then ongoing compliance is shown with 12 month rolling totals. However,this permit contains both monthly and 12 month rolling emission limits with no provision to drop the monthly limits even though these dehydration units have been in operation for longer than 12 months.These units operate in parallel,and if one unit goes down,the other • unit can take the additional gas while maintenance is being completed on the downed unit. However,the monthly throughput limits make it difficult to utilize such operational flexibility. Secondly, since these units are both permitted for a throughput of 16,425 MMSCF/yr,DCP would like to set the glycol recirculation rates and emission limits to be the same for both units. Currently TEG unit P-112 is permitted at a glycol recirculation rate of 7.5 gpm and a VOC emission limit of 3.41 tpy, while P-113 has corresponding limits of 5.0 gpm and 2.23 tpy. DCP would like to set the glycol recirculation rate limit for both units to 6.25 gpm. This is simply the average between 5.0 and 7.5 gpm. This will make the V0C emission limit be 2.82 tpy for both units. The adjustment of these limits will allow for greater operational flexibility and will not result in an increase in emissions. The combined VOC emissions from both of these units will remain unchanged at 5.64 tpy. Both units are currently routed to the same combustor. Therefore, there will be no change to the amount of vapor going to the unit for combustion. Revised • www.dcpmidstream.com April 9,2010 Mr.Jim Geier Page 2 of 2 APENs for each dehydration unit are attached along with a check for$305.80 for the APEN filing fees. Lastly, there was a minor modification to the CAM plan submitted on April 1,2010. Please incorporate the changes requested in that submittal while amending the permit for the requested modifications to the fugitive emissions and dehydration units. Should you have any questions regarding this minor modification request,please contact me at (303)605-1716 or wdhill@dcpmidstream.com. Thank you for your assistance. 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V c O .. v V °i I v R v m • (750, n , ,,,,,,,,_---t W in y 'E U II; F B ( c E L' � o v Q C. o y u a s eia c co `° m x V g°g y c a'" o o o co o >a. u eP+ !C = u c �,;Ei = 0 0 0 2 3 'o' �' 0 E c m 2 .- a o O F F- a I> a Q o a Z > U v o T x 5 o c A W, DCP Midstream 370 17th Street,Suite 2500 trCla Denver,CO 80202 Midstream. 303-595-3331 August 7, 2009 Mr.Jim King Colorado Department of Public Health and Environment APCD-SS-B l 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 SUBJECT: Marla Compressor Station Operating Permit 95OPWE020 Minor Modification Mr. King: DCP Midstream,LP(DCP)requests the following minor modification to Title V Operating Permit 95OPWE020 for the Marla Compressor Station. Since Operating Permit Minor Modification Application forms have not been developed,this letter serves as the application. DCP would like to combine the two fugitive emission sources(P106&P114)into one source(P106). The AIRS 1D#s are 123/0243/056 and 123/0243/064 respectively. DCP would like to cancel AIRS ID# • 123/0243/064 and roll all of the fugitive emissions into AIRS ID#123/0243/056. DCP has recently reevaluated the Marla fugitive emissions based on the most recent gas analysis and component count. DCP requests a combined fugitive VOC emission limit of 36.02 TPY. This emission limit was calculated with a 10% buffer to accommodate the addition of any new components or changes in gas composition. Also,the emission calculations use emission factors for components in both gas and liquid service with a VOC content of 23.73% for the gas and 100%for the liquids.This calculation methodology varies from the July 24, 2008 minor modification for these sources which did not breakout the liquid service components. A signed responsible official certification form is attached for this minor modification application.Also,please find attached an APEN,supporting calculations,and check for$152.90 for the APEN filing fee. Should you have any questions regarding this minor modification request,please contact me at(303)605-1984 or wdhill(a dcpmidstream.com. Sincerely, ' DCP Midstream,LP Wesley Hill Senior Environmental Specialist Attachments www.dcpmidstream.com • 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 be used to process this application. This certification conforms with Regulation No. 3, Part C, Section X.D.3 (5 CCR 1001-5). William Prentice Vice President, Technical Services Printed or Typed e Title AUG 0 7 2009 ignature of Responsi le Official Date • 0 to o `o E u o le) a U —'' « a 0. E o = �F E ti ° c a E z 5 lc pp t M z g 1.. 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' mr e E O .� m 'n co '� m Z..2.0 O J CO y Z ff v O n c u 0.2 Z m w O E , m L w w O m L y m co_ co w w T> ≥ Lo co w 0) o r, V O O w O J W CO O J w w m N 0 J C O O `y .• w a U FF �i E gp Y a c U E S. m�w 45 lij any S ul w co w , m d a c o S E c'`, g m U 5 CO m m m o E L n o a m m o w V a o v o o m o O 0 0- o o_ 9wmw d Sa > > wr >> OCL 0000 ULL+ r 04/07/2009 14:27:43 • ' All Regulations Percent Leaker Report Monitor Run ID: SUMM Area: ALL Sub Area: ALL Total Total Left Percent Number Percent Delay of Leak Def. Equip Type Chemical State Monitored to Monitor Monitored of Leaks Leaking Repair (ppm) CMP Vapor 0 7 0.00% 0 0.00 0 10000 CON Light Liquid 0 454 0.00% 0 0.00% 0 10000 CON Vapor 0 556 0.00% 0 0.00% 0 10000 FLG Light Liquid 0 32 0.00% 0 0.00% 0 10000 FLG Vapor 0 295 0.00% 0 0.00 0 10000 PMP Light Liquid 0 25 0.00% 0 0.000/0 0 10000 PRV Light Liquid 0 11 0.00% 0 0.00% 0 10000 PRV Vapor 0 46 0.00% 0 0.00% 0 10000 VLV Light Liquid 0 734 0.00% 0 0.00% 0 10000 VLV Vapor 0 615 0.00% 0 0.00% 0 10000 TOTALS 0 2975 0.00% 0 / 0 i Page 1 • PGAS Meter Information Report Date:Tuesday,May 12,2009 10:58:54 Record 1 of 1,Page lot 1 Meter Information MS ID: 65394 County: Weld Stab: CO PGAS Matz Number: 224804 Meter Description: COORS SOCO WELD INLET,SN: 103982 Most Recent Anal sis AnalyS Data 05/01/2009 Analysis ID: 48773 Pressure(psla): 131.000 Analysis Name: 224804 Tanperatu a en: 49.00 Alternate Nance: !tu Content(litu/dscf): 1,247.700 Ewa Md�'�" Anibenba Sits taboo Dioxide 002 2.4%u 0.02416 Meta Frac thane C2H6 13.4ete 0.13966 Mole Frac \Helium lie o.004. 0.00006 Mole Frac ‘Htuarte 064414 0..214- 0.00232 Mole Frac '1-&t3ne C4H10 0.'hW 0.00706 Mole Frac si-p ne C5H12 6.'L94 0.00276 Mole Frac 014 fl.tn 0.73288 Mole Frac \n-giaK C4HI0 1.444 0.01699 Mole Frac •.Nitrogen N2 8.434 0.00434 Mole Frac ' n,Pmtene CSH12 (,'bl'3 0.00313 Mote Fiat .Propane OHS 'Te,yy4 0.06664 Mole Frac Total: 1.00000 • S 370• &Car Midstream 370 17th Street,Suite 2500 Denver, CO 80202 Midstream. 303-595-3331 July 24,2008 UPS Next Day Air(Tracking Number 1Z F46 915 22 1006 305 3) Mr. Jim King Colorado Department of Public Health and Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 SUBJECT: Minor Modifications Marla Compressor Station Operating Permit 95OPWE020 Dear Mr. King: DCP Midstream, LP (DCP), requests the following changes to the Title V Operating Permit 95OPWE020 for the Marla Compressor Station. DCP is requesting these changes under a Minor Modification to 95OPWE020. Since Operating Permit Minor Modification Application forms have not been developed,this letter serves as the application. • DCP would like to request that the emission limit for the fugitive VOC emissions from equipment leaks(P- 106) be increased from 8.2 ton/yr to 23.3 ton/yr. DCP would like to request this change to accommodate recent piping configuration changes. A 30 percent buffer was also included to accommodate future changes in configuration or VOC content of the gas. Like wise, DCP would also like to increase the emission limit for the fugitive VOC emissions from the fuel conditioning unit(P-114)from 1.03 ton/yr to 1.5 ton/yr to account for recent and future changes. Please find the following back-up information attached: • Two APENs, • Component counts, both actual and requested, • Emission calculations based on most recent gas analysis, • One check for$305.80 for the APEN filing fees, and • One responsible official certification form. Should you have any questions regarding this minor modification request, please contact me at 8g rosertbernadc midstream.com or(303)595-3331. Sincerely, DCP Midstream,LP Lls--"H"- lOr Susan Rosenberg Senior Environmental Specialist www.dcpmidstream.com 1/40 O u� ba 3o 0 ore 0 en N ^ri' X. 68 'figg �n 0 el �^ ❑ >- .-F a. n• € r •a° M 'g C aT C ❑ 8 6 �. w t un (A o < 13 • Y d k p 11 E re N a a' 0 0 0 E 'S' P'' Z0 o y x 3.t "aa ' c▪ Q �n w a< U 1 FA o a0 of y Q oo w., wW? ng v ?jig CT 11 :14 azi ac yc .9 ° md. ° so; if$. 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'f816 CONSTRUCTION PERMIT PERMIT NO: 01 WE0499 INITIAL APPROVAL DATE ISSUED: SEPTEMBER 25, 2001 ISSUED TO: DUKE ENERGY FIELD SERVICES, LP__ THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural Gas Facility known as the Maria Compressor Station,located in the SE%of Sec 28-4N-64W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: • One(1)Waukesha L 7042 GSI,S/N 397541,Rated at 1478 HP,natural gas fired,internal combustion reciprocating engine equipped with a NSCR, AFR. This emission unit powers a natural gas compressor, stack number 52,C-148. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S.(25-7-101 et seq),TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: 1, 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 minutesin any sixty consecutive minutes. Opacity shall be measured by EPA Method 9. (Reference: Regulation 1,Section ll.A.1.& 4.) 2. The permit number shall be marked on the subject equipment for ease of identification.(Reference: Reg. 3, Part B, IV.E.)(State only enforceable) 3. Emissions of air pollutants shall not exceed the following limitations(as calculated in the Division's preliminary analysis). Compliance with the annual limits shall be determined on a rolling(12)month total.By the end of each month a new twelve-month total is calculated based on the previous twelve months'data.The permit holder shall calculate monthly emissions and keep a compliance record on site for Division review:(Reference: Regulation 3, Part B, III.A.4). Nitrogen Oxides: 42.8 tons per year and 7,270.0 pounds per month Volatile Organic Compounds: 14.3 tons per year and 2,429.0 pounds per month Carbon Monoxide: 42.8 tons per year and 7,270.0 pounds per month • Note: Based on a fuel heating value of 1040 Btu/scf 123/0243/052 ver.2/00 DUKE ENERGY FIELD SERVICES. LP Colorado Department of Public Health and Environment • Permit No.01WE0499 Air Pollution Control Division INITIAL APPROVAL Page 2 During the first twelve (12) months of operation, compliance with both the monthly and yearly emission limitations shall be required.After the first twelve(12)months of qperation,compliance with only the yearly limitation shall be required. 4. This source shall be limited to a maximum consumption rate as listed below and all other activities, operational rates and numbers of equipment as stated in the application.Monthly records of the actual consumption rate shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference:Regulation 3,Part B,III.A.4) Consumption of natural gas as fuel shall not exceed 8.45 million scf per month and 101.4 million scf per year. During the first twelve (12) months of operation, compliance with both the monthly and yearly consumption limitations shall be required.After the first twelve(12)months of operation,compliance with only the yearly limitation shall be required.Compliance with the yearly consumption limits shall be determined on a rolling twelve(12)month total. 5. A source compliance test shall be conducted to measure the emission rate(s)for the pollutants listed below. 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. The protocol shall include manufacturers analysis of emissions at engine maximum and minimum loads,at site specific conditions. Engine operating parameters will be included in the analysis with emissions reported in parts per million dry volume and grams per • actual horsepower-hour(g/BHP-Hr.) or pounds per million BTU (Ib/MMBTU). No test shall be conducted without prior approval from the Division.Any stack 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.(Reference: Regulation 3, Part B.IV.H.3) Oxides of Nitrogen,Carbon Monoxide and Oxygen, using EPA approved methods. 6. Prior to the stack test being performed, the applicant shall submit to the Division the catalyst manufacturer,model number,serial number and specifications. 7. Prevention of Significant Deterioration(PSD)requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. My relaxation that increases the potential to emit above the applicable PSD threshold will require a full PSD review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit is granted. 8. Operating Permit(OP)requirements shall apply to this source. An application to modify the existing Operating Permit for this facility shall be submitted within one year of the Initial Approval Date of this Construction Permit(Regulation 3, Part C). 9. A revised Air Pollutant Emission Notice(APEN)shall be filed: (Reference: Reg.3, Part A.It.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year,a change in actual emissions of five(5) • tons per year or more,above the level reported on the last APEN; or 123/0243/052 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0499 Air Pollution Control Division INITIAL APPROVAL Page 3 For any non-criteria reportable pollutant: If the emissions increase by 50%or five(5)tons per year,whichever is less,above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility,process,or activity; or c. Whenever new control equipment Is installed, or whenever a different type of control equipment replaces an existing type of control equipment;or d. Whenever a permit limitation must be modified;or e. No later than 30 days before the existing APEN expires. 10. The applicant shall track emissions from all insignificant activities on a yearly basis.This information shall be made available to the Division for inspection upon request.For thepurposes of this condition, insignificant activities shall be defined as any activity or equipment which wits any amount but does not require an Air Pollutant Emission Notice(APEN). 11. Within one hundred and eighty days (180)after commencement of operation, compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee's responsibility to self certify compliance with the conditions.Failure to demonstrate compliance within 180 days may result in revocation of the permit.(Information on how to certify compliance was mafied • with the permit or can be obtained from the Division at 303-692-3209.) 12. The engine covered under this permit may be replaced in accordance with the provisions of the Alternative Operating Scenario listed In Attachment A.(Regulation 3,A,IV,A) 13. No atmospheric condensate tanks will be operated at this facility • --� By:62411 P.Mark James S. Geie.P.E. Permit Engineer Unit Leader Notes to Permit Holder: 1) The fuel consumption limits and emission limits contained in this permit are based on the fuel consumption rates requested in the permit application. These limits may be revised upon request of the pernittee providing there is no exceedence of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice(APEN)and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Upset Conditions and Breakdowns.The permittee shall notify the Division of any upset condition which causes a violation of any emission limit or limits stated in this permit as soon as possible,but no later than two(2)hours after the start of the next working day, followed by written notice to the Division explaining the cause of the occurrence and that proper action has been or is being taken to correct the conditions causing said violation and to prevent such excess emission in the future. S 123/0243/052 ver. 2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No. 01WE0499 Air Pollution Control Division INITIAL APPROVAL Page 4 3) The following emissions of non-criteria reportable air pollutants are estimated based upon the material consumptions as indicated In Condition No.3. This information is listed to inform the operator of the Division's analysis of the specific compounds. This information Is listed on the Division's emission inventory system. C.A.S. # SUBSTANCE EMISSIONS JLB/YR) 50-00-0 Formaldehyde 1,338.7 7143-2 Benzene 516.6 75-07-0 Acetaldehyde 91.3 4) The emission levels contained In this permit are based on the following emission factors: Nitrogen Oxides- 3.0 grams per horsepower-hour Volatile Organic Compounds: 1.0 grams per horsepower-hour Carbon Monoxide: 3.0 grams per horsepower-hour 5) Operating Permit(OP)requirements shall apply to this source and shall require submittal of and issuance of an operating permit, under Regulation 3, Part C. 6) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years. The five year terrn for this APEN expires on May 15,2006. A revised APEN shall be submitted no later than 30 days before the five year term expires. 7) This emission unit is classified as a: Synthetic minor source • At a: Synthetic minor facility for MACT HH At a: Major Title V facility At a: Synthetic minor facility for PSD • 123/0243/052 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0499 Air Pollution Control Division INITIAL APPROVAL Page 5 GENERAL TERMS AND CONDITIONS: (IMPORTANT! REAL) ITEMS 5,6,7 AND 8) 1. This permit is Issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity,or construction,installation and operation of the source,in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 2. Unless specifically stated otherwise,the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7.114.5(7Xa),C.R.S. 3. Each and every condition of this permit Is a material part hereof and is riot severable. My challenge to or appeal of,a condition hereof shall constitute a rejection of the entire permit and upon such occurrence,this permit shall be deemed denied ab Maio. This permit may be revoked at any time prior to final approval by the Air Pollution Control Division (APCD) on grounds set forth In the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission(AQCC).including failure to meet any express term or condition of the permit If the Division denies a permit,conditions imposed upon a permit are contested by the applicant or the Division revokes a permit,the applicant or owner or operator of a source may request a hearing before the AQCC for review of-the Division's action. 4. This permit and any required attachments must be retained and made available for inspection upon request at the location set forth herein. With respect to a portable source which is moved to a new location,a copy of the Relocation Notice(required by law to be submitted to the APCD whenevera portable source is relocated)should be attached to this permit. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No.3,Part B, Section III.B.upon a request for transfer of ownership and the sttbmitlal of a revised APEN and the required fee. 5. Issuance(Initial approval)of an emission permit does not provide final authority for this activity or operation of this source. Final approval of the peimit must be seared from the APCD In wilting it accordance with the provisions of 25-7- • 114.5(12)(a)C.R.S. and AQCC Regulation No.3, Part B,Section N.H. Final approval 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. lithe APCD so determines,it wN provide written documentation of such final approval,which does constitute finer authority to operate.Compliance with the permit conditions must be demonstrated within 180 days after commencement of operation. 6. THIS PERMIT AUTOMATICALLY EXPIRES IF you(1)do not commence construction or operation within 18 months after either the date of issuance of this permit or the date on witch such construction or activity was scheduled to commence as set forth In the permit,whichever is later,(2)discontinue construction fora period ci 18 months or more;or (3)do not complete construction within a reasonable time of the estimated completion date. Extensions of the expiration date may be granted by the APCD upon a showing of good cause by the pernittee prior to the expiration date. 7. YOU MUST notify the APCD at least thirty days(fifteen days for portable sources)priori')commencement of the permitted operation or activity. Failure to do so is a violation of Section 25-T-114.6(12Xa), C.R.S. and AQCC Regulation No.3, Part B, Section IV,H.1.,and can result in the revocation of the permit. You must demonstrate compliance with the permit conditions within 180 days after commencement of operation es stated in condition 5. 8. Section 25-7-114.7(2)(a),C.R.S.requires that all sotrces required to file an Air Pollution Emission Notice(APEN)must pay an annual fee to cover the costs of Inspections and administration. If a source oractivity is to be discontinued,the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification,annual fee biting will terminate. 9. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative,civil or criminal enforcement actions under Sections 25-7-115 (enforcement),-121(injunctions),-122(civil penalties),-122.1(aintnal penalties),C.RS. S 123/0243/052 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No. 01WE0499 Air Pollution Control Division INITIAL APPROVAL Page 6 ATTACHMENT A Alternative Operating Scenarios The following Alternative Operating Scenario(AOS)for temporary and permanent engine replacement has been reviewed In accordance with the requirements of Regulation No. 3..Part A,Section IV.A, Operational Flexibility-Alternative Operating Scenarios,and Regulation No.3, Part B,Construction Permits,and 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. For purposes of Regulation No. 3, Part B, Section IV.G.4.a., any engine replacement authorized under this AOS shall commence operation upon notation of same in the-contemporaneous log as required below. Results of any testing required below shall be normaljzed for comparison to the applicable permitted emission limits. • 1.1 Temporary Engine Replacement The following AOS is incorporated into a permittee's operating or construction permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair which requires the • use of a temporary replacement engine(defined as in the same service for 90 days or less in any 12 month period). The compliance demonstrations made as part of this AOS are in addition to any • compliance demonstrations required by the permit. 4.1.1. 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 some manufacturer,model, and horsepower or a different manufacturer, model,or horsepower as the existing engine without modifying this permit. The permittee shall measure nitrogen oxide(NO)and carbon monoxide(CO)emissions in the exhaust from the temporary replacement engine using a portable flue gas analyzer within seven (7)calendar days of commencing operation of the temporary replacement engine. Calibration of the analyzer shall be conducted according to manufacturer=s Instructions. In the absence of evidence to the contrary,results of the portable flue gas analyzer test shall be evidence of enforceable compliance or noncompliance of the temporary replacement engine with the emission limitations of the original engine. An exceedance of either the NO,or CO emission limitation during the initial portable flue gas analyzer test shall require a subsequent portable flue gas analyzer test indicating compliance with both the NO, and CO emission limitations within 14 calendar days of commencing operation of the replacement engine. Calibration gases shall be used to calibrate the portable analyzer for all tests conducted subsequent to the initial test. If portable flue gas analyzer results indicate compliance with both the NO,and CO emission limitations within the 14-day period,the temporary replacement engine will be considered to be in compliance for purposes of this AOS from the time that the replacement engine • commenced operation until the replacement engine is taken off line. 123/0243/052 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0499 Air Pollution Control Division INITIAL APPROVAL Page 7 If portable flue gas analyzer results fail to indicate the compliance with either the NO,or CO emission limitations within the 14-day period, the source will notify the Division in writing within 10 calendar days of the end of the 14-day period. In the absehce of evidence to the contrary,the temporary replacement engine will be considered to be out of compliance from the time that the temporary replacement engine commenced operation until the engine is taken off line. Results of all testing that Indicates noncompliance shall be submitted to the Division within 10 calendar days of the end of the 14 day period. 4.1.2 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. Potential emissions from the temporary replacement engine must be less than or equal to the potential emissions 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. 4.1.3 Temporary replacement engines, whether of the same manufacturer, model, and horsepower,or of a different manufacturer,model,or horsepower,are subject to all federally applicable and state-only requirements set forth in this permittktduding monitoring and record keeping),and shall be subject to any shield afforded by this permit 4.1.4 The permittee shall maintain a log on-site to contemporaneously record the start and stop date of any temporary engine replacement,the manufacturer, model number,horsepower, and serial number of the engine(s) that are temporarily replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the • replacement engine. 4.2 Permanent Engine Replacement The following AOS is incorporated Into a permittee's operating or construction permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair which requires the use of a permanent replacement engine(defined as in the same service for more than 90 days in any 12 month period). The compliance demonstrations made as part of this AOS are in addition to any compliance demonstrations required by the permit. 4.2.1 The permittee may permanently replace the existing compressor engine for the emission points specified in Table 1 with the manufacturer,model,and hortbpower engines listed in Table 1 without modifying this permit. The periodic monitoring specified for the replacement engine shall be required. Wdhln 180 days of permit issuance or within 180 days of the startup of a new source, whichever is applicable, and prior to replacing the existing compressor engine for the emission points specified in Table 1, the existing engine (if it has a design rate of 150 horsepower or greater)must have demonstrated compliance with the permitted NOX and CO emission limits using EPA Reference Test Methods(identified as Reference Method 7E and Reference Method 10,Of Reference Method 19(40 C.F.R.Part 60 Appendix A)or other test methods or procedures acceptable to the Division. The Division shall be notified at least 30 calendar days prior to the EPA Reference Test date, so that it may choose whether to observe the testing. The permittee shall measure nitrogen oxide(NO,)and carbon monoxide(CO)emissions in • the exhaust from the permanent replacement engine using a portable flue gas analyzer within seven (T) calendar days of commencing operation of the permanent replacement engine. Calibration of the analyzer shall be conducted according to manufacturer=s instructions. 123/0243/052 ver. 2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0499 Air Pollution Control Division INITIAL APPROVAL Page 8 In the absence of evidence to the contrary,results of the portable flue gas analyzer test shall be evidence of enforceable compliance or noncompliance of the permanent replacement engine with the emission limitations of the original engine. An exceedance of either the NO,or CO emission limitation during the initial portable flue gas analyzer test shall require a subsequent portable analyzer test indicating compliance with both the NO,and CO emission limitations within 14 calendar days of commencing operation of the replacement engine. Calibration gases shall be used to calibrate the portable analyzer for all tests conducted subsequent to the initial test. If portable flue gas analyzer results indicate compliance with both the NO,and CO emission limitations within the 14-day period,the permanent replacement engine will be considered to be in compliance for purposes of this AOS. If portable flue gas analyzer results fad to indicate the compliance of the permanent replacement engine with either the NO,or CO emission limitations within the 14-day period, the source will notify the Division in writing within 10 calendar da98 of the end of the 14-day period. Results of all testing that indicates noncompliance shall be submitted to the Division within 10 calendar days of the end of the 14 day period. The source will be required to conduct EPA Reference Test Methods(identified as Reference Method 7E and Reference Method 10, or Reference Method 19 (40 C.F.R. Part 60 Appendix A). hereinafter AEPA Reference Test Methods@)or other test methods or procedures acceptable to the Division within 45 calendar days of the end of the 14 day period allowed for the portable flue gas • analyzer testing. The Division shad be notified at least 30 calendar days prior to the EPA Reference Test date, so that it may choose whether to observe the testing. If the EPA Reference Tests indicate compliance with both the NO, and CO emission limitations,the permanent replacement engine will be considered to be in compliance for the purposes of this AOS. If the EPA Reference Tests fail to demonstrate compliance with either the NO, or CO emission limitations and in the absence of evidence to the contrary, the permanent replacement engine will be considered to be out of compliance for the purposes of this AOS from the date the replacement engine commenced operation untilale engine is taken off line. Results of all EPA Reference testing that indicate noncompliance shall be submitted to the Division within 14 calendar days after receipt of the test results. 4.2.2 Permanent 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. 4.2.3 The permittee shall maintain a log on-site to contemporaneously record the date of any permanent engine replacement,the manufacturer, model number, horsepower,and serial number of the engine(s)that are permanently replaced during the term of this permit,and the manufacturer,model number, horsepower,and serial number of the replacement engine. 4.2.4 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 appropriate APEN filing fee and a cover letter . explaining that the permittee is exercising an alternative operating scenario and is installing a permanent replacement engine shall accompany the APEN. 123/0243/052 ver. 2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0499 Air Pollution Control Division INITIAL APPROVAL Page 9 4.2.5 This procedure cannot be used for permanent engine replacement in the following situations: a. Replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. 4.2.6 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 4.2.7 Results of all tests conducted pursuant to this AOS shall be kept on site for five(5)years and made available to the Division upon request. 4.2.8 For comparison with an annual or short term emissions limit, the results of any testing required by this AOS shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies)in order Jo monitor compliance. If a source is not limited in its hours of operation, the test results shall be multiplied by the maximum number of hours in the month or year(8760),whichever applies. 4.3 Additional Sources Current State Air Quality Regulations do not allow for advanced New Source Review in the absence of discrete and verifiable Information concerning future installations. Therefore,any additional operational changes requiring new equipment at this facility not addressed • by these Alternative Operating Scenarios Ml need to undergo appropriate Regulation No.3 review procedures. • 123/0243/052 ver.2/00 DUKE ENERGY FIELD SERVICES,LP Colorado Department of Public Health and Environment • Permit No.01WE0499 Air Pollution Control Division INITIAL APPROVAL Page 10 Table 1 Internal Combustion Engine Information for the AOS Emission Replacement Engine Periodic Monitoring' Stack Test? Point • 001 (Exact replacement) See Footnote 1 -- No f ' For Title V operating permit sources utilizing this AOS,periodic monitoring shall be determined from the Division's Title V periodic monitoring grid. For Construction permit sources utilizing this AOS,periodic monitoring shall be as follows: Synthetic Minor source: For permanent engine replacement,once the original engine is replaced and the monitoring set forth in the body of the AOS is completed,quarterly portable monitoring for both NOX and CO must be instituted. Compliance for both the NOX and the CO limits must be demonstrated for four(4) consecutive quarters. If compliance is demonstrated for four(4)consecutive quarters,the required frequency of portable monitoring analysis shall become semi-annual. Frequency will revert back to quarterly if portable analyzer results indicate exceedance of the limitations for either pollutant. The required frequency of this monitoring will again go to semi-annual if portable analyzer results indicate compliance for four(4)consecutive quarters. Results of all portable analyzer analyses conducted shall be kept on site and made available to the Division upon request. • 123/0243/052 ver.2/00 • STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT ha' ‘ AIR POLLUTION CONTROL DIVISION IA If Li TELEPHONE: (303}692-3150 " k •1876 x CONSTRUCTION PERMIT PERMIT NO: O1 WE0500 INITIAL APPROVAL DATE ISSUED: SEPTEMBER 25, 2001 ISSUED TO: DUKE ENERGY FIELD SERVICES, LP.. THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural Gas Facility known as the Marla Compressor Station,located in the SE%of Sec 28-4N-64W, Weld County,Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: • One(1)Waukesha L 7042 GW,S/N 337712,Rated at 1478 HP,natural gas fired,internal combustion reciprocating engine equipped with a NSCR, AFR. This emission unit powers a natural gas compressor,stack number 53, C-135 THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S.(25-7-101 et seq),TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: 1. 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 minutesin any sixty consecutive minutes. Opacity shall be measured by EPA Method 9. (Reference: Regulation 1,Section II.A.1.& 4.) 2. The permit number shall be marked on the subject equipment for ease of identification.(Reference: Reg.3,Part B, IV.E.)(State only enforceable) 3. Emissions of air pollutants shall not exceed the following limitations(as calculated in the Division's preliminary analysis). Compliance with the annual limits shall be determined on a rolling(12)month total.By the end of each month a new twelve-month total is calculated based on the previous twelve months'data.The permit holder shall calculate monthly emissions and keep a compliance record on site for Division review: (Reference: Regulation 3,Part B, III.A.4). Nitrogen Oxides: 42.8 tons per year and 7,270.0 pounds per month Volatile Organic Compounds: 14.3 tons per year and 2,429.0 pounds per month Carbon Monoxide: 42.8 tons per year and 7,270.0 pounds per month • Note: Based on a fuel heating value of 1040 Btu/scf 123/0243/053 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01 WE0500 Air Pollution Control Division INITIAL APPROVAL Page 2 During the first twelve (12) months of operation, compliance with both the monthly and yearly emission limitations shall be required.After the first twelve(12)months of operation,compliance with only the yearly limitation shall be required. 4. This source shall be limited to a maximum consumption rate as listed below and all other activities, operational rates and numbers of equipment as stated in the application.Monthly records of the actual consumption rate shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Pad B,III.A.4) Consumption of natural gas as fuel shall not exceed 8.45 million scf per month and 101.4 million scf per year. During the first twelve (12) months of operation, compliance with both the monthly and yearly consumption limitations shall be required.After the first twelve(12)months of operation,compliance with only the yearly limitation shall be required.Compliance with the yearly consumption limits shall be determined on a rolling twelve(12)month total. -- 5. A source compliance test shall be conducted to measure the emission rate(s)for the pollutants listed below. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual end shall be submitted to the Division for review and approval at least thirty(30)days prior to testing. The protocol shall include manufacturers analysis of emissions at engine maximum and minimum loads,at site specific conditions. Engine operating parameters will be included in the analysis with emissions reported in parts per million dry volume and grams per • actual horsepower-hour(g/BHP-Hr.) or pounds per million BTU (Ib/MMBTU). No test shall be conducted without prior approval from the Division.Any stack 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. (Reference: Regulation 3,Part B.1V.H.3) Oxides of Nitrogen,Carbon Monoxide and Oxygen,using EPA approved methods. 6. Prior to the stack test being performed, the applicant shall submit to the Division the catalyst manufacturer,model number, serial number and specifications. 7. Prevention of Significant Deterioration(PSD)requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. My relaxation that increases the potential to emit above the applicable PSD threshold will require a kill PSD review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit is granted. 8, Operating Permit(OP)requirements shall apply to this source. An application to modify the existing Operating Permit for this facility shall be submitted within one year of the Initial Approval Date of this Construction Permit(Regulation 3, Part C). 9. A revised Air Pollutant Emission Notice(APEN)shall be filed:(Reference: Reg.3, Part A,IL.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year,a change in actual emissions of five(5) • tons per year or more,above the level reported on the last APEN;or 123/0243/053 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0500 Air Pollution Control Division INITIAL APPROVAL Page 3 For any non-criteria reportable pollutant: If the emissions increase by 50%or five(5)tons per year,whichever is less,above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility,process,or activity;or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment;or d. Whenever a permit limitation must be modified;or e. No later than 30 days before the existing APEN expires. 10. The applicant shall track emissions from all insignificant activities on a yearly basis.This information shall be made available to the Division for inspection upon request For thepurposes of this condition, insignificant activities shall be defined as any activity or equipment which @mits any amount but does not require an Air Pollutant Emission Notice(APEN). 11. Within one hundred and eighty days (180)after commencement of operation,compliance with the conditions contained on this permit shah be demonstrated to the Division. It is the permittee's responsibility to self certify compliance with the conditions.Failure to demonstrate compliance within 180 days may result in revocation of the permit.(Information on how to certify compliance was mailed • with the permit or can be obtained from the Division at 303-692-3209.) 12. The engine covered under this permit may be replaced in accordance with the provisions of the Altemative Operating Scenario listed in Attachment A. (Regulation 3.A, IV,A) 13. No atmospheric condensate tanks will be operated at this facility it 8 : By' .�/ L omas P. Mark James S.Geier P.E. Permit Engineer Unit Leader Notes to Permit Holder: 1) The fuel consumption limits and emission limits contained in this permit are based on the fuel consumption rates requested in the permit application. These limits may be revised upon request of the pem ittee providing there is no exceedence of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice(APEN)and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Upset Conditions and Breakdowns.The permittee shall notify the Division of any upset condition which causes a violation of any emission limit or limits stated in this permit as soon as possible,but no later than two(2)hours after the start of the next working day, followed by written notice to the Division explaining the cause of the occurrence and that proper action has been or is being taken to correct the conditions causing said violation and to prevent such excess emission in the future. 3) The following emissions of non-criteria reportable air pollutants are estimated based upon the material . consumptions as indicated in Condition No.3. This information is listed to inform the operator of the 123/0243/053 ver. 2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0500 Air Pollution Control Division INITIAL APPROVAL Page 4 Division's analysis of the specific compounds. This information is listed on the Division's emission inventory system. G.A.S.# SUBSTANCE EMISSIONS ILB/YR1 50-00-0 Formaldehyde 1,338.7 71-43-2 Benzene 516.6 75-07-0 Acetaldehyde 91.3 4) The emission levels contained in this permit are based on the following emission factors: Nitrogen Oxides* 3.0 grams per horsepower-hour Volatile Organic Compounds: 1.0 grams per horsepower-hour Carbon Monoxide: • 3.0 .grams per horsepower-hour 5) Operating Permit(OP)requirements shall apply to this source and shall require submittal of and issuance of an operating permit, under Regulation 3,Part C. 6) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (AOEN) associated with this permit is valid for a term of five years. The five year term for this APEN expires on May 15, 2006. A revised APEN shall be submitted no later than 30 days before the five year term expires. 7) This emission unit is classified as a: Synthetic minor source At a: Synthetic minor facility for MACT HH • At a: Major Title V facility • At a: Synthetic minor facility for PSD • 123/0243/053 ver.2/00 DUKE ENERGY HELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0500 Air Pollution Control Division INITIAL APPROVAL Page 5 GENERAL TERMS AND CONDITIONS: (IMPORTANT! READ ITEMS 5,6,7 AND 8) 1. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is • conditioned upon conduct of the activity,or construction,installation and operation of the source,In accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 2. Unless specifically stated otherwise,the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25.7-114.5(7xa),C.R.S. 3. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of,a condition hereof shall constitute a rejection of the entire permit and upon such occurrence,this permit shall be deemed denied ab lnitao. This permit may be revoked at any time prior to final approval by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Ad and regulations of the Air Quality Control Commission(AQCC), including failure to meet any express term or condition of the permit It the Division denies a permit,conditions imposed upon a permit are contested by the appicant,or the Division revokes a permit,the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 4. This permit and any required attachments must be retained and made available for irispection upon request at the location set forth herein. With respect to a portable source which is moved to a new location,a Copy d the Relocation Notice(required by law to be submitted to the APCD whenever a portable source is relocated)should be attached to this permit The permit may be reissued to a new owner by the APCD as provided In AQCC Regulation No.3, Part B, Section III.B.upon a request for transfer of ownership and the submittal of a revised APEN and the required fee_ 5. Issuance(initial approval)of an emission permit does not provide lint authority for this activity or operation of this source. Final approval of the permit must be secured from the APCD in writing In accondancewith the provisions of 25.7- 114.5(12xa)C.R.S. and AQCC Regulation No.3, Part B, Section N.H. Final approval cannot be granted until the • operation or activity commences and has been verified by the APCD as conforming mirg in all respects with the conditions of the permit. If the APCD so detormtnes,It will provide written documentation of such final approval,which does constitute -finer authority to operate. Compliance with the permit conditions most be demonstrated within 180 days after commencement of operation. 6. M5 PERMIT AUTOMATICALLY EXPIRES IF you(1)do not commence construction or operation within 18 months after either the date of issuance of this permit or the date on which such construction or activity was scheduled to commence as set forth In the permit,whichever is later,(2)discontinue construction for a period of 18 months or more:or (3)do not complete construction within a reasonable time of the estimated completion date. Extensions of the expiration date may be granted by the APCD upon a showing of good cause by the pernittee prior to the expiration date. 7. YOU MUST notify the APCD at least thirty days(fifteen days for portable sources)prior tocommencementofthe permitted operation or activity. Failure to do so is a violation of Section 25-7-114.5(12xa), C.RS. and AQCC Regulation No.3.Pan B. Section Will.. and can result in the revocation of the permit. You must demonstrate compliance with the permit conditions within 180 days after commencement of operation as stated In condition 5. 8. Section 25-7-114.7(2Xa),C.R.S.requires that all sources required to file en Air Pollution Emission Notice(APEN)must pay an annual fee to cover the costs of inspections and administration. Resource or activity is to be discontinued,the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification,annual fee billing will terminate. 9. Violation of the terms of a permit or of the provisions d the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative,civil or criminal enforcement actions under Sections 25-7-115 (enforcement),-121(Injunctions).-122(civil penalties),-122.1(criminal penalties), ATTACHMENT A Alternative Operating Scenarios The following Alternative Operating Scenario(AOS)for temporary and permanent engine replacement . has been reviewed in accordance with the requirements of Regulation No.3.,Part A,Section IV.A, Operational Flexibility-Alternative Operating Scenarios,and Regulation No.3, Part B,Construction 123/0243/053 ver. 2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No. 01 WE0500 Air Pollution Control Division INITIAL APPROVAL Page 6 Permits,and 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. For purposes of Regulation No. 3, Part B. Section IV.G.4.a., any engine replacement authorized under this AOS shall commence operation upon notation of same in the contemporaneous log as required below. Results of any testing required below shall be normalized for comparison to the applicable permitted emission limits. 1.1 Temporary Engine Replacement The following AOS is incorporated into a pemitttee's operating or construction permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair which requires the use of a temporary replacement engine(defined as In the same service for 90 days or less in any 12 month period). The compliance demonstrations made as part of this AOS are in addition to any compliance demonstrations required by the permit. 4.1.1. 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. • The permittee shall measure nitrogen oxide(NO,)and carbon monoxide(CO)emissions in the exhaust from the temporary replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the temporary replacement engine. Calibration of the analyzer shall be conducted according to manufacturer=s Instructions. In the absence of evidence to the contrary,results of the portable flue gas analyzer test shall be evidence of enforceable compliance or noncompliance of the temporary replacement engine with the emission limitations of the original engine. An exceedance of either the NO,or CO emission limitation during the initial portable flue gas analyzer test shall require a subsequent portable flue gas analyzer test Indicating compliance with both the NO, and CO emission limitations within 14 calendar days of commencing operation of the replacement engine. Calibration gases shall be used to calibrate the portable analyzer for all tests conducted subsequent to the initial test. If portable flue gas analyzer results indicate compliance with both the NO,and CO emission limitations within the 14-day period,the temporary replacement engine will be considered to be in compliance for purposes of this AOS from the time that the replacement engine commenced operation until the replacement engine is taken off line. If portable flue gas analyzer results fail to indicate the compliance with either the NO,or CO emission limitations within the 14-day period, the source will notify the Division in writing within 10 calendar days of the end of the 14-day period. In the absence of evidence to the contrary,the temporary replacement engine wil be considered to be out of compliance from the time that the temporary replacement engine commenced operation until the engine is taken off line. Results of all testing that indicates noncompliance shall be submitted to the • Division within 10 calendar days of the end of the 14 day period. 123/0243/053 ver.2100 DUKE ENERGY FIELD SERVICES,LP Colorado Department of Public Health and Environment • Permit No.01 WE0500 Air Pollution Control Division INITIAL APPROVAL Page 7 4.12 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. Potential emissions from the temporary replacement engine must be legs than or equal to the potential emissions 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. 4.1.3 Temporary replacement engines, whether of the same manufacturer, model, and horsepower,or of a different manufacturer,model,or horsepower,are subject to a0 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. 4.1.4 The permittee shall maintain a log on-site to contemporaneously record the start and stop date of any temporary engine replacement,the manufacturer,model number,horsepower, and serial number of the engine(s)that are temporarily replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. ,. -- 4.2 Permanent Engine Replacement The following AOS is incorporated into a permittee's operating or construction permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair which requires the use of a permanent replacement engine(defined as in the same service for more than 90 days in any 12 month period). The compliance demonstrations made as part of this AOS are in addition to any • compliance demonstrations required by the permit. 4.2.1 The permittee may permanently replace the existing compressor engine for the emission points specified in Table 1 with the manufacturer,model,and horsepower engines listed in Table 1 without modifying this permit. The periodic monitoring specified for the replacement engine shall be required. Within 180 days of permit issuance or within 180 days of the startup of a new source, whichever Is applicable, and prior to replacing the existing compressor engine for the emission points specified in Table 1, the existing engine (if it has a design rate of 150 horsepower or greater)must have demonstrated compliance with the permitted NOX and CO emission limits using EPA Reference Test Methods(identified as Reference Method 7E and Reference Method 10,or Reference Method 19(40 C.F.R.Part 60 Appendix A)or other test methods or procedures acceptable to the Division. The Division shall be notified at least 30 calendar days prior to the EPA Reference Test date, so that it may choose whether to observe the testing. The permittee shall measure nitrogen oxide(NO,)and carbon monoxide(CO)emissions in the exhaust from the permanent replacement engine using a portable flue gas analyzer within seven (7)calendar days of commencing operation of the permanent replacement engine. Calibration of the analyzer shall be conducted according to manufacturer=s instructions. In the absence of evidence to the contrary,results of the portable flue gas analyzer test shall be evidence of enforceable compliance or noncompliance of the permanent replacement engine with the emission limitations of the original engine. An exceedance of either the NO,or CO emission limitation during the initial portable flue gas • analyzer test shall require a subsequent portable analyzer test indicating compliance with both the NO,and CO emission limitations within 14 calendar days of commencing operation 123/0243/053 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01 WED500 Air Pollution Control Division INITIAL APPROVAL Page 8 of the replacement engine. Calibration gases shall be used to calibrate the portable analyzer for all tests conducted subsequent to the initial test. If portable flue gas analyzer results Indicate compliance with both the NO,and CO emission limitations within the 14-day period,the permanent replacement engine will be considered to be in compliance for purposes of this AOS. If portable flue gas analyzer results fail to indicate the compliance of the permanent replacement engine with either the NO,or CO emission limitations within the 14-day period, the source will notify the Division in writing within 10 calendar days of the end of the 14-day period. Results of all testing that indicates noncompliance shall be submitted to the Division within 10 calendar days of the end of the 14 day period. The source will be required to conduct EPA Reference Test Methods(identified as Reference Method TE and Reference Method 10, or Reference Method 19 (40 C.F.R. Part 60 Appendix A), hereinafter AEPA Reference Test Methods@)or other test methods or procedures acceptable to the Division within 45 calendar days of the end of the 14 day period allowed for the portable flue gas analyzer testing. The Division shall be notified at least 30 calendar days prior to the EPA Reference Test date, so that It may choose whether to observe the testing. If the EPA Reference Tests indicate compliance with both the NO, and CO emission limitations,the permanent replacement engine will be considered to be in compliance for the purposes of this AOS. • If the EPA Reference Tests fall to demonstrate compliance with either the NO, or CO emission limitations and in the absence of evidence to the contrary, the permanent replacement engine will be considered to be out of compliance for the purposes of this AOS from the date the replacement engine commenced operation until the engine is taken off line. Results of all EPA Reference testing that Indicate noncompliance shall be submitted to the Division within 14 calendar days after receipt of the test results. 4.2.2 Permanent 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. 4.2.3 The permittee shall maintain a log on-site to contemporaneouslp record the date of any permanent engine replacement, the manufacturer,model number, horsepower,and serial number of the engine(s)that are permanently replaced during the term of this permit,and the manufacturer,model number,horsepower,and serial number of the replacement engine. 4.2.4 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 appropriate APEN filing fee and a cover letter explaining that the permittee is exercising an alternative operating scenario and is installing a permanent replacement engine shall accompany the APEN. 4.2.5 This procedure cannot be used for permanent engine replacement in the following situations: a. Replacement of a grandfathered or permit exempt engine or an engine that is not subject • to emission limits. 4.2.6 The permittee shall agree to pay fees based on the normal permit processing rate for review 123/0243/053 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01 WE0500 Air Pollution Control Division INITIAL APPROVAL Page 9 of information submitted to the Division in regard to any permanent engine replacement. 4.2.7 Results of all tests conducted pursuant to this AOS shall be kept on site for five(5)years and made available to the Division upon request. 4.2.8 For comparison with an annual or short term emissions limit, the results of any testing required by this AOS 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 shall be multiplied by the maximum number of hours in the month or year(8760),whichever applies. 4.3 Additional Sources Current State Air Quality Regulations do not allow for advanced New Source Review in the absence of discrete and verifiable information concerning future installations. Therefore,any additional operational changes requiring new equipment atthis facility not addressed by these Alternative Operating Scenarios will need to undergo appropriate Regulation No.3 review procedures. • • 123/0243/053 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01 WE0500 Air Pollution Control Division INITIAL APPROVAL Page 10 Table 1 Internal Combustion Engine Information for the AOS Emission Replacement Engine Periodic Monitoring' Stack Test? Point 001 (Exact replacement) See Footnote 1 -. No ' For Title V operating permit sources utilizing this AOS,periodic monitoring shall be determined from the Division's Title V periodic monitoring grid. For Construction permit sources utilizing this AOS,periodic monitoring shall be as follows: Synthetic Minor source: For permanent engine replacement,once the original engine is replaced and the monitoring set forth in the body of the AOS is completed,quarterly portable monitoring for both NOX and CO must be Instituted. Compliance for both the NOX and the CO limits must be demonstrated for four(4) consecutive quarters. If compliance is demonstrated for four(4)consecutive quarters,the required frequency of portable monitoring analysis shall become semi-annual. Frequency wilt revert back to quarterly if portable analyzer results indicate exceedance of the limitations for either pollutant. The required frequency of this monitoring will again go to semi-annual if portable analyzer results Indicate compliance for four(4)consecutive quarters. Results of all portable analyzer analyses conducted shall be kept on site and made available to the Division upon request. • 123/0243/053 ver. 2/00 • STATE OF COLORADO 1t COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT ` =a AIR POLLUTION CONTROL DIVISION " TELEPHONE: (303) 692-3150 .`�. •1g7O CONSTRUCTION PERMIT PERMIT NO: 01 W E050I INITIAL APPROVAL DATE ISSUED: SEPTEMBER 25, 2001 ISSUED TO: DUKE ENERGY FIELD SERVICES, LP_ THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural Gas Facility known as the Mada Compressor Station,located in the SE%of Sec 28-4N-64W, Weld County,Colorado. • THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: One(1)Waukesha L 7042 GSI,SIN 383730,Rated at 1478 HP,natural gas fired,Internal combustion • • reciprocating engine equipped with a NSCR, AFR. This emission unit powers a natural gas compressor,stack number 54,C-151 THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S.(25-7.101 et seq),TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: 1. 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. Opacity shall be measured by EPA Method 9. (Reference:Regulation 1.Section II.A.1.& 4.) 2. The permit number shall be marked on the subject equipment for ease of identification.(Reference: Reg.3,Part B, IV.E.)(State only enforceable) 3. Emissions of air pollutants shall not exceed the following limitations(as calculated in the Division's preliminary analysis). Compliance with the annual limits shall be determined on a rolling(12)month total.By the end of each month a new twelve-month total Is calculated based on the previous twelve months'data.The permit holder shall calculate monthly emissions and keep a compliance record on site for Division review: (Reference: Regulation 3,Part B, III.A.4). Nitrogen Oxides: 42.8 tons per year and 7,270.0 pounds per month Volatile Organic Compounds: 14.3 tons per year and 2,429.0 pounds per month Carbon Monoxide: 42.8 tons per year and 7,270.0 pounds per month • Note: Based on a fuel heating value of 1040 Btu/scf 123/0243/054 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment Permit No.01 WE0501 Air Pollution Control Division • INITIAL APPROVAL Page 2 During the first twelve (12) months of operation, compliance with both the monthly and yearly emission limitations shall be required.After the first twelve(12)months of operation,compliance with ' only the yearly limitation shall be required. 4. This source shall be limited to a maximum consumption rate as listed below and all other activities, operational rates and numbers of equipment as stated in the application.Monthly records of the actual consumption rate shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3,Part B,III.A.A) Consumption of natural gas as fuel shall not exceed 8.45 million sd per month and 101.4 million set per year. During the first twelve (12) months of operation, compliance with both the monthly and yearly consumption limitations shall be required.After the first twelve(12)months of operation,compliance with only the yearly limitation shall be required.Compliance with the yearly consumption limits shall be determined on a rolling twelve(12)month total. -- 5. A source compliance test shall be conducted to measure the emission rates)for the pollutants listed below. 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. The protocol shall include manufacturers analysis of emissions at engine maximum and minimum loads,at site specific conditions. Engine operating parameters will be included in the analysis with emissions reported in parts per million dry volume and grams per actual horsepower-hour(g/BHP-Hr.) or pounds per million BTU (Ib/MMBTU). No test shall be • conducted without prior approval from the Division.Any stack 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. (Reference: Regulation 3, Part B.IV.H.3) Oxides of Nitrogen,Carbon Monoxide and Oxygen,using EPA approved methods. 6. Prior to the stack test being performed, the applicant shall submit to the Division the catalyst manufacturer,model number, serial number and specifications. 7. Prevention of Significant Deterioration(PSD)requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permrtcondition. My relaxation that increases the potential to emit above the applicable PSD threshold will require a full PSD review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit is granted. 8. Operating Permit(OP)requirements shall apply to this source. An application to modify the existing Operating Permit for this facility shall be submitted within one year of the Initial Approval Date of this Construction Permit(Regulation 3, Part C). 9. A revised Air Pollutant Emission Notice(APEN)shall be filed:(Reference: Reg.3, Part A,II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant For sources emitting less than 100 tons per year,a change in actual emissions of five(5) • tons per year or more,above the level reported on the last APEN;or 123/0243/054 ver.2/00 DUKE ENERGY FIELD SERVICES,LP Colorado Department of Public Health and Environment Permit No.01 WE0501 Air Pollution Control Division • INITIAL APPROVAL Page 3 For any non-criteria reportable pollutant: If the emissions increase by 50%or five(5)tons per year,whichever Is less,above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment;or d. Whenever a permit limitation must be modified;or e. No later than 30 days before the existing APEN expires. 10. The applicant shalt track emissions from all insignificant activities on a yearly basis.This information shall be made available to the Division for inspection upon request.For the-purposes of this condition, insignificant activities shall be defined as any activity or equipment which @mits any amount but does not require an Air Pollutant Emission Notice(APEN). 11. Within one hundred and eighty days(180)after commencement of operation,compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee's responsibility to self certify compliance with the conditions.Failure to demonstrate compliancewithin 180 days may result in revocation of the permit.(Information on how to certify compliance was mailed with the permit or can be obtained from the Division at 303-692-3209.) • 12. The engine covered under this permit may be replaced in accordance with the provisions of the Alternative Operating Scenario listed in Attachment A.(Regulation 3,A, IV,A) 13. No atmospheric condensate tanks will be operated at this facility Bye � �� By: 9 L. Thomas P. Mark James S.Geier P.E. Permit Engineer Unit Leader ti Notes to Permit Holder: 1) The fuel consumption limits and emission limits contained in this permit are based on the fuel consumption rates requested In the permit application. These limits may be revised upon request of the pennittee providing there is no exceedence of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice(APEN)and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E.Upset Conditions and Breakdowns.The permittee shall notify the Division of any upset condition which causes a violation of any emission limit or limits stated in this permit as soon as possible,but no later than two(2)hours after the start of the next working day, followed by written notice to the Division explaining the cause of the occurrence and that proper action has been or is being taken to correct the conditions causing said violation and to prevent such excess emission in the future. 3) The following emissions of non-criteria reportable air pollutants are estimated based upon the material • consumptions as indicated in Condition No.3. This information is listed to inform the operator of the 123/0243/054 ver, 2100 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment Permit No. 01 WE0501 Air Pollution Control Division • INITIAL APPROVAL Page 4 Division's analysis of the specific compounds. This information is listed on the Division's emission inventory system. C.A.S. # SUBSTANCE EMISSIONS JLB/YRI 50-00-0 Formaldehyde 1338.7 71-43.2 Benzene 516.6 75-07-0 Acetaldehyde 91.3 4) The emission levels contained in this permit are based on the following emission factors: Nitrogen Oxides: 3.0 grams per horsepower-hour Volatile Organic Compounds: 1.0 grams per horsepower-hour Carbon Monoxide: 3.0 grams per horsepower-hour 5) Operating Permit(OP)requirements shall apply to this source and shall require submittal of and issuance of an operating permit,under Regulation 3,Part C. -- 6) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years. The five year term for this APEN expires on May 15, 2006. A revised APEN shall be submitted no later than 30 days before the five year term expires. 7) This emission unit is classified as a: Synthetic minor source At a: Synthetic minor faddy for MACT HH • At a: Major Title V facility At a: Synthetic Minor Facility for PSD . 12310243/054 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment Permit No.D1 WE0501 Air Pollution Control Division • INITIAL APPROVAL Page 5 GENERAL TERMS AND CONDITIONS: (IMPORTANT! READ ITEMS 5,6,7 AND 8) 1. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity,of construction,installation and operation of the source,In accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 2. Unless specifically stated otherwise,the general and specific conditions contained In this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25.7-114.5(7xa).C.RS. 3. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of,a condition hereof shall constitute a rejection of the entire permit and upon such occurrence,this permit shall be deemed denied eh inttio. This permit may be revoked at any time prior to final approval by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission(A0CC), Including failure to meet arty express term or condition of the permit if the Division denies a permit,conditions imposed upon a permit are contested by the applcant,or the Division revokes a perm,the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 4. This permit and any required attachments must be retained and made available for inspection upon request at the location set forth herein. With respect toe portable seine which Is moved to a new location,a copy of the Relocation Notice(required by law to be submitted to the APCD whenever portable source Is rebcated)shodd be attached to this permit The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No.3, Part B. Section 111.8.upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 5. Issuance(initial approval)of an emission permit does not provide"finer authaty for this activity or operation of this source. Final approval of the permit must be seared from the APCD in writing In accordance with the provisions of 25-7- 114.5(12Xa) C.RS. and AQCC Regulation No.3,Part B.Section IV.H. Final approval 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. If the APCD so deter mines,it will provide written documentation of such final approval,wNCh does constitute lunar authority to operate.Compliance with the pemnt conditions must be demonstrated within 180 days after commencement of operation. 6. THIS PERMIT AUTOMATICALLY EXPIRES IF you(1)do not commerce construction or operation within 18 months after either the date of issuance of this permit or the date on which such construction or activity was scheduled to commence as set forth in the permit,whichever is later;(2)discontinue construction nstructionforaperiodof18monthsormore;or (3)do not complete construction within a reasonable time of the estimated completion date. Extensions of the expiration date may be granted by the APCD upon a showing of good cause by the-pens tee prior to the expiration date. 7. YOU MUST notify the APCD at least thirty days(fifteen days for portable sources)prior to commencement of the permitted operation or activity. Failure to do so Is a violation of Section 25.7-114.5(12Xa), C.R.S. and AQCC Regulation No.3, Part B. Section IV.H.1., and can result In the revocation of the permit. You must demonstrate compliance with the permit conditions within 180 days alter commencement of operation as stated In cond0/on 5. 8. Section 25.7-114.7(2Xa),C.RS.requires that ail sources required to fide an Air Pollution Emission Notice(APEN)must pay en annual fee to cover the costs of Inspections and administration. tf a source or activity Is to be discontinued,the owner must notify the Division in writing requesting a cancellation ofthe permit. Upon notification,annual fee billing will terminate. 9. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative,civil or criminal enforcement actions under Sections 25-7-115 (enforcement),-121 (injunctions),-122(civil penalties).-122.1(criminal penalties).C.RS. • 123/0243/054 ver.2/00 DUKE ENERGY FIELD SERVICES,LP Colorado Department of Public Health and Environment Permit No. 01WE0501 Air Pollution Control Division . INITIAL APPROVAL Page 6 ATTACHMENT A Alternative Operating Scenarios The following Alternative Operating Scenario(AOS)for temporary and permanent engine replacement has been reviewed In accordance with the requirements of Regulation No. 3.,Part A,Section IV.A, Operational Flexibility-Alternative Operating Scenarios,and Regulation No.3, Part B,Construction Permits,and 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. For purposes of Regulation No. 3, Part 8, Section IV.G.4.a., any engine replacement authorized under this AOS shah commence operation upon notation of same in the contenq oraneous log as required below. Results of any testing required below shall be normalized for comparison to the applicable permitted emission limits. 1.1 Temporary Engine Replacement The following AOS is Incorporated Into a permittee's operating or construction permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair which requires the use of a temporary replacement engine(defined as in the same service for 90 days or less in any 12 month period). The compliance demonstrations made as part of this AOS are in addition to any compliance demonstrations required by the permit. 4.1.1. 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. The permittee shall measure nitrogen oxide(NO()and carbon monoxide(CO)emissions in the exhaust from the temporary replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the temporary replacement engine. Calibration of the analyzer shall be conducted according to manufacturer=s instructions. In the absence of evidence to the contrary,results of the portable flue gas analyzer test shall be evidence of enforceable compliance or noncompliance of the temporary replacement engine with the emission limitations of the original engine. An exceedance of either the NO,or CO emission limitation during the initial portable flue gas analyzer test shall require a subsequent portable flue gas analyzer test indicating compliance with both the NO, and CO emission limitations within 14 calendar days of commencing operation of the replacement engine. Calibration gases shall be used to calibrate the portable analyzer for all tests conducted subsequent to the initial test. If portable flue gas analyzer results indicate compliance with both the NO,and CO emission limitations within the 14-day period,the temporary replacement engine will be considered to be in compliance for purposes of this AOS from the time that the replacement engine commenced operation until the replacement engine is taken off line. • 123/0243/054 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment Permit No.OtWE0501 Air Pollution Control Division • INITIAL APPROVAL Page 7 If portable flue gas analyzer results fall to Indicate the compliance with either the NO,or CO emission limitations within the 14-day period, the source will notify the Division in writing within 10 calendar days of the end of the 14-day period. In the absence of evidence to the contrary,the temporary replacement engine will be considered to be out of compliance from the time that the temporary replacement engine commenced operation until the engine is taken off line. Results of all testing that indicates noncompliance shall be submitted to the Division within 10 calendar days of the end of the 14 day period. 4.1.2 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. Potential emissions from the temporary replacement engine must be less than or equal to the potential emissions 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. 4.1.3 Temporary replacement engines, whether of the same manufacturer, model, and horsepower,or of a different manufacturer,model,or horsepower,are subject to all federally applicable and state-only requirements set forth In this pen nitlincluding monitoring and record keeping), and shall be subject to any shield afforded by this permit. 4.1.4 The permittee shall maintain a log on-site to contemporaneously record the start and stop date of any temporary engine replacement,the manufacturer,model number,horsepower, and serial number of the engine(s) that are temporarily replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. 4.2 Permanent Engine Replacement The following AOS is incorporated into a permittee's operating or construction permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair which requires the use of a permanent replacement engine(defined as in the same service for more than 90 days in any 12 month period). The compliance demonstrations made as part of this AOS are in addition to any compliance demonstrations required by the permit. 4.2.1 The permittee may permanently replace the existing compressor engine for the emission points specified in Table 1 with the manufacturer,model,and horsepower engines listed in Table 1 without modifying this permit. The periodic monitoring specified for the replacement engine shall be required. Within 180 days of permit issuance or within 180 days of the startup of a new source, whichever is applicable, and prior to replacing the existing compressor engine for the emission points specified in Table 1, the existing engine (if it has a design rate of 150 horsepower or greater)must have demonstrated compliance with the permitted NOX and CO emission limits using EPA Reference Test Methods(identified as Reference Method 7E and Reference Method 10,or Reference Method 19(40 C.F.R.Part 60 Appendix A)or other test methods or procedures acceptable to the Division. The Division shall be notified at least 30 calendar days prior to the EPA Reference Test date, so that it may choose whether to observe the testing. The permittee shall measure nitrogen oxide(NO,)and carbon monoxide(CO)emissions in the exhaust from the permanent replacement engine using a portable flue gas analyzer within • seven (7)calendar days of commencing operation of the permanent replacement engine. Calibration of the analyzer shall be conducted according to manufacturer=s instructions. 123/0243/054 ver. 2/00 DUKE ENERGY FIELD SERVICES,LP Colorado Department of Public Health and Environment Permit No.01 WE0501 Air Pollution Control Division • INITIAL APPROVAL Page 8 In the absence of evidence to the contrary,results of the portable flue gas analyzer test shall be evidence of enforceable compliance or noncompliance of the permanent replacement engine with tile emission limitations of the original engine. An exceedance of either the NO,or CO emission limitation during the initial portable flue gas analyzer test shall require a subsequent portable analyzer test indicating compliance with both the NO,and CO emission limitations within 14 calendar days of commencing operation of the replacement engine. Calibration gases shall be used to calibrate the portable analyzer for all tests conducted subsequent to the initial test. If portable flue gas analyzer results indicate compliance with both the NO,and CO emission limitations within the 14-day period,the permanent replacement engine will be considered to be in compliance for purposes of this AOS. If portable flue gas analyzer results fad to indicate the compliance of the permanent replacement engine with either the NO,or CO emission limitations within the 14-day period, the source will notify the Division In writing within 10 calendar days of the end of the 14-day period. Results of all testing that Indicates noncompliance shall be submitted to the Division within 10 calendar days of the end of the 14 day period. The source will be required to conduct EPA Reference Test Methods(identified as Reference Method 7E and Reference Method 10, or Reference Method 19 (40 C.F.R. Part 60 Appendix A), hereinafter AEPA Reference Test Methods@)or other test methods or procedures acceptable to the Division within 45 calendar days of the end of the 14 day period allowed for the portable flue gas • analyzer testing. The Division shall be notified et least 30 calendar days prior to the EPA Reference Test date,so that ft may choose whether to observe the testing. If the EPA Reference Tests indicate compliance with both the NO, and CO emission limitations,the permanent replacement engine will be considered to be in compliance for the purposes of this AOS. If the EPA Reference Tests fail to demonstrate compliance with either the NO, or CO emission limitations and in the absence of evidence to the contrary, the permanent replacement engine will be considered to be out of compliance for the purposes of this AOS from the date the replacement engine commenced operation until the engine is taken off line. Results of all EPA Reference testing that indicate noncompliance shall be submitted to the Division within 14 calendar days after receipt of the test results. 4.2.2 Permanent replacement engines are subject to all federahy 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 4.2.3 The permittee shall maintain a log on-site to contemporaneously record the date of any permanent engine replacement, the manufacturer, model number, horsepower, and serial number of the engine(s)that are permanently replaced during the term of this permit,and the manufacturer,model number,horsepower,and serial number of the replacement engine. 4.2.4 An Air Pollutant Emissions Notice(APEN)that includes the specific manufacturer,model and serial number and horsepower of the permanent replacement engine shall be flied with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The appropriate APEN fling fee and a cover letter • explaining that the permittee is exercising an alternative operating scenario and is Installing a permanent replacement engine shall accompany the APEN. 123/0243/054 ver. 2/00 DUKE ENERGY FIELD SERVICES,LP Colorado Department of Public Health and Environment • Permit No. 01 WE0501 Air Pollution Control Division INITIAL APPROVAL Page 9 4.2.5 This procedure cannot be used for permanent engine replacement in the following situations: a. Replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. 4.2.6 The perrnittee 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. 4.2.7 Results of all tests conducted pursuant to this AOS shall be kept on site for five(5)years and made available to the Division upon request. 4.2.8 For comparison with an annual or short term emissions limit, the results of any testing required by this AOS shalt be convened 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 shall be multiplied by the maximum number of hours in the month or year(8760),whichever applies. 4.3 Additional Sources Current State Air Quality Regulations do not allow for advanced New Source Review in the absence of discrete and verifiable Information concerning future installations. Therefore,any additional operational changes requiring new equipment at this facility not addressed • by these Alternative Operating Scenarios will need to undergo appropriate Regulation No.3 review procedures. • 12310243/054 ver. 2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01 WE0501 Air Pollution Control Division INITIAL APPROVAL Page 10 Table 1 Internal Combustion Engine Information for the AOS Emission Replacement Engine Periodic Monitoring' Stack Test? Point 001 (Exact replacement) See Footnote 1 -. No • ' For Title V operating permit sources utilizing this AOS, periodic monitoring shall be determined from the Division's Title V periodic monitoring grid. For Construction permit sources utilizing this AOS,periodic monitoring shall be as follows: Synthetic Minor source: For permanent engine replacement, once the original engine is replaced and the monitoring set forth in the body of the AOS is completed,quarterly portable monitoring for both NOX and CO must be instituted. Compliance for both the NOX and the CO limits must be demonstrated for four(4) consecutive quarters. If compliance is demonstrated for four(4)consecutive quarters,the required frequency of portable monitoring analysis shall become semi-annual. Frequency will revert back to quarterly if portable analyzer results indicate exceedance of the limitations for either pollutant. The required frequency of this monitoring will again go to semi-annual if portable analyzer results indicate compliance for four(4)consecutive quarters. Results of all portable analyzer analyses conducted shall be kept on site and made available to the Division upon request. • 123/0243/054 ver. 2/00 STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT ° >; AIR POLLUTION CONTROL DIVISION TELEPHONE: (303)692-3150 ;�,�• ** •ieac CONSTRUCTION PERMIT PERMIT NO: 01WE0502 INITIAL APPROVAL DATE ISSUED: sn"maiR 25, 2001 ISSUED TO: Duke Energy Field Services, LP THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural gas compression facility known as the Marla Compressor Station,located In the SE`/.of Sec 28-4N-64W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: • Fugitive equipment leaks from the Marla Compressor Station. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S.(25-7-101 et seq),TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: 1. 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. Opacity shall be measured by EPA Method 9. (Reference:Regulation 1, Section II.A.1.8. 4.) 2. Emissions of air pollutants shall not exceed the following limitations(as calculated in the Division's preliminary analysis). Compliance with the annual limits shall be determined one rolling(12)month total.By the end of each month a new twelve-month total is calculated based on the previous twelve months'data.The permit holder shall calculate monthly emissions and keep a compliance record on site for Division review: (Reference: Regulation 3,Part B, III.A.4). Volatile Organic Compounds: 8.2 tons per year and 1393.0 pounds per month Compliance with the annual limits shall be determined on a rolling (12) month total. 3. This source shall be limited to a maximum equipment configuration as listed below and all other activities,operational rates and numbers of equipment as stated in the application. Records of the actual equipment configuration shall be maintained by the applicant and made available to the Division for Inspection upon request. (Reference: Regulation 3,Part B,IIIA.4) • Valves- 461 Pump/Compressor Seals: 2 Connectors 1008 Safety Valves: 48 Flanges/Connectors. 294 123/0243/056 ver.2/00 Duke Energy Field Services,LP Colorado Department of Public Health and Environment • Permit No.01WE0502 Air Pollution Control Division INITIAL APPROVAL Page 2 4. Prior to final approval being issued,the applicant shall submit to the Division for approval a compliance plan,containing an operational and maintenance plan,along with recordkeeping results,that outlines how the applicant will maintain compliance on an ongoing basis with the requirements of this permit. The compliance plan shall commence at startup. (Reference: Reg. 3, Part B,IV.B.2). 5. Operating Permit(OP)requirements shall apply to this source. 6. A revised Air Pollutant Emission Notice(APEN)shall be filed: (Reference: Reg.3, Part A,II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year.a change in actual emissions of five(5) tons per year or more,above the level reported on the last APEDI1 or For any non-criteria reportable pollutant: If the emissions increase by 50%or five(5)tons per year,whichever is less,above the level reported on the last APEN submitted to the Division. • b. Whenever there is a change in the owner or operator of any facility, process,or activity;or c. Whenever new control equipment is Installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified;or e. No later than 30 days before the existing APEN expires. 7. Within one hundred and eighty days (180)after commencement of operation, compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee's responsbaity to self certify compliance with the conditions.Failure to demonstrate compliance within 180 days may result in revocation of the permit.(Information on how to certify compliance was mailed with the permit or can be obtained from the Division at 303-692-3209.) 8. Construction of this source must commence within 18 months of initial approval permit issuance date or within 18 months of date on which such construction or activity was scheduled to commence as stated in the application. If commencement does not occur within the stated time the permit will expire on MARCH 25. 2003 (See General Condition No.6.,Item 1.) (Reference:Regulation 3,Part B, IV.G.4.) 9. No atmospheric condensate tanks will be operated at this facility By: // &Can% Thomas P. Mark James S. Geier P.E. • Permit Engineer Unit Leader 12310243/056 ver. 2/00 Duke Energy Field Services,LP Colorado Department of Public Health and Environment • Permit No.01WE0502 Air Pollution Control Division INITIAL APPROVAL Page 3 Notes to Permit Holder: • 1) The production or raw material processing limits and emission limits contained in this permit are based on the production/processing rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedence of arty specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice(APEN)and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Upset Conditions and Breakdowns.The permittee shall notify the Division of any upset condition which causes a violation of any emission limit or limits stated in this permit as soon as possible,but no later than two(2)hours after the start of the next working day. followed by written notice to the Division explaining the cause of the occurrence and Thal proper action has been or is being taken to correct the conditions causing said violation and to prevent such excess emission in the future. -- 3) The following emissions of non-criteria reportable air pollutants we estimatedbased upon the material consumptions as indicated in Condition No.3. This information is listed to inform the operator of the Division's analysis of the specific compounds. This Information is listed on the Division's emission inventory system. 4) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN)associated with this • permit is valid for a term of five years. The five-year tern for this APEN expires on March 1, 2006. A revised APEN shall be submitted no later than 30 days before the five-year term expires. 5) This emission unit is classified as a: Minor source At a: Synthetic minor facility for MACT HH At a: Major Title V facility At a - Synthetic Minor Facility for PSD • 123/0243/056 ver.2/00 Duke Energy Field Services, LP Colorado Department of Public Health and Environment • Permit No.01WE0502 Air Pollution Control Division INITIAL APPROVAL Page 4 GENERAL TERMS AND CONDITIONS: (IMPORTANT! READ ITEMS 5,6,7 AND 8) 1. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and Is conditioned upon conduct of the activity,or construction,installation and operation of the source,in accordancewith this information and with representations made by the applicant or applicant's agents. It Is valid only for the equipment and operations or activity specifically identified on the permit. 2. Unless specifically stated otherwise,the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25.7.114.5(7)(a),C.R.S. 3. Each and every condition of this permit is a material part hereof and is not severable. My challenge to or appeal of,a condition hereof shall constitute a rejection of the entire permit and upon such occurrence,this permit shall be deemed denied ab info. This permit may be revoked at any tine prior to final approval by the Air Pollution Control Division (APCD) on grounds set forth In the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission(AQCC),including failure to meet any express term or condition of the permit t the Division denies a permit,conditions imposed upon a permit are contested by the applicant,or the Division revokes a permit,the applicant or owner or operator of a source may request a hearing before the AQCC for review ofthe Division's action. 4. This permit and any required attachments must be retained and made available for Inspection upon request at the location set forth herein. With respect to a portable source which is moved to a new location,a copy of the Relocation Notice(required by law to be submitted to the APCD whenever portable source is relocated)should be attached to this permit. The permit may be reissued to a new owner by the APCD as provided In AQCC Regulation No.3,Part B, Section DLR.upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 5. Issuance(initial approval)d an emission permit does not provide liner authority for this activity or operation of this source. Final approval of the permit must be secured Fran the APCD in writing In accordance with the provisions of 25-7- • 114.5(12Xa)C.RS. end AQCC Regulation No.3, Pad B, Section IV.H. Final approval 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 penct lf the APCD so determines,it wiN provide written documentation of such final approval,which does constitute lunar authority to operate_Compliance with the perm conditions must be demonstrated within 180 days after commencement of operation. 6. THIS PERMIT AUTOMATICALLY EXPIRES IF you(1)do not apmmence construction or operation within 18 months after either the date of Issuance of this permit or the date on with such construction or activity was scheduled to commence as set forth in the permit,whichever is later,(2)discontinue construction fora period of 18 morphs a more:or (3)do not complete construction within a reasonable time of the estimated completion date. Extensions of the expiration date may be granted by the APCD upon a showing of good cause by the permitee prior to the expiration date. 7. YOU MUST notify the APCD at least thirty days(fifteen days for portable sources)prior to commencement ofthe permitted operation or activity. Failure to do so Is a violation of Section 25-7-114n5(12Xa), C.RS. and AQCC Regulation No.3, Pan B, Section IV.H.1.,and can result n the revocation of the permit. You must demonstrate compliance with the permit conditions within 180 days after commencement of operation as stated in condition 5. 8. Section 25-7-114.7(2)(a),C.R.S.requires that alt sources required to file an Mr Pollution Emission Notice(APEN)must pay an annual fee to cover the costs of inspections ardadministration. If a source Of activity Is to be discontinued,the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification,annual fee billing will terminate. 9. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result In administrative,civil or criminal enforcement actions under Sections 25-7-115 (enforcement),-121 (injunctions),-122(evil penalties),-122.1(criminal penalties),C.R.S. • 123/02431056 ver.2/00 • STATE Of COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AT AIR POLLUTION CONTROL DIVISION TELEPHONE:(303) 6923150 `1176' CONSTRUCTION PERMIT PERMIT NO: 01WE0503 INITIAL APPROVAL DATE ISSUED: SEPTEMBER 25, 2001 ISSUED TO: DUKE ENERGY FIELD SERVICES, LP, THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural Gas Facility known as the Marla Compressor Station,located in the SE of Sec 28-4N-64W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: • One (1) Waukesha L 7044 GSI, S/N unknown, Rated at 1680 HP, natural gas fired, internal combustion reciprocating engine equipped with a NSCR,AFR. This emission unit powers a natural gas compressor,stack number 59, P-109 THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S.(25-7-101 et seq),TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: 1. Visible emissions shall not exceed twenty peroent(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 minutesin any slaty consecutive minutes. Opacity shall be measured by EPA Method 9. (Reference: Regulation 1, Section II.A.1.& 4.) 2. The permit number shall be marked on the subject equipment for ease of identification.(Reference: Reg.3, Part B,IV.E.)(State only enforceable) 3. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). Compliance with the annual limits shall be determined on a rolling(12)month total.By the end of each month a new twelve-month total is calculated based on the previous twelve months'data.The permit holder shall calculate monthly emissions and keep a compliance record on site for Division review: (Reference: Regulation 3, Part B, III.A.4). Nitrogen Oxides: 32.4 tons per year and 5,504.0 pounds per month Volatile Organic Compounds: 16.2 tons per year and 2,752.0 pounds per month Carbon Monoxide: 32.4 tons per year and 5,504.0 pounds per month • Note: Based on a fuel heating value of 1040 Btu/scf 123/0243/059 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0503 Air Pollution Control Division INITIAL APPROVAL Page 2 During the first twelve (12) months of operation, compliance with both the monthly and yearly emission limitations shall be required.After the first twelve(12)months of operation,compliance with • only the yearly limitation shall be required. 4. This source shall be limited to a maximum consumption rate as listed below and all other activities, operational rates and numbers of equipment as stated in the application.Monthly records of the actual consumption rate shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B,III.A.4) Consumption of natural gas as fuel shall not exceed 9.21 million scf per month and 110.5 million scf per year. During the first twelve (12) months of operation, compliance with both the monthly and yearly consumption limitations shall be required.After the first twelve(12)months of operation,compliance with only the yearly limitation shall be required.Compliance with the yearly consumption limits shall be determined on a rolling twelve(12)month total. - 5. A source compliance test shall be conducted to measure the emission rate(s)for the pollutants listed below. 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. The protocol shall Include manufacturers analysis of emissions at engine maximum and minimum loads,at site specific conditions. Engine operating parameters will be included in the analysis with emissions reported In parts per million dry volume and grams per • actual horsepower-hour(g/BHP-Hr.) or pounds per million BTU (Ib/MMBTU). No test shall be conducted without prior approval from the Division.Any stack 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. (Reference:Regulation 3, Part B.IV.H.3) Oxides of Nitrogen,Carbon Monoxide and Oxygen,using EPA approved methods. 6. Prior to the stack test being performed, the applicant shall submit to the Division the catalyst manufacturer, model number, serial number and specifications. 7. Prevention of Significant Deterioration(PSD)requirements shall apply to tba source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. My relaxation that increases the potential to emit above the applicable PSD threshold will require a full PSD review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit Is granted. 8. Operating Permit(OP)requirements shall apply to this source. An application to modify the existing Operating Permit for this facility shall be submitted within one year of the start up date of this emission unit(Regulation 3,Part C). 9. A revised Air Pollutant Emission Notice(APEN)shall be fled:(Reference: Reg.3,Part A,ll,C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year,a change in actual emissions of five(5) • tons per year or more, above the level reported on the last APEN;or • 123/0243/0659 ver. 2/00 DUKE ENERGY FIELD SERVICES,LP Colorado Department of Public Health and Environment • Permit No.01WE0503 Air Pollution Control Division INITIAL APPROVAL Page 3 For any non-criteria reportable polutant: If the emissions increase by 50%or five(5)tons per year,whichever is less,above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility,process, or activity;or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified;or e. No later than 30 days before the existing ADEN expires. 10. The applicant shaft track emissions from all insignificant activities on a yearly basis.This information shall be made available to the Division for inspection upon request.For thepurposes of this condition, insignificant activities shall be defined as any activity or equipment which emits any amount but does not require an Air Pollutant Emission Notice(APEN). 11. Within one hundred and eighty days(180)after commencement of operation,compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee's responsibility to self certify compliance with the conditions.Failure to demonstrate compliance within 180 days may result in revocation of the permit.(Information on how to certify compliance was mailed • with the permit or can be obtained torn the Division at 303-692-3209.) 12. Construction of this source must commence within 18 months of initial approval permit issuance date or within 18 months of date on which such construction or activity was scheduled to commence as stated in the application. If commencement does not occur within the stated time the permit will expire on MARCH 25, 2003 (See General Condition No,6., Item 1.) (Reference: Regulation 3,Part B. IV.G.4.) 13. Before startup,a compliance plan,containing art operational and maintenance plan,outlining how the applicant will maintain compliance with the requirements of this permit, shall be submitted to the Division for approval. The compliance plan shall commence at startup. At the end of six(6)months of operation,the compliance plan recordkeeping results,shall be submitted to the Division. Annual compliance records shall be maintained by the applicant be made available to the Division for inspection upon request. 14. The serial number of the subject equipment shall be provided to the Division prior to Final Approval. (Reference: Reg. 3, Part 8, WV,E.) 15. The engine covered under this permit may be replaced in accordance with the provisions of the Alternative Operating Scenario listed in Attachment A.(Regulation 3,A, IV,A) 16. No atmospheric condensate tanks will be operated at this facility Thomas P.Mark James S. Geier P.E. Permit Engineer Unit Leader • 123/0243/0659 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No. 01WE0503 Air Pollution Control Division INITIAL APPROVAL Page 4 Notes to Permit Holder: • 1) The fuel consumption limits and emission limits contained in this permit are based on the fuel consumption rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedence of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice(APEN)and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Upset Conditions and Breakdowns.The permittee shall notify the Division of any upset condition which causes a violation of any emission limit or limits stated In this permit as soon as possible,but no tater than two(2)hours after the start of the next working day, followed by written notice to the Division explaining the cause of the occurrence and that proper action has been or is being taken to correct the conditions causing said violation and to prevent such excess emission in the future. - 3) The following emissions of non-criteria reportable air pollutants are estimated based upon the material consumptions as indicated in Condition No.3. This information is listed to inform the operator of the Division's analysis of the specific compounds. This information is listed on the Division's emission inventory system. C.A.S.# SUBSTANCE EMISSIONS ILBA'RI • 50-00-0 Formaldehyde 1,5242 71-43-2 Benzene 585.8 75-07-0 Acetaldehyde 104.6 4) The emission levels contained in this permit are based on the following emission factors: Nitrogen Oxides' 2..0 grams per horsepower-hour Volatile Organic Compounds: 1.0 grams per horsepower-hour Carbon Monoxide: 2.0 grams per horsepower-hour 5) Operating Permit(OP)requirements shall apply to this source and shall require submittal of and issuance of an operating permit, under Regulation 3, Part C. 6) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN)associated with this permit is valid for a term of five years. The five year term for this APEN expires on May 15, 2006. A revised APEN shall be submitted no later than 30 days before the five year term expires. 7) This emission unit is classified as a: Synthetic minor source At a: Synthetic minor facility for MACT HH At a: Major Title V facility At a: Synthetic minor facility for PSD • 123/0243/0659 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0503 Air Pollution ControlDivision INITIAL APPROVAL Page 5 GENERAL TERMS AND CONDITIONS: (IMPORTANT! READ ITEMS 5.6,7 AND 8) 1. This permit is issued in reliance upon the accuracy and completeness of Information supplied by the applicant and is conditioned upon conduct of the activity.or construction,installation and operation of the source,in accordance with this information and with representations made by the applicant or applicants agents. It Is valid only for the equipment and operations or activity specifically identified on the permit. 2. Unless spedlically stated otherwise,the general and specific conditions contained in this permit have been detemined by the APCD to be necessary to assure compliance with the provisions d Section 25.7-114.5(7xa),C.R.S. 3. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of,a condition hereof shall constitute a rejection of the entire permit and upon such occurrence,this permit shall be deemed denied orb intio, This permit may be revoked at any time prior to final approval by the Air Pollution Control Division (APCD) on grounds set forth In the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission(AQCC),including failure to meet any express tens or condition of the permit. If the Division denies a permit,concitions imposed upon a permit are contested by the applicant,or the Division revokes a permit,the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 4. This permit and any required attachments must be retained and made available for Inspection upon request at the location set forth herein. With respect to a portable sotroe which is moved to a new location,a copy of the Relocation Notice(required by law to be submitted to the APCD whenever a portable source Is relocated)should be attached to this permit The permit may be reissued to a new owner by the APCD as provided In AQCC Regulation No.3, Part B, Section 11I.B.upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 5. issuance(initial approval)of an emission permit does not provide'tinar authority for this activity or operation of this source. Final approval of the permit must be seared from the APCD Inwriting In accordance wihthe provisions of 2S7- 114.5(12Xa)C.RS. and AQCC Regulation No.3,Part B, Section N.H. Final approval cannot be granted until the • operation or activity commences and has been verified by the APCD as conforming h all respells with the conditions of the permit. If the APCD so determines,it MN provide written documentation of such final approval,which does constitute 'finer authority to operate. Compliance with the permit conditions must be demonstrated within 180 days after commencement of operation. 6. THIS PERMIT AUTOMATICALLY EXPIRES IF you(1)do not commence construction or operation within 18 months after either the date of issuance of this permit or the date on which such construction or activity was scheduled to commence as set forth In the permit,whichever is later,(2)discontinue construction fora period of 18 months or more:or (3)do not complete construction within a reasonable time ofthe estimated completion date. Extensions of the expiration dale may be granted by the APCD upon a showing of good cause by the permittee prior to the expiration date. 7. YOU MUST notify the APCD at least thirty days(fifteen days for portable source)prior to commencement of the permitted operation or activity. Failure to do so is a violation of Section 25-7-114.5(12)(a), C.R.S. and A0CC Regulation No.3, Part B, Section N.H.1., and can result In the revocation of the perktlt. You must demonstrate compliance with the permit conditions within 180 days after commencement of operation as stated in condition 5. 8. Section -7-114.7(2)(3),C.R.S.requires that all sources required to file an Air Pollution Emission Notice(APEN)must pay an annual fee to cover the costs of inspections arid administration, If a source or activity Is to be discontinued,the owner must notify the Division in writing requesting a caniellation of the permit Upon notification,annual fee bitting wilt terminate. 9. Violation of the temps of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result In administrative,civil or criminal enforcement actions under Sections 25-7-115 (enforcement),-121 (injunctions),-122(dvi penalties),-122.1 (criminal penalties),C.RS. • 123/0243/0659 ver. 2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01 WE0503 Air Pollution Control Division INITIAL APPROVAL Page 6 10. ATTACHMENT A Alternative Operating Scenarios The following Alternative Operating Scenario(AOS)for temporary and permanent engine replacement has been reviewed in accordance with the requirements of Regulation No.3., Part A,Section IV.A, Operational Flexibility-Alternative Operating Scenarios,and Regulation No.3, Part B,Construction Permits,and 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. For purposes of Regulation No. 3, Part B, Section IV.G.4.a., any engine replacement authorized under this AOS shall commence operation upon notation of same in the contemporaneous log as required below. Results of any testing required below shall be nonnafiwd for comparison to the applicable permitted emission limits. 1.1 Temporary Engine Replacement The following AOS is incorporated into a pemmittee's operating or construction permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair which requires the • use of a temporary replacement engine(defined as in the same service for 90 days or less in any 12 month period). The compliance demonstrations made as part of this AOS are in addition to any compliance demonstrations required by the permit. 4.1.1. The permittee may temporarily replace art 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. The permittee shall measure nitrogen oxide(NO,)and carbon monoxide(CO)emissions in the exhaust from the temporary replacement engine using a portable flue gas analyzer within seven (7)calendar days of commencing operation of the temporary replacement engine. Calibration of the analyzer shall be conducted according to manufacturer=s instructions. In the absence of evidence to the contrary,results of the portable flue gas analyzer test shall be evidence of enforceable compliance or noncompliance of the temporary replacement engine with the emission limitations of the original engine. An exceedance of either the NO,or CO emission limitation during the initial portable flue gas analyzer test shall require a subsequent portable flue gas analyzer test indicating compliance with both the NO, and CO emission limitations within 14 calendar days of commencing operation of the replacement engine. Calibration gases shall be used to calibrate the portable analyzer for all tests conducted subsequent to the initial test. If portable flue gas analyzer results indicate compliance with both the NO,and CO emission limitations within the 14-day period,the temporary replacement engine will be considered to • be in compliance for purposes of this AOS from the time that the replacement engine commenced operation until the replacement engine is taken off line. 123/0243/0659 ver.2/00 DUKE ENERGY FIELD SERVICES,LP Colorado Department of Public Health and Environment • Permit No.01WE0503 Air Pollution Control Division INITIAL APPROVAL Page 7 If portable flue gas analyzer results fail to indicate the compliance with either the NO,or CO emission limitations within the 14-day period, the source will notify the Division in writing within 10 calendar days of the end of the 14-day period. In the absence of evidence to the contrary,the temporary replacement engine will be considered to be out of compliance from the time that the temporary replacement engine commenced operation until the engine Is taken off line. Results of all testing that indicates noncompliance shall be submitted to the Division within 10 calendar days of the end of the 14 day period. 4.12 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. Potential emissions from the temporary replacement engine must be less than or equal to the potential emissions 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. 4.1.3 Temporary replacement engines, whether of the same manufacturer, model, and horsepower,or of a different manufacturer,model,or horsepower,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. 4.1.4 The permittee shall maintain a log on site to contemporaneously record the start and stop date of any temporary engine replacement,the manufacturer,model number,horsepower, and serial number of the engine(s) that are temporarily replaced during the term of this • permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. 42 Permanent Engine Replacement The following AOS is incorporated into a permlttee's operating or construction permit In order to deal with a compressor engine breakdown or periodic routine maintenance and repair which requires the use of a permanent replacement engine(defined as In the same service for more than 90 days in any 12 month period). The compliance demonstrations made as part of this AOS are in addition to any compliance demonstrations required by the permit. 4.2.1 The permittee may permanently replace the existing compressor engine for the emission points specified in Table 1 with the manufacturer,model, and horsepower engines listed in Table 1 without modifying this permit. The periodic monitoring specified for the replacement engine shall be required. Within 180 days of permit issuance or within 180 days of the startup of a new source, whichever is applicable, and prior to replacing the existing compressor engine for the emission points specified in Table 1, the existing engine (if it has a design rate of 150 horsepower or greater)must have demonstrated compliance with the permitted NOX and CO emission limits using EPA Reference Test Methods(Identified as Reference Method 7E and Reference Method 10,or Reference Method 19(40 C.F.R.Part 60 Appendix A)or other test methods or procedures acceptable to the Division. The Division shall be notified at least 30 calendar days prior to the EPA Reference Test date, so that it may choose whether to observe the testing. The permittee shell measure nitrogen oxide(NO,)and carbon monoxide(CO)emissions in • the exhaust from the permanent replacement engine using a portable flue gas analyzer within seven (7)calendar days of commencing operation of the permanent replacement engine. Calibration of the analyzer shall be conducted according to manufacturer=s instructions. 123/0243/0659 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No. 01WE0503 Air Pollution Control Division INITIAL APPROVAL Page 8 In the absence of evidence to the contrary,results of the portable flue gas analyzer test shall be evidence of enforceable compliance or noncompliance of the permanent replacement , engine with the emission limitations of the original engine. An exceedance of either the NO,or CO emission limitation during the initial portable flue gas analyzer test shall require a subsequent portable analyzer test indicating compliance with both the NO,and CO emission limitations within 14 calendar days of commencing operation of the replacement engine. Calibration gases shall be used to calibrate the portable analyzer for all tests conducted subsequent to the initial test. If portable flue gas analyzer results Indicate compliance with both the NO,and CO emission limitations within the 14-day period,the permanent replacement engine will be considered to be in compliance for purposes of this AOS. If portable flue gas analyzer results fail to indicate the compliance of the permanent replacement engine with either the NO,or CO emission limitations within the 14-day period, the source will notify the Division In writing within 10 calendar da9S of the end of the 14-ay period. Results of all testing that indicates noncompliance shall be submitted to the Division within 10 calendar days of the end of the 14 day period. The source will be required to conduct EPA Reference Test Methods(identified as Reference Method 7E and Reference Method 10, or Reference Method 19 (40 C.F.R Part 60 Appendix A), hereinafter AEPA Reference Test Methodsit)or other test methods or procedures acceptable to the Division within 45 calendar days of the end of the 14 day period allowed for the portable flue gas • analyzer testing. The Division shaft be notified at least 30 calendar days prior to the EPA Reference Test date,so that it may choose whether to observe the testing. If the EPA Reference Tests indicate compliance with both the NO, and CO emission limitations,the permanent replacement engine will be considered to be in compliance for the purposes of this AOS. If the EPA Reference Tests fail to demonstrate compliance with either the NO, or CO emission limitations and in the absence of evidence to the contrary, the permanent replacement engine will be considered to be out of compliance for the purposes of this AOS from the date the replacement engine commenced operation until jhe engine is taken off line. Results of all EPA Reference testing that indicate noncompliance shall be submitted to the Division within 14 calendar days after receipt of the test results. 4.2.2 Permanent 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. 4.2.3 The permittee shall maintain a log on-site to contemporaneously record the date of any permanent engine replacement, the manufacturer, model number,horsepower,and serial number of the engine(s)that are permanently replaced during the term of this permit,and the manufacturer,model number, horsepower,and serial number of the replacement engine. 4.2.4 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 appropriate APEN fling fee and a cover letter • explaining that the permittee is exercising an alternative operating scenario and is installing a permanent replacement engine shall accompany the APEN. 123/0243/0659 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01 WE0503 Air Pollution Control Division INITIAL APPROVAL Page 9 4.2.5 This procedure cannot be used for permanent engine replacement in the following situations: a. Replacement of a grand fathered or permit exempt engine or an engine that is not subject to emission limits. 4.2.6 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. 4.2.7 Results of alt tests conducted pursuant to this AOS shall be kept on site for five(5)years and made available to the Division upon request. 4.2.8 For comparison with an annual or short term emissions limit, the results of any testing required by this AOS shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies)in orderlo monitor compliance. If a source is not limited in its hours of operation, the test results shall be multiplied by the maximum number of hours In the month or year(8760),whichever applies. 4.3 Additional Sources Current State Air Quality Regulations do not allow for advanced New Source Review in the absence of discrete and verifiable information concerning future installations. Therefore,any additional operational changes requiring new equipment at this facility not addressed • by these Alternative Operating Scenarios will need to undergo appropriate Regulation No.3 review procedures. • 123/0243/0659 ver_2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0503 Air Pollution Control Division INITIAL APPROVAL Page 10 Table 1 Internal Combustion Engine Information for the AOS Emission Replacement Engine Periodic Monitoring' Stack Test? Point 001 (Exact replacement) See Footnote 1 -, No • ' For Title V operating permit sources utilizing this AOS,periodic monitoring shall be determined from the Division's Title V periodic monitoring grid. For Construction permit sources utilizing this AOS, periodic monitoring shall be as follows: Synthetic Minor source:For permanent engine replacement,once the original engine is replaced and the monitoring set forth in the body of the AOS is completed,quarterly portable monitoring for both NOX and CO must be instituted. Compliance for both the NOX and the CO limits must be demonstrated for four(4) consecutive quarters. If compliance is demonstrated for four(4)consecutive quarters,the required frequency of portable monitoring analysis shall become semi-annual. Frequency will revert back to quarterly if portable analyzer results indicate exceedance of the limitations for either pollutant. The required frequency of this monitoring will again go to semi-annual if portable analyzer results indicate compliance for four(4)consecutive quarters. Results of all portable analyzer analyses conducted shall be kept on site and made available to the Division upon request. • 123/0243/0659 ver.2/00 • STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT e •, AIR POLLUTION CONTROL DIVISION k • 4.J , TELEPHONE: (303)692-3150 +« ,• w •re7G Y CONSTRUCTION PERMIT PERMIT NO: 01 WE0504 • INITIAL APPROVAL DATE ISSUED: SEPTEMBER 25, 2001 ISSUED TO: DUKE ENERGY FIELD SERVICES, LP_ THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural Gas Facility known as the Marla Compressor Station,located In the SE%of Sec 28-4N-64W, Weld County,Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: • One (1) Waukesha L 7044 GSI, S/N unknown, Rated at 1680 HP, natural gas fired, internal combustion reciprocating engine equipped with a NSCR,AFR. This emission unit powers a natural gas compressor,stack number 60,P-110 THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S.(25-7-101 et seq),TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: 1. 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 minutesdn any sixty consecutive minutes. Opacity shall be measured by EPA Method 9. (Reference:Regulation 1, Section 4.) 2. The permit number shall be marked on the subject equipment for ease of identification.(Reference: Reg.3,Part B, IV.E.)(State only enforceable) 3. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). Compliance with the annual knits shall be determined on a rolling(12)month total.By the end of each month a new twelve-month total is calculated based on the previous twelve months'data.The permit holder shall calculate monthly emissions and keep a compliance record on site for Division review: (Reference: Regulation 3, Part B, IIL.A.4). Nitrogen Oxides: 32.4 tons per year and 5,504.0 pounds per month Volatile Organic Compounds: 16.2 tons per year and 2,752.0 pounds per month Carbon Monoxide: 32.4 tons per year and 5,504.2 pounds per month • Note: Based on a fuel heating value of 1040 Btu/scf 123/0243/060 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No. 01 WE0504 Air Pollution Control Division INITIAL APPROVAL Page 2 During the first twelve (12) months of operation, compliance with both the monthly and yearly emission limitations shall be required.After the first twelve(12)months of operation,compliance with only the yearly limitation shall be required. 4. This source shall be limited to a maximum consumption rate as listed below and all other activities, operational rates and numbers of equipment as stated in the application.Monthly records of the actual consumption rate shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference; Regulation 3,Part B,III.A.4) Consumption of natural gas as fuel shall not exceed 9.21 million scf per month and 110.5 million scf per year. During the first twelve (12) months of operation, compliance with both the monthly and yearly consumption limitations shall be required.After the first twelve(12)months of operation,compliance with only the yearly limitation shall be required.Compliance with the yearly consumption limits shall be determined on a rolling twelve(12)month total. 5. A source compliance test shall be conducted to measure the emission rate(s)for the pollutants listed below, 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. The protocol shall include manufacturers analysis of emissions at engine maximum and minimum loads,at site specific conditions. Engine operating parameters will be Included in the analysis with emissions reported In parts per million dry volume and grams per • actual horsepower-hour(g/BHP-Hr.) or pounds per million BTU (Ib/MMBTU). No test shall be • conducted without prior approval from the Division.My stack 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. (Reference:Regulation 3, Part B.IV.H.3) Oxides of Nitrogen,Carbon Monoxide and Oxygen, using EPA approved methods. 6. Prior to the stack test being performed, the applicant shall submit to the Division the catalyst manufacturer,model number,serial number and specifications. 7. Prevention of Significant Deterioration(PSD)requirements shall apply to tVVis source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. My relaxation that increases the potential to emit above the applicable PSD threshold will require a full PSD review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit Is granted. 8. Operating Permit(OP)requirements shall apply to this source. An application to modify the existing Operating Permit for this facility shall be submitted within one year of the start up date of this emission unit. (Regulation 3, Part C). 9. A revised Air Pollutant Emission Notice(ADEN)shall be filed:(Reference: Reg.3, Part A,II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year,a change in actual emissions of five(5) • tons per year or more,above the level reported on the last APEN;or 123/0243/060 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0504 Air Pollution Control Division INITIAL APPROVAL Page 3 For any non-criteria reportable pollutant: • If the emissions Increase by 50%or five(5)tons per year,whichever is less,above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process,or activity, or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. 10. The applicant shall track emissions from all insignificant activities on a yearly basis.This information shall be made available to the Division for inspection upon request.For thepurposes of this condition, insignificant activities shall be defined as any activity or equipment which emits any amount but does not require an Air Pollutant Emission Notice(APEN). 11. Within one hundred and eighty days(180)after commencement of operation,compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee's responsibility to self certify compliance with the conditions.Failure to demonstrate compliance within 180 days may result in revocation of the permit.(Information on how to certify compliance was maied with the permit or can be obtained from the Division at 303-692-3209.) • 12. Construction of this source must commence within 18 months of initial approval permit issuance date or within 18 months of date on which such construction or activity was scheduled to commence as stated in the application. If commencement does not occur within the stated time the permit will expire on MARCH 25, 2003 (See General Condition No.6.,Item 1.) (Reference:Regulation 3,Part B,IV.G.4.) 13. Before startup,a compliance plan,containing an operational and maintenance plan,outlining how the applicant will maintain compliance with the requirements of this permit. shall be submitted to the Division for approval. The compliance plan shall commence at startup. At the end of six(6)months of operation,the compliance plan recordkeeping results,shall be submitted to the Division. Annual compliance records shall be maintained by the applicant be made available to the Division for inspection upon request. 14. The serial number of the subject equipment shall be provided to the Division prior to Final Approval. (Reference: Reg. 3, Part B, IV.E.) 15. The engine covered under this permit may be replaced in accordance with the provisions of the Altemative Operating Scenario listed in Attachment A. (Regulation 3,A, IV,A) 16. No atmospheric condensate tanks will be operated at this facility B : ./1 By: r�v Thomas P.Mark James S.Geier P.E. Permit Engineer Unit Leader 12310243/060 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0504 Air Pollution Control Division INITIAL APPROVAL Page 4 Notes to Permit Holder: 1) The fuel consumption limits and emission limits contained in this permit are based on the fuel consumption rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedence of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice(APEN)and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Upset Conditions and Breakdowns.The permittee shall notify the Division of any upset condition which causes a violation of any emission limit or limits stated in this permit as soon as possible,but no later than two(2)hours after the start of the next working day, followed by written notice to the Division explaining the cause of the occurrence end that proper action has been or Is being taken to correct the conditions causing said violation and to prevent such excess emission in the future. - 3) The following emissions of non-criteria reportable air pollutants are estimated based upon the material consumptions as indicated in Condition No.3. This information is listed to inform the operator of the Division's analysis of the specific compounds. This information is listed on the Division's emission inventory system. C.A.S.# SUBSTANCE EMISSIONS ILB/YR1 50.00-0 Formaldehyde 1,524.2 • 7143-2 Benzene 585.8 75 07-0 Acetaldehyde 104.6 4) The emission levels contained in this permit are based on the following emission factors: Nitrogen Oxides* 2.0 grams per horsepower-hour Volatile Organic Compounds 1.0 grams per horsepower-hour Carbon Monoxide: 2.0 grams per horsepower-hour 5) Operating Permit(OP)requirements shall apply to this source and shall require submittal of and Issuance of an operating permit,under Regulation 3,Part C. 6) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN)associated with this permit is valid for a term of five years. The five year term for this APEN expires on May 15,2006. A revised APEN shall be submitted no later than 30 days before the five year term expires. 7) This emission unit is classified as a: Synthetic minor source At a: Synthetic minor facility for MACT HH At a: Major Title V facility At a : Synthetic Minor Facility for PSD • 123/0243/060 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0504 Air Pollution Control Division INITIAL APPROVAL Page 5 GENERAL TERMS AND CONDITIONS: (IMPORTANT! READ ITEMS 5,6,7 AND 8) 1 . This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity,or construction,installation and operation of the source.In accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 2. Unless specifically stated otherwise,the general and specific conditions contained in this permit have been detenmtned by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7Xa),CRS. 3. Each and every condition of this permit Is a material pan hereof and is not severable. My challenge to or appeal of,a condition hereof shall constitute a rejection of the entire permit and upon such occurrence,this permit shall be deemed denied oh Inas. This permit may be revoked at any time prior to final approval by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Al Quality Control Commission(AOCC),including failure to meet any express term or condition of the pennit. N the Division denies a permit,conditions imposed upon a permit are contested by the applicant,or the Division revokes a permit,the applicant or owner or operator of a source may request a hearing before the AOCC for review of the Division's action. 4. This permit and any required attachments must be retained and made available for irupection upon request at the location set forth herein. With respect to a portable source which is moved to a new location,a copy of the Relocation Notice(required by law to be submitted to the APCD whenever a portable source is relocated)shoSd be attached to this permit. The permit may be reissued to a new owner by the APCO as provided in AOCC Regulation No.3, Part 8, Section III.B.upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 5. Issuance(initial approval)of an emission permit does not provide'finer authority for this activity or operation of this source. Final approval of the permit must be secured from the APCD In writing in accordance with the provisions of 25-7- 114.5(12x8)C.R.S.and AOCC Regulation No.3,Part B, Section IV.H. Final approval 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. If the APCD so determines,it will provide written documentation of such final approval,which does constitute 'finar authority to operate.Compliance with the permit conditions must be demonstrated within 180 days after commencement of operation. 6. THIS PERMIT AUTOMATICALLY EXPIRES F you(1)do not commence construction or operation within 18 months after either the date of issuance of this permit or the date on which such construction or activity was scheduled to commence as set forth in the permit,whichever Is later,(2)discontinue construction bra period of 18 months or more;or (3)do not complete construction within a reasonable timed the estimated completion date. Extensions of the expiration date maybe granted by the APCD upon a showing of good cause by the pentittee prior to the expiration date. 7. YOU MUST notify the APCD at least thirty days(fifteen days for portable sources)priorto commencement of the permitted operation or activity. Faikrre to do so is a violation of Section 25.7-114.5(12xa), C.R.S. and AQCC Regulation No.3, Part 8, Section IV.H.1., and can result in the revocation of the penult. You must demonstrate compliance with the permit conditions within 180 days after commencement of operation as stated In condition 6. 8. Section 25-7-114.7(2Xa).CRS.requires that all sources required to file an Air Pollution Emission Notice(APEN)must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued,the owner must notify the Division In writing requesting a cancellation of the permit. Upon notification,annual fee billing will terminate, 9. Violation of the terms or a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result In administrative,civil or criminal enforcement actions under Sections 25-7-115 (enforcement).-121 (injunctions),-122(civil penalties),-122.1 (criminal penalties),C.R.S. • 123/0243/060 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No. 01WE0504 Air Pollution Control Division INITIAL APPROVAL Page 6 ATTACHMENT A Alternative Operating Scenarios The following Alternative Operating Scenario(AOS)for temporary and permanent engine replacement has been reviewed in accordance with the requirements of Regulation No.3., Part A,Section IV.A, Operational Flexibility-Alternative Operating Scenarios,and Regulation No. 3, Part 8, Construction Permits,and 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 pernittee shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. For purposes of Regulation No. 3, Part B, Section IV.G.4.a., any engine replacement authorized under this AOS shall commence operation upon notation of same in thecontemporaneous log as required below. Results of any testing required below shall be normalizpd for comparison to the applicable permitted emission limits. 1.1 Temporary Engine Replacement The following AOS is incorporated into a permittee's operating or construction permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair which requires the use of a temporary replacement engine(defined as in the same service for 90 days or less in any 12 • month period). The compliance demonstrations made as part of this AOS are in addition to any compliance demonstrations required by the permit. 4.1.1. The pemrittee 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 sane manufacturer,model, and horsepower or a different manufacturer,model,or horsepower as the existing engine without modifying this permit. The permittee shall measure nitrogen oxide(NO,)and carbon monoxide(CO)emissions in the exhaust from the temporary replacement engine using a portable flue gas analyzer within seven (7)calendar days of commencing operation of the temporary replacement engine. Calibration of the analyzer shall be conducted according to manufacturer=s Instructions. In the absence of evidence to the contrary,results of the portable flue gas analyzer test shall be evidence of enforceable compliance or noncompliance of the temporary replacement engine with the emission limitations of the original engine. An exceedance of either the NO,or CO emission limitation during the initial portable flue gas analyzer test shall require a subsequent portable flue gas analyzer test indicating compliance with both the NO, and CO emission limitations within 14 calendar days of commencing operation of the replacement engine. Calibration gases shall be used to calibrate the portable analyzer for all tests conducted subsequent to the initial test. If portable flue gas analyzer results indicate compliance with both the NO,and CO emission limitations within the 14-day period,the temporary replacement engine will be considered to be in compliance for purposes of this AOS from the time that the replacement engine • commenced operation until the replacement engine is taken off line. 123/0243/060 ver. 2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No. 01WE0504 Air Pollution Control Division INITIAL APPROVAL Page 7 If portable flue gas analyzer results fall to indicate the compliance with either the NO,or CO emission limitations within the 14-day period, the source will notify the Division in writing within 10 calendar days of the end of the 14-day period. In the absence of evidence to the contrary,the temporary replacement engine will be considered to be out of compliance from the time that the temporary replacement engine commenced operation until the engine is taken off line. Results of all testing that indicates noncompliance shall be submitted to the Division within 10 calendar days of the end of the 14 day period. 4.1.2 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. Potential emissions from the temporary replacement engine must be less than or equal to the potential emissions 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. 4.1.3 Temporary replacement engines, whether of the same manufacturer, model, and horsepower,or of a different manufacturer,model,or horsepower,are subject to all federally applicable and state-only requirements set forth in this permit (fiduding monitoring and record keeping),and shall be subject to any shield afforded by this permit. 4.1.4 The permittee shall maintain a log on-site to contemporaneously record the start and stop date of any temporary engine replacement,the manufacturer,model number,horsepower, and serial number of the engine(s) that are temporally replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the • replacement engine. 4.2 Permanent Engine Replacement The following AOS is Incorporated into a permittee's operating or construction permit In order to deal with a compressor engine breakdown or periodic routine maintenance and repair which requires the use of a permanent replacement engine(defined as in the same service for more than 90 days in any 12 month period). The compliance demonstrations made as part of this AOS are in addition to any compliance demonstrations required by the pen-nit. 4.2.1 The permittee may permanently replace the existing compressor engine for the emission points specified in Table 1 with the manufacturer, model,and horsepower engines listed in Table 1 without modifying this permit. The periodic monitoring specified for the replacement engine shall be required. Within 180 days of permit issuance or within 180 days of the startup of a new source, whichever is applicable, and prior to replacing the existing compressor engine for the emission points specified in Table 1, the existing engine (if it has a design rate of 150 horsepower or greater)must have demonstrated compliance with the permitted NOX and CO emission limits using EPA Reference Test Methods(identified as Reference Method 7E and Reference Method 10,or Reference Method 19(40 C.F.R.Part 60 Appendix A)or other test methods or procedures acceptable to the Division. The Division shall be notified at least 30 calendar days prior to the EPA Reference Test date, so that it may choose whether to observe the testing. The permittee shall measure nitrogen oxide(NO,)and carbon monoxide(CO)emissions in the exhaust from the permanent replacement engine using a portable flue gas analyzer within • seven (7)calendar days of commencing operation of the permanent replacement engine. Calibration of the analyzer shall be conducted according to manufacturers instructions. 123/0243/060 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0504 Air Pollution Control Division INITIAL APPROVAL Page 8 In the absence of evidence to the contrary,results of the portable flue gas analyzer test shall be evidence of enforceable compliance or noncompliance of the permanent replacement engine with the emission limitations of the original engine. An exceedance of either the NO,or CO emission limitation during the initial portable flue gas analyzer test shall require a subsequent portable analyzer test indicating compliance with both the NO,and CO emission limitations within 14 calendar days of commencing operation of the replacement engine. Calibration gases shall be used to calibrate the portable analyzer for all tests conducted subsequent to the initial test. If portable flue gas analyzer results indicate compliance with both the NO,and CO emission limitations within the 14-day period,the permanent replacement engine will be considered to be in compliance for purposes of this AOS. If portable flue gas analyzer results fail to indicate the compliance of the permanent replacement engine with either the NO,or CO emission limitations within the 14-day period, the source will notify the Division in writing within 10 calendar dais of the end of the 14-day period. Results of all testing that indicates noncompliance shall be submitted to the Division within 10 calendar days of the end of the 14 day period. The source will be required to conduct EPA Reference Test Methods(identified as Reference Method 7E and Reference Method 10, or Reference Method 19 (40 C.F.R. Part 60 Appendix A), hereinafter AEPA Reference Test Methods@)or other test methods or procedures acceptable to the Division within 45 calendar days of the end of the 14 day period allowed for the portable flue gas • analyzer testing. The Division shall be notified at least 30 calendar days prior to the EPA Reference Test date,so that it may choose whether to observe the testing. If the EPA Reference Tests indicate compliance with both the NO, and CO emission limitations,the permanent replacement engine will be considered to be In compliance for the purposes of this AOS. If the EPA Reference Tests fail to demonstrate compliance with either the NO, or CO emission limitations and in the absence of evidence to the contrary, the permanent replacement engine will be considered to be out of compliance for the purposes of this AOS from the date the replacement engine commenced operation until the engine is taken off line. Results of all EPA Reference testing that indicate noncompliance shall be submitted to the Division within 14 calendar days after receipt of the test results. 4.2.2 Permanent 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. 4.2.3 The permittee shall maintain a log on-site to contemporaneously record the date of any permanent engine replacement, the manufacturer, model number,horsepower, and serial number of the engine(s)that are permanently replaced during the term of this permit,and the manufacturer,model number,horsepower, and serial number of the replacement engine. 4.2.4 An Air Pollutant Emissions Notice(APEN)that includes the specific manufacturer,model and serial number end 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 appropriate APEN fling fee and a cover letter • explaining that the permittee is exercising an alternative operating scenario and is installing a permanent replacement engine shall accompany the APEN. 12310243/060 ver, 2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment Permit No.01WE0504 Air Pollution Control Division • INITIAL APPROVAL Page 9 4.2.5 This procedure cannot be used for permanent engine replacement in the following situations: a. Replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. 4.2.6 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. 4.2.7 Results of all tests conducted pursuant to this AOS shall be kept on site for five(5)years and made available to the Division upon request. 4.2,8 For comparison with an annual or short term emissions limit, the results of any testing required by this AOS 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 shall be multiplied by the maximum number of hours in the month or year(8760),whichever applies. 4.3 Additional Sources Current State Air Quality Regulations do not allow for advanced New Source Review in the absence of discrete and verifiable Information concerning future installations. Therefore,any additional operational changes requiring new equipment at this facility not addressed by these Alternative Operating Scenarios will need to undergo appropriate Regulation No.3 review • procedures. a. • 123/0243/060 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment Permit No. 01WE0504 Air Pollution Control Division • INITIAL APPROVAL Page 10 Table 1 Internal Combustion Engine Information for the AOS Emission Replacement Engine Periodic Monitoring' Stack Test? Point 001 (Exact replacement) See Footnote 1 No • ' For Title V operating permit sources utilizing this AOS, periodic monitoring shall be determined from the Division's Title V periodic monitoring grid. For Construction permit sources utilizing this AOS, periodic monitoring shall be as follows: Synthetic Minor source: For permanent engine replacement,once the original enghte is replaced and the monitoring set forth In the body of the AOS is completed,quarterly portable monitoring for both NOX and CO must be instituted. Compliance for both the NOX and the CO limits must be demonstrated for four(4) consecutive quarters. If compliance Is demonstrated for four(4)consecutive quarters,the required frequency of portable monitoring analysis shall become semi-annual. Frequency will revert back to quarterly if portable analyzer results Indicate exceedance of the limitations for either pollutant. The required frequency of this monitoring will again go to semi-annual if portable analyzer results indicate compliance for four(4)consecutive quarters. Results of all portable analyzer analyses conducted shall be kept on site and made available to the Division upon request. • 123/02431060 ver.2/00 • STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION „ 'Tit; TELEPHONE: (303)692-3150 •�J* CONSTRUCTION PERMIT PERMIT NO: 01WE0505 INITIAL APPROVAL DATE ISSUED: SEPTEMBER 25, 2001 ISSUED TO: DUKE ENERGY FIELD SERVICES, LP_ THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural Gas Facility known as the Marla Compressor Station,located in the SE%of Sec 28-4N-64W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: • One (1) Waukesha L 7044 GSI, SRI unknown, Rated at 1680 HP, natural gas fired, Internal combustion reciprocating engine equipped with a NSCR,AFR. This emission unit powers a natural . gas compressor,stack number 61,P-111 THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S.(25-7-101 et sea),TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: 1. 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.jn any sixty consecutive minutes. Opacity shall be measured by EPA Method 9. (Reference:Regulation 1,Section 4.) 2. The permit number shall be marked on the subject equipment for ease of identification.(Reference: Reg. 3,Part B, IV.E.)(State only enforceable) 3. Emissions of air pollutants shall not exceed the following limitations(as calculated in the Division's preliminary analysts). Compliance with the annual limits shall be determined on a rolling(12)month total.By the end of each month a new twelve-month total is calculated based on the previous twelve months'data.The permit holder shall calculate monthly emissions and keep a compliance record on site for Division review:(Reference: Regulation 3, Part B, III.A.4). Nitrogen Oxides: 32.4 tons per year and 5,504.0 pounds per month Volatile Organic Compounds; 16.2 tons per year and 2,752.0 pounds per month Carbon Monoxide: 32.4 tons per year and 5,504.0 pounds per month • Note: Based on a fuel heating value of 1040 Btu/scf 123/0243/061 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit Na.01 WE0505 Air Pollution Control Division INITIAL APPROVAL Page 2 During the first twelve (12) months of operation, compliance with both the monthly and yearly emission limitations shall be required.After the first twelve(12)months of operation,compliance with only the yearly limitation shall be required. 4. This source shall be limited to a maximum consumption rate as listed below and all other activities, operational rates and numbers of equipment as stated in the application.Monthly records of the actual consumption rate shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3. Part B,III.A.4) Consumption of natural gas as fuel shall not exceed 9.21 million scf per month and 110.5 million scf per year. During the first twelve (12) months of operation, compliance with both the monthly and yearly consumption limitations shall be required.After the first twelve(12)months of operation,compliance with only the yearly limitation shell be required.Compliance with the yearly consumption limits shall be determined on a rolling twelve(12)month total. -- 5. A source compliance test shall be conducted to measure the emission rate(s)for the pollutants listed below. 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. The protocol shag include manufacturers analysis of emissions at engine maximum and minimum loads,at site specific conditions. Engine operating parameters will be induded in the analysis with emissions reported in parts per million dry volume and grams per • actual horsepower-hour(gBHP-Hr.) or pounds per million BTU (Ib/MMBTU). No test shall be conducted without prior approval from the Division.Any stack 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.(Reference: Regulation 3,Part B.IV.H.3) Oxides of Nitrogen,Carbon Monoxide and Oxygen,using EPA approved methods. 8. Prior to the stack test being performed, the applicant shall submit to the Division the catalyst manufacturer,model number, serial number and specifications. 7. Prevention of Significant Deterioration(PSD)requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. My relaxation that Increases the potential to emit above the applicable PSD threshold will require a full PSD review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit Is granted. 8. Operating Permit(OP)requirements shall apply to this source. An application to modify the existing Operating Permit for this facility shall be submitted within one year of the start up date of this emission unit. (Regulation 3,Part C). 9. A revised Air Pollutant Emission Notice(APEN)shall be filed:(Reference: Reg.3,Pert A,II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year,a change in actual emissions of five(5) • tons per year or more,above the level reported on the last APEN;or 123/0243/0661 ver.2/00 DUKE ENERGY FIELD SERVICES. LP Colorado Department of Public Health and Environment • Permit No.01 WE0505 Air Pollution Control Division INITIAL APPROVAL Page 3 For any non-criteria reportable pollutant If the emissions increase by 50%or five(5)tons per year,whichever is less,above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility,process,or activity;or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment;or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. 10. The applicant shall track emissions from all insignificant activities on a yearly basis.This information shall be made available to the Division for inspection upon request.For thepurposes of this condition, insignificant activities shall be defined as any activity or equipment which emits any amount but does not require an Air Pollutant Emission Notice(APEN). 11. Within one hundred and eighty days (180)after commencement of operation,compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee's responsibility to self certify compliance with the conditions.Failure to demonstrate compliance within 180 days may result in revocation of the permit.(Information on how to certify compliance was mailed with the permit or can be obtained from the Division at 303-6923209.) • 12. Construction of this source must commence within 18 months of initial approval permit issuance date or within 18 months of date on which such construction or activity was scheduled to commence as stated in the application. If commencement does not occur within the stated time the permit will expire on MARCH 25. 2003 (See General Condition No.6., Item 1.) (Reference:Regulation 3,Part B, IV.G.4.) 13. Before startup,a compliance plan,containing an operational and maintenance plan,outlining how the applicant will maintain compliance with the requirements of this permit, shall be submitted to the Division for approval. The compliance plan shall commence at startup. At the end of six(6)months of operation,the compliance plan recordkeeping results,shall be submitted to the Division. Annuat compliance records shall be maintained by the applicant be made available to the Division for inspection upon request. 14. The serial number of the subject equipment shall be provided to the Division prior to Final Approval. (Reference: Reg. 3, Part B, IV.E.) 15. The engine covered under this permit may be replaced in accordance with the provisions of the Alternative Operating Scenario listed in Attachment A.(Regulation 3,A, IV,A) 16. No atmospheric condensate tanks will be operated at this facility By: 41 Thomas P. Mark � James S.Geier P.E. Permit Engineer Unit Leader • 123/0243/0661 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No. 01 WE0505 Air Pollution Control Division INITIAL APPROVAL Page 4 Notes to Permit Holder: 1) The fuel consumption limits and emission limits contained in this permit are based on the fuel consumption rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedence of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice(APEN)and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Upset Conditions and Breakdowns.The permittee shall notify the Division of any upset condition which causes a violation of any emission limit or limits stated in This permit as soon as possible,but no later than two(2)hours after the start of the next working day, followed by written notice to the Division explaining the cause of the occurrence and that proper action has been or is being taken to correct the conditions causing said violation and to prevent such excess emission in the future. 3) The following emissions of non-criteria reportable air pollutants are estimated based upon the material consumptions as indicated in Condition No.3. This information is listed to inform the operator of the Division's analysis of the specific compounds. This information is listed on the Division's emission inventory system. C.A.S.# SUBSTANCE EMISSIONS[LB/YR) 50-00-0 Formaldehyde 1,524.2 • 7143-2 Benzene 585.8 75-07 0 Acetaldehyde 104.6 4) The emission levels contained in this permit are based on the following emission factors: Nitrogen Oxides- 2.0 grams per horsepower-hour Volatile Organic Compounds: 1.0 grams per horsepower-hour Carbon Monoxide: 2.0 grams per horsepower-hour 5) Operating Permit(OP)requirements shall apply to this source and shall require submittal of and issuance of an operating permit,under Regulation 3, Part C. 6) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN)associated with this permit is valid for a term of five years. The five year term for this APEN expires on May 15, 2006. A revised APEN shall be submitted no later than 30 days before the five year term expires. 7) This emission unit is classified as a: Synthetic minor source At a: Synthetic minor facility for MACT HH At a: Major Title V facility At a : Synthetic minor facility for PSD • 123/0243/0661 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment Permit No.01 WE0505 Air Pollution Control Division • INITIAL APPROVAL Page 5 GENERAL TERMS AND CONDITIONS: (IMPORTANT! READ ITEMS 5,6,7 AND 8) 1. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity,or construction,instalfatlon and operation of the source,In accordance with this Information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 2. Unless specifically stated otherwise,the general and specific conditions contained In this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7Xa),C.R.S. 3. Each and every condition of this permit is a material part hereof and is not severable. My challenge to or appeal of,a condition hereof shall constitute a rejection of the entire permit and upon such occurrence,this permit shall be deemed denied orb inftio. This permit may be revoked at any time prior to final approval by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission(AOCC), Including failure to meet any express term or condition of the permit If the Division denies a permit,conditions Imposed upon a permit we contested by the applicant,or the Division revokes a permit,the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 4. This permit and any required attachments must be retained and made available for ki"speoion upon request at the location set forth herein. With respect to a portable source witch Is moved to a new bastion,a copy of the Relocation Notice(required by law to be submitted to the APCD whenever a portable source Is relocated)should be attached to this permit. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No.3,Part B, Section II1.B.upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 5. Issuance(Initial approval)of an emission permit does not provide liner authority for this activity or operation of this source. Final approval of the permit must be secured from the APCD inwr fig In accordancevAtitthe provisions of 25-7- 114.5(12)(a) C.RS. and AQCC Regulation No.3,Part B,Section N.H. Final approval cannot be granted until the • operation or activity commences and has been verified by the APCD as conforming hi all respects wihthe conditions of the permit If the APCD so determines,it wit provide written documentation of such final approval,which does constitute 'finer authority to operate.Compliance with the permit conditions must be demonstrated within 180 days after commencement of operation. 6. THIS PERMIT AUTOMATICALLY EXPIRES IF you(1)do not Commence construction or operation within 18 months after either the date of issuance of this pert or the date on with such construction or activity was scheduled to commence as set forth in the permit,whichever is later,(2)discontinue construction fora period of 18 months or more;or (3)do rot complete construction within a reasonable time tithe estimated completion date. Extensions tithe expiration date may be granted by the APCD upon a showing of good cause by the permitted prior to the expiration date. 7. YOU MUST nobly the APCD at least thirty days(fifteen days for portable sources)prior to commencement of the permitted operation or activity. Failure to do so is a violation of Section 25-7-114.5(12Xa),C.RS. and AQCC Regulation No.3, Part B, Section IV.H.1., and can result In the revocation of the permit You must demonstrate compliance rah the permit conditions within 180 days after commencement of operation as stated In condition 5. 8. Section 25.7-114.7(2Xa),C.R.S.requires that all sources required to file an Air Pollution Emission Notice(APEN)must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued,the owner must notify the Division in writing requesting a cancellation of the permit. Upon ratification,annual fee billing will terminate. 9. Violation of the teens of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative,OW or criminal enforcement actions under Sections 25-7-115 (enforcement),-121 (injunctions),-122(civil penalties),.122.1 (criminal penalties).C.RS. 123/0243/0661 ver.2/00 DUKE ENERGY FIELD SERVICES,LP Colorado Department of Public Health and Environment Permit No.01WE0505 Air Pollution Control Division • INITIAL APPROVAL Page 6 ATTACHMENT A Alternative Operating Scenarios The following Alternative Operating Scenario(AOS)for tengxnm_y and permanent engine replacement has been reviewed in accordance with the requirements of Regulation No.3., Part A, Section IVA, Operational Flexibility-Alternative Operating Scenarios,and Regulation No. 3, Part B,Construction Permits,and has been found to meet all applicable substantive and procedural requirements. This penult 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. For purposes of Regulation No. 3, Pal B, Section IV.G.4.a., any engine replacement authorized under this AOS shall commence operation upon notation of same in thecontemporaneous log as required below. Results of any testing required below shall be normali4ed for comparison to the applicable permitted emission limits. 1.1 Temporary Engine Replacement The following AOS is incorporated into a permittee's operating or construction permit In order to deal with a compressor engine breakdown or periodic routine maintenance and repair which requires the use of a temporary replacement engine(defined as in the same service for 90 days or less in any 12 • month period). The compliance demonstrations made as part of this AOS are in addition to any compliance demonstrations required by the permit. 4.1.1. 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. The permittee shall measure nitrogen oxide(NO,)and carbon monoxide(CO)emissions in the exhaust from the temporary replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the temporary replacement engine. Calibration of the analyzer shall be conducted according to manufacturer=s instructions. In the absence of evidence to the contrary,results of the portable flue gas analyzer test shall be evidence of enforceable compliance or noncompliance of the temporary replacement engine with the emission limitations of the original engine. Art exceedance of either the NO,or CO emission limitation during the initial portable flue gas analyzer test shall require a subsequent portable flue gas analyzer test indicating compliance with both the NO, and CO emission limitations within 14 calendar days of commencing operation of the replacement engine. Calibration gases shall be used to calibrate the portable analyzer for all tests conducted subsequent to the initial test. If portable flue gas analyzer results indicate compliance with both the NO,and CO emission limitations within the 14-day period,the temporary replacement engine will be considered to be in compliance for purposes of this AOS from the time that the replacement engine • commenced operation untilthe replacement engine Is taken off line. 123/0243/0661 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01 WE0505 Air Pollution Control Division INITIAL APPROVAL Page 7 If portable flue gas analyzer results fail to indicate the compliance with either the NO,or CO emission limitations within the 14-day period, the source will notify the Division in writing within 10 calendar days of the end of the 14-day period. In the absence of evidence to the contrary,the temporary replacement engine will be considered to be out of compliance from the time that the temporary replacement engine commenced operation until the engine is taken off line. Results of all testing that indicates noncompliance shall be submitted to the Division within 10 calendar days of the end of the 14 day period. 4.1.2 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. Potential emissions from the temporary replacement engine must be less than or equal to the potential emissions 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. 4.1.3 Temporary replacement engines, whether of the same manufacturer, model, and horsepower,or of a different manufacture,model,or horsepower,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. 4.1.4 The permittee shall maintain a log on-site to contemporaneously record the start and stop date of any temporary engine replacement,the manufacturer,model number, horsepower, and serial number of the engine(s) that are temporarily replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the • replacement engine. 4.2 Permanent Engine Replacement The following AOS Is Incorporated into a pemiittee's operating or construction permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair which requires the use of a permanent replacement engine(defined as in the same service for more than 90 days in any 12 month period). The compliance demonstrations made as part of this AOS are in addition to any compliance demonstrations required by the permit. 4.2.1 The permittee may permanently replace the existing compressor engine for the emission points specified In Table 1 with the manufacturer, model,and horsepower engines listed in Table 1 without modifying this permit. The periodic monitoring specified for the replacement engine shalt be required. Within 180 days of permit Issuance or within 180 days of the startup of a new source, whichever is applicable, and prior to replacing the existing compressor engine for the emission points specified in Table 1, the existing engine (if it has a design rate of 150 horsepower or greater)must have demonstrated compliance with the permitted NOX and CO emission limits using EPA Reference Test Methods(identified as Reference Method 7E and Reference Method 10,or Reference Method 19(40 C.F.R.Part 60 Appendix A)or other test methods or procedures acceptable to the Division. The Division shall be notified at least 30 calendar days prior to the EPA Reference Test date, so that it may choose whether to observe the testing. The permittee shall measure nitrogen oxide(NO)and carbon monoxide(CO)emissions in the exhaust from the permanent replacement engine using a portable flue gas analyzer within • seven (7)calendar days of commencing operation of the permanent replacement engine. Calibration of the analyzer shall be conducted according to manufacturer=s instructions. 123/0243/0661 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0505 Air Pollution Control Division INITIAL APPROVAL Page 8 In the absence of evidence to the contrary,results of the portable flue gas analyzer test shall be evidence of enforceable compliance or noncompliance of the permanent replacement engine with the emission limitations of the original engine. An exceedance of either the NO,or CO emission limitation during the initial portable flue gas analyzer test shall require a subsequent portable analyzer test indicating compliance with both the NO,and CO emission limitations within 14 calendar days of commencing operation of the replacement engine. Calibration gases shall be used to calibrate the portable analyzer for all tests conducted subsequent to the initial test. If portable flue gas analyzer results indicate compliance with both the NO,and CO emission limitations within the 14-day period,the permanent replacement engine will be considered to be in compliance for purposes of this AOS. If portable flue gas analyzer results fail to indicate the compliance of the permanent replacement engine with either the NO,or CO emission limitations within the 14-day period, the source will notify the Division in writing within 10 calendar daft of the end of the 14-day period. Results of all testing that indicates noncompliance shall be submitted to the Division within 10 calendar days of the end of the 14 day period. The source will be required to conduct EPA Reference Test Methods(identified as Reference Method 7E and Reference Method 10, or Reference Method 19 (40 C.F.R. Part 60 Appendix A), hereinafter AEPA Reference Test MethodsO)or other test methods or procedures acceptable to the Division within 45 calendar days of the end of the 14 day period allowed for the portable flue gas • analyzer testing. The Division shall be notified at least 30 calendar days prior to the EPA Reference Test date,so that It may choose whether to observe the testing. If the EPA Reference Tests indicate compliance with both the NO, and CO emission limitations,the permanent replacement engine will be considered to be in compliance for the purposes of this AOS. If the EPA Reference Tests fail to demonstrate compliance with either the NO, or CO emission limitations and in the absence of evidence to the contrary, the permanent replacement engine will be considered to be out of compliance for the purposes of this AOS from the date the replacement engine commenced operation until Ile engine is taken off line. Results of ell EPA Reference testing That indicate noncompliance shall be submitted to the Division within 14 calendar days after receipt of the test results. 4.2.2 Permanent 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. 4.2.3 The permittee shall maintain a log on-site to contemporaneously record the date of any permanent engine replacement,the manufacturer,model number,horsepower, and serial number of the engine(s)that we permanently replaced during the term of this permit,and the manufacturer,model number,horsepower, and serial number of the replacement engine. 4.2.4 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 appropriate APEN fling fee and a cover letter • explaining that the permittee is exercising an alternative operating scenario and is installing a permanent replacement engine shall accompany the APEN. 123/0243/0661 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment • Permit No.01WE0505 Air Pollution Control Division INITIAL APPROVAL Page 9 4.2.5 This procedure cannot be used for permanent engine replacement in the following situations: a. Replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. 4.2.6 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. 4.2.7 Results of all tests conducted pursuant to this AOS shall be kept on site for five(5)years and made available to the Division upon request. 4.2.8 For comparison with an annual or short term emissions limit, the results of any testing required by this AOS 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 shall be multiplied by the maximum number of hours in the month or year(8760),whichever applies. 4.3 Additional Sources Current State Air Quality Regulations do not allow for advanced New Source Review in the absence of discrete and verifiable information concerning future Installations. Therefore,any additional operational changes requiring new equipment at this facility not addressed . by these Alternative Operating Scenarios will need to undergo appropriate Regulation No.3 review procedures. Y • 123/0243/0661 ver.2/00 DUKE ENERGY FIELD SERVICES, LP Colorado Department of Public Health and Environment Permit No.01WE0505 Air Pollution Control Division • INITIAL APPROVAL Page 10 Table 1 • Internal Combustion Engine Information for the AOS Emission Replacement Engine Periodic Monitoring' Stack Test? Point 001 (Exact replacement) See Footnote 1 _ No • ' For Title V operating permit sources utilizing this AOS, periodic monitoring shall be determined from the Division's Title V periodic monitoring grid. For Construction permit sources utilizing this AOS,periodic monitoring shall be as follows: Synthetic Minor source: For permanent engine replacement,once the original engfhe is replaced and the monitoring set forth in the body of the AOS is completed,quarterly portable monitoring for both NOX and CO must be instituted. Compliance for both the NOX and the CO limits must be demonstrated for four(4) consecutive quarters. If compliance Is demonstrated for four(4)consecutive quarters,the required frequency of portable monitoring analysis shall become semi-annual. Frequency will revert back to quarterly If portable analyzer results indicate exceedance of the limitations for either pollutant. The required frequency of this monitoring will again go to semi-annual if portable analyzer results indicate compliance for tour(4)consecutive quarters. Results of all portable analyzer analyses conducted shall be kept on site and made available to the Division upon requesL • 123/0243/0661 ver. 2/00 STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE:(303)692-3150 4J " CONSTRUCTION PERMIT PERMIT No: 01WE0506 INITIAL APPROVAL FEBRUARY zz, 2006 DATE ISSUED: Modification No.2 ISSUED TO: Duke Energy Field Services, LP THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: One Natural gas dehydration unit associated with a facility known as Marla Compressor Station, located in SE'/.Section 28, T4NS, R64W in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: One(1)P-112, TEG Dehydration System, rated at 45 mmscf per day. This emission unit removes water from pipeline gas. • THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et sect), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: 1. 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, EPA Method 9 shall be used to measure opacity. (Reference: Regulation 1, Section II.A.1.&4.) 2. The permit number shall be marked on the subject equipment for ease of identification. (Reference: (Reference: Regulation No. 3, Part B, III.E.) 3. The manufacturer, model number and serial number of the subject equipment shall be provided to the Division prior to Final Approval. (Reference. Regulation No. 3, Part B, I11.E.) 4. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis): (Reference: Regulation 3, Part B, II.A.4) Volatile Organic Compounds (VOC): 0.29 pounds per month and 3.41 tons per year Each Individual Hazardous Air Pollutant: 0.68 pounds per month and 6.00 tons per year All Hazardous Air Pollutants Combined: 1.70 pounds per month and 20.00 tons per year. (Note: Monthly emissions are based on 31 day month) During the first twelve (12) months of operation, compliance with both the monthly and yearly emission limitations shall be required.After the first twelve(12)months of operation,compliance with only the yearly limitation shall be required. By the end of each month a new twelve month total is • calculated based on the previous twelve months data.Monthly records of the actual emissions shall be maintained by the applicant and made available to the Division for inspection upon request. Compliance with the annual limits shall be determined on a rolling (12)month total. 12310234/062 Page 2 Colorado Department of Public Health and Environment Air Pollution Control Division • Duke Energy Field Services, LP Permit No. 01 WE0506 INITIAL APPROVAL 5. This source shall be limited to a maximum process and consumption rates as listed below and all other activities,operational rates and numbers of equipment as stated in the application. Daily records of the actual production rate shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Natural gas processing shat not exceed 1,395 mmscf per month and 16,425 mmscf per year (Note: Monthly processing rate is based on 31 day month) During the first twelve(12)months of operation,compliance with both the monthly and yearly process rate limitations shall be required.After the first twelve(12)months of operation,compliance with only the yearly limitation shall be required. Compliance with the yearly consumption limits shall be determined on a rolling twelve(12)month total. 6. This source shall be limited to a maximum lean glycol pump rate as listed below and all other activities, operational rates and numbers of equipment as stated in the application. Annual records of the actual pump rate shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation No. 3, Part B, II.A4) The maximum pumping rate of lean glycol shall not exceed 7.5 gallons per minute 7. This source shall be equipped with a condenser and flare control devices capable of reducing uncontrolled emissions of VOC and Hazardous Air Pollutants by at least 99%. Operating parameters of the control equipment shall be identified prior to final approval of this permit. The identified operating parameters will replace the control • efficiency requirement on the final permit.(Reference: Regulation No. 3,Part B, Section 111.8,1. 8. Compliance with the emission limits, shall be demonstrated by running the GRI GlyCalc version 4.0 or higher, model on a monthly basis. 9. Prior to final approval being issued,the applicant shall submit to the Division for approval an operating and maintenance plan for all control equipment and control practices,and a proposed record keeping format that will outline how the applicant will maintain compliance on an ongoing basis with the requirements of conditions no.4,5,6 and 7 listed above. (Reference: Reg. 3, Part B.III.G.4) 10. A source compliance test shall be conducted during the summer quarter to measure the emission rate(s) for the pollutants listed below in order to show compliance with VOC emission limit.The test protocol must be in accordance with the requirements of the Alr Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least 30 days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any stack 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 (Reference: Regulation No. 3, Part B., Section III.G.3) Volatile Organic Compounds(VOC) using EPA approved methods. 11. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 12. A revised Air Pollutant Emission Notice(APEN)shall be filed: (Reference: Reg. 3, Part A,II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: • For sources emitting less than 100 tons per year, a change in actual emissions of five tons per year or more, above the level reported on the last APEN;or 12310234/062 Page 3 Colorado Department of Public Health and Environment Air Pollution Control Division Duke Energy Field Services, LP Permit No. 01 WE0506 INITIAL APPROVAL For any non-criteria reportable pollutant: If the emissions increase by 50% or five(5)tons per year,whichever is less, above the level reported on the last APEN submitted to the Division. a. Whenever there is a change in the owner or operator of any facility, process, or activity;or b. Whenever new control equipment is installed,or whenever a different type of control equipment replaces an existing type of control equipment;or c. Whenever a permit limitation must be modified;or d. No later than 30 days before the existing APEN expires. 13. Prevention of Significant Deterioration(PSD)requirements shall apply to this source at any such time that this source modification becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable PSD threshold will require a full PSD review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit is granted. (Reference: Regulation No. 3, Part B, IV.D.3.b.(iv)) 14. This source is subject to the provisions of Regulation No. 3, Part C,Operating Permits(Title V of the 1990 • Federal Clean Air Act Amendments). The provisions of this construction permit must be incorporated into the operating permit associated with this permit. The application for the modification to the Operating Permit is due within one year of commencing operation of the equipment covered by this permit. (Reference Reg. 3, Part C, II.B.2) 15. Within one hundred and eighty days (180) after commencement of operation, compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee's responsibility to self certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit.(Information on how to certify compliance was mailed with the permit.) 16. This permit shall expire If the owner or operator of the source for which this permit was issued:(i)does not commence construction/modification or operation of this source within 18 months after either the date of issuance of this initial approval permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit;(ii)discontinues construction for a period of eighteen months or more;or(ii)does not complete construction within a reasonable time of the estimated completion date(See General Condition No.6.,Item 1.).Upon a showing of good cause by the permittee, the Division may grant extensions of the permit. (Reference: Regulation No. 3, Part B, Section III.F.4.) 17. All previous versions of this permit are canceled upon issuance of this permit. '—" r' p By: Sunday A. adeyi, P.E. K Hancock III,P.E. Permit Engineer Unit Leader initial Approval: Issued on September 25,2001 • Modification No. 1 Increased VOC emissions from 8.4 to 33.3 tons per year due to adjusting GRI GlyCalc paranUrs. Initial Approval: Reissued on July 11,2002. Modification No.2: Addition of flare as a control device end reduction in process rate from 21,170 mmscf per year. 123/02341062 Page 4 Colorado Department of Public Health and Environment Air Pollution Control Division Duke Energy Field Services, LP Permit No. 01 WE0506 INITIAL APPROVAL Notes to permit holder: 1) The production or raw material processing limits and emission limits contained in this permit are based on the production/processing rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice(APEN)and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Upset Conditions and Breakdowns. The permittee shall notify the Division of any upset condition which causes a violation of any emission limit or limits stated in this permit as soon as possible,but no later than two(2)hours after the start of the next working day,followed by written notice to the Division explaining the cause of the occurrence and that proper action has been or is being taken to correct the conditions causing said violation and to prevent such excess emission in the future. 3) The emission levels contained in this permit are based on the following normalized emission factors (any change in operations may change these factors): Volatile Organic Compound(VOC): 0.4141 pounds per mmscf 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the throughput as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds. This information is listed on the Division's emission inventory system. • C.A.S.X SUBSTANCE[BIN] EMISSIONS [LBJYR] 71-43-2 Benzene (A) 742 1330-20-7 Xylenes (C) 601 100-441-4 Ethyl benzene(C) 37 108-88-3 Toluene(C) 1,244 5) This source is classified as a: Synthetic Minor source for Operating Permit Synthetic Minor source for PSD At a: Major Source facility for Operating Permit Synthetic Minor facility for PSD • 123/02341062 Page 5 Colorado Department of Public Health and Environment Air Pollution Control Division Duke Energy Field Services, LP Permit No. 01 WE0508 INITIAL APPROVAL GENERAL TERMS AND CONDITIONS: (IMPORTANT! READ ITEMS 5.6,7 AND 8) 1. This permit is issued In reliance upon the accuracy and completeness of information supplied by the applicant and Is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicants agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 2 Unless specifically stated otherwise. the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 3. Each and every condition of this permit Is a material part hereof and is not severable. Any challenge to or appeal of,a condition hereof shall constitute a rejection of the entire permit and upon such occurrence,this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to final approval by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit,conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AOCC for review of the Division's action. 4 This permit and any required attachments must be retained and made available for inspection upon request at the location set forth herein. Wtth respect to a portable source that is moved to a new location,a copy of the Relocation Notice (required by law to be submitted to the APCD whenever a portable source is relocated) should be attached to this permit. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No.3,Part B,Section 11.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required tee. • 5. Issuance(initial approval)of an emission permit does not provide"final"authority for this activity or operation of this source. Final approval 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 approval 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. If the APCD so determines,it will provide written documentation or such final approval,which does constitute"final"authority to operate.Compliance with the permit conditions must be demonstrated within 180 days after commencement of operation. 6. THIS PERMIT AUTOMATICALLY EXPIRES IF you(1)do not commence construction or operation within 18 months after either the date of issuance of this permit or the date on which such construction or activity was scheduled to commence as set forth in the permit,whichever is later;(2)discontinue construction for a period of 18 months or more;or(3)do not complete construction within a reasonable time of the estimated completion date. Extensions of the expiration date may be granted by the APCD upon a showing of good cause by the permittee prior to the expiration date. 7. YOU MUST notify the APCD at least thirty days (fifteen days for portable sources) prior to commencement of the permitted operation or activity. Failure to do so is a violation of Section 25-7- 114.5(12)(a),C.R.S.and AQCC Regulation No.3,Part B,Section III.G.1.,and can result in the revocation of the permit. You must demonstrate compliance with the permit conditions within 180 days after commencement of operation as stated in condition 5. 8. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN)must pay an annual fee to cover the costs of Inspections and administration. If a source or activity is to be discontinued,the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification,annual fee billing will terminate. 9. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and control Act or the regulations of the AQCC may result in administrative,civil or criminal enforcement actions under Sections 25-7.115(enforcement),-121 (injunctions),-122 (civil penalties),-122.1 (criminal penalties), C.R.S. • 12310234/062 Duke Energy, Duke Energy Field Services t O-Ror,5493 'Field Services Denver,Colorado 80217 A New Kind d Energy"' 370 17th Sired,Suite 900 • Denver,Colorado 80202 301/595-3,i31 April 30, 2002 Construction Permitting Unit Colorado Dept. of Public Health and Environment Air Pollution Control Division Stationary Sources Section,APCD-SSP-B 1 4300 Cherry Creek Drive South Denver,CO 80246-1530 Re: Construction Permit 01 WE0506 Marla Compressor Station Weld County,CO Facility ID: 1230243 Dear Permit Engineer: Duke Energy Field Services, LP (DEFS) currently has a permit for a triethylene glycol dehydration unit located at the Marla Compressor Station in Weld County, Colorado. DEFS would like to modify the permit to increase the allowable emissions of VOCs. • The TEG unit is currently permitted at 8.4 tpy of VOC, 24.0 tpy of total HAPs and 9.0 tpy of individual HAPs. DEFS is requesting to raise the limit to 33.3 tpy VOC to allow for greater operational flexibility in the parameters for the unit. In addition, please lower the HAP emissions to 20 tpy total HAPs and 8 tpy year individual HAPs to coincide with Condition 10 of the permit. The GRI GLYCalc Version 4.0 run and extended analysis can be found in Appendix A and a completed Application Form and APEN are provided in Appendix B. The APEN filing fee and any permit processing fees can be invoiced to the company at your convenience. Please contact me at 720-944-9386 with any questions or concerns with the attached information. Sincerely, Duke Energy Field Services,LP a ithl e Ashley Campsie Environmental Engineer enclosures • APPENDIX A Supporting Emissions Calculations • Page: 1 GRI-GLYCalc VERSION 4 . 0 - SUMMARY OF INPUT VALUES Case Name: Marla File Name: D: \Colorado\Applications 2002\Marla\worstcase .ddf Date: April 30, 2002 DESCRIPTION: Description: Parameters Modifications Annual Hours of Operation: 8760 . 0 hours/yr WET GAS : Temperature: 80 .00 deg. F Pressure : 900.00 psig Wet Gas Water Content : Saturated Component Conc. (vol %) Carbon Dioxide 2 . 2770 Nitrogen 0.4210 Methane 75 . 0640 • Ethane 12 . 8390 Propane 5. 5950 Isobutane 0.8750 n-Butane 1 .7560 Isopentane 0.4570 n-Pentane 0.3960 Cyclopentane 0 .0273 n-Hexane 0.0698 Cyclohexane 0 .0137 Other Hexanes 0 . 1333 Heptanes 0 .0313 Methylcyclohexane 0. 0091 Benzene 0 . 0080 Toluene 0 . 0057 Ethylbenzene 0 . 0002 xylenes 0 . 0032 C8+ Heavies 0 . 0177 DRY GAS: N Flow Rate: Water 58 .0 MMSCF/day r Content : 7. 0 lbs . H2O/MMSCF Page : 2 • T.FAN GLYCOL: Glycol Type: TEG Water Content : 1 .5 wt% H2O Flow Rate: 7 .5 gpm PUMP: Glycol Pump Type: Gas Injection Gas Injection Pump Volume Ratio: 0 . 080 acfm gas/qpm glycol FLASH TANK: Flash Control: Recycle/recompression Temperature : 120 . 0 deg. F Pressure : 50. 0 psig •. REGENERATOR OVERHEADS CONTROL DEVICE: Control Device: Condenser • Temperature : 120 . 0 deg. F Pressure : 14 . 7 psis N GRI-GLYCaic VERSION 4 . 0 - AGGREGATE CALCULATIONS REPORT Page: 1 • Case Name : Marla File Name : D:\Colorado\Applications 2002\Marla\worstcase .ddf Date : April 30, 2002 DESCRIPTION: Description: Parameters Modifications Annual Hours of Operation: 8760 . 0 hours/yr EMISSIONS REPORTS : CONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0. 6906 16 . 575 3 . 0250 Ethane 0. 9445 22. 667 4 . 1368 Propane 1.41'11 34 . 011 6 . 2071 • Isobutane 0.4711 11.307 2 . 0636 n-Butane 1. 3460 32.304 5 . 8954 Isopentane 0 .4241 10. 179 1 . 8577 n-Pentane 0 .4779 11 .469 2 . 0931 • Cyclopentane 0. 2317 5 . 561 1 .0148 n-Hexane 0.1614 3 . 874 0 .7070 Cyclohexane 0.2040 4 . 895 0 . 8934 Other Hexanes 0.2405 5 . 773 1. 0535 Heptanes 0 . 1156 2 .775 0 . 5065 Methylcyclohexane 0. 1174 2 .817 0 . 5141 Benzene 1.3457 32 .296 5. 8940 Toluene 0 . 7481 17 . 954 3 . 2766 Ethylbenzene 0 . 0149 0 .358 0 . 0654 Xylenes 0 . 2748 6 . 595 1 .2036 O8+ Heavies 0 . 0014 0 . 033 0 . 0061 Total Emissions 9 . 2269 221.445 40 .4138 Total Hydrocarbon Emissions 9 . 2269 221 .445 40 .4138 Total VOC Emissions 7 .5918 182 . 202 33 .2520 Total HAP Emissions 2 . 5449 6] . 077 11.1466 Total BTEX Emissions 2 .3835 57 . 203 10 .4396 401 UNCONTROLLED REGENERATOR EMISSIONS SPage: 2 Component lbs/hr lbs/day tons/yr . Methane 0 . 6917 16 . 602 3 .0298 Ethane 0 . 9513 22 . 831 4 .1667 Propane 1.4675 35 . 220 6 .4277 Isobutane 0 . 5045 12 . 109 2 .2098 n Butane 1.4780 35 .471 6 .4735 Isopentane 0.5298 12 . 715 2 . 3205 n-Pentane 0 . 6377 15 . 304 2 . 7930 Cyclopentane 0 . 3348 8 . 034 1 .4662 n-Hexane 0 .2838 6 . 812 1 . 2431 Cyclohexane 0 .4219 10 . 125 1 . 8478 Other Hexanes 0 .3672 8 . 814 1 .6085 Heptanes 0 .3627 8 . 704 1 .5885 Methylcyclohexane 0 . 3755 9 . 013 1. 6449 Benzene 3 .2856 78 . 853 14 .3907 Toluene 3 . 8490 92 . 375 16 . 8585 Ethylbenzene 0 . 1951 4 . 682 0 . 8544 Xylenes 4 . 3391 104 . 139 19 . 0053 C8+ Heavies 1 . 0837 26 . 008 4 . 7464 Total Emissions 21 . 1588 507 . 810 92 .6754 O• Total Hydrocarbon Emissions 21 . 1588 507 .810 92 .6754 Total VOC Emissions 19 . 5157 468 .377 85 .4789 Total HAP Emissions 11. 9525 286 .861 52.3521 Total BTEX Emissions 11 . 6687 280 .049 51 .1089 FLASH GAS EMISSIONS Note: Flash Gas Emissions are zero with the Recycle/recompression control option. FLASH TANK OFF GAS Component lbs/hr lbs/day tons/yr Methane 97. 9172 2350 . 012 428.8772 Ethane 37 . 1646 891. 952 162 .7812 Propane 26 . 0855 626 . 051 114 .2544 Isobutane 5 . 8092 139 .420 25.4441 n-Butane 12 . 8580 308 . 592 56.3180 Isopentane 3 . 9923 95 . 815 17.4863 Ille n-Pentane 3 . 8175 91 .620 16. 7207 Cyclopentane 0 . 5039 12 .093 2 . 2069 n-Hexane 0 . 9156 21 . 975 4 . 0104 Page: 3 II Cyclohexane 0 . 3429 8 . 229 1. 5018 • Other Hexanes 1 . 5876 38 . 103 6 . 9539 Heptanes 0 . 5553 13 . 327 2 .4322 Methylcyclohexane 0 . 2333 5 . 598 1 . 0217 Benzene 0 . 3550 8 . 519 1 .5547 Toluene 0 . 2605 6 .252 1 . 1409 Ethylbenzene 0 . 0074 0 . 179 0 . 0326 Xylenes 0 . 1136 2.727 0 .4976 08+ Heavies 0 . 1406 3 .375 0 . 6160 Total Emissions 192 . 6599 4623 .839 843 . 8506 Total Hydrocarbon Emissions 192 . 6599 4623 .839 843 . 8506 Total VOC Emissions 57. 5781 1381. 875 252 . 1922 Total HAP Emissions 1. 6521 39 . 651 7.2363 Total BTEX Emissions 0 . 7365 :7. 676 3 .2259 EQUIPMENT REPORTS : •• CONDENSER Condenser Outlet Temperature : 120 . 00 deg. F Condenser Pressure : 14 .70 psis Condenser Duty: 6 . 58e-002 MM BTU/hr Hydrocarbon Recovery: 0 . 96 bbls/day Produced Water: 5 .47 bbls/day VOC Control Efficiency: 61 . 10 % HAP Control Efficiency: 78 .71 % BTEX Control Efficiency: 79 . 57 % Dissolved Hydrocarbons in Water: 754 . 24 mg/L Component Emitted Condensed Water 0 . 67% 99 . 33% Carbon Dioxide 98 . 99% 1. 01% Nitrogen 99 . 72% 0 . 28% Methane 99 . 84% 0 . 16% Ethane 99 .28% 0 . 72% Propane 96 . 57% 3 .43% Isobutane 93 . 38% 6 . 62% n-Butane 91. 07% 8 . 93% Isopentane 80 . 05% 19 . 95% n-Pentane 74 . 94% 25 . 06% Cyclopentane 69 .21% 30 . 79% n-Hexane 56. 88% 43 . 12% Cyclohexane 48.35% 51.65% . ?age : 4 Other Hexanes 65 .50% 34 . 50"% Heptanes 31 .88% 68 . 12% • Methylcyclohexane 31 .26% 68 . 74% Benzene 40 . 96% 59. 04% Toluene 19 .44% 80. 56% Ethylbenzene 7 .66% 92 . 34% Xylenes 6 . 33% 93 . 67% C8+ Heavies 0 . 13% 99. 87% ABSORBER NOTE: Because the Calculated Absorber Stages was below the minimum allowed, GRI-GLYCalc has set the number of Absorber Stages to 1 .25 and has calculated a revised Dry Gas Dew Point. Calculated Absorber Stages : 1 . 25 Calculated Dry Gas Dew Point : 1 . 72 lbs . H2O/MMSCF Temperature: 80 . 0 deg. F Pressure: 900 . 0 psig O Dry Gas Flow Rate: 58 . 0000 MMSCF/day • Glycol Losses with Dry Gas: 0 . 6220 lb/hr Wet Gas Water Content : Saturated Calculated Wet Gas Water Content : 35 . 01 lbs. H2O/MMSCF Calculated Lean Glycol Recirc . Ratio: 5 . 59 gal/lb H2O Remaining Absorbed Component in Dry Gas in Glycol Water 4 . 91% 95. 09% Carboy. Dioxide 99 .81% 0. 19% Nitrogen 99 . 98% 0. 02% Methane 99 . 99% 0. 01% Ethane 99 . 96% 0. 04% Propane 99 . 94% 0. 06% Isobutane 99 . 92% 0. 08% n-Butane 99 . 89% 0. 11% Isopentane 99 . 90% 0 . 10% n-Pentane 99 . 87% 0. 13% Cyclopentane 99 .43% 0. 57% n-Hexane 99 . 80% 0. 20% Cyclohexane 99 . 07% 0. 93% Other Hexanes 99 . 85% 0 . 15% Heptanes 99 . 66% 0.34% Methylcyclohexane 99 . 05% 0. 95% Benzene 90 . 97% 9. 03% Toluene 87 .83% 12 . 17% Page: 5 • Ethylbenzene 85 . 14% 14 . 86% Xylenes 79 . 54% 20 .46% • C8+ Heavies 99 .48% 0 . 521 FLASH TANK Flash Control : Recycle/recompression Flash Temperature : 120 . 0 deg. F Flash Pressure: 50 . 0 psig Left in Removed in Component Glycol Flash Gas Water 99 .77% 0 .23% Carbon Dioxide 8.14% 91. 86% Nitrogen 0.68% 99 .32% Methane 0 . 70% 99 .30% Ethane 2 .50% 97 . 50% Propane 5.33% 94 . 67% Isobutane 7. 99% 92 . 01% n-Butane 10.31% 89 . 69% Isopentane 11. 92% 88 . 08% • n-Pentane 14 . 54% 85 .46% Cyclopentane 40.17% 59 . 83% n-Hexane 23 .90% 76. 10% Cyclohexane 56 .45% 43. 55% Other Hexanes 19.25% 80.75% Heptanes 39.73% 60 . 27% Methylcyclohexane 63 .06% 36 . 94% Benzene 90 .73% 9.27% Toluene 94 .16% 5.84% Ethylbenzene 96 . 70% 3 .30% Xylenes 97. 78% 2 . 22% C8+ Heavies 89. 67% 10. 33% REGENERATOR No Stripping Gas used in regenerator. Remaining Distilled Component in Glycol Overhead Water 44 . 00°% 55 . 91 Carbon Dioxide 0 . 00% 100. 00% Nitrogen 0. 00% 100 . 00% Page: 6 • Methane 0 . 00% 100 .00% Ethane 0 . 00% 100 . 00% • Propane 0 . 00% 100 . 00% lsobutane 0 . 00% 100. 00% n- Butanc 0 . 00% 100. 00% Isopentane 1 . 96% 98 . 04% n-Pentane 1 . 83% 98 . 17% Cyclopentane 1 . 04% 98 . 96% n-Hexane 1 . 33% 98 . 67% Cyclohexane 5 . 06% 94 . 94% Other Hexanes 2 . 97% 97 . 03% Hcptares 0 . 94% 99 . 06% Methylcyclohexane 5.69% 94 . 31% Benzene 5.45% 94 . 55% Toluene 8.32% 91 .68% Ethylbenzene 10.69% 89 .31% Xylenes 13 .16% 86 . 84% C8+ Heavies 11.23% 88. 77% STREAM REPORTS : • WET GAS STREAM Temperature: 80. 00 deg. F Pressure: 914 . 70 psia Flow Rate: 2 .42e+006 scth Component Conc. Loading (vol%) (lb/hr) Water 7 . 38e-002 8 .47e+001 Carbon Dioxide 2 . 28e+000 6 . 38e+003 Nitrogen 4 .21e-001 7 . S1e+002 Methane 7 . 50e+001 7 . 67e+004 Ethane 1 . 28e+001 2 . 46e+004 Propane 5. 59e+000 1. 57e+004 Isobutane 8. 74e-001 3 . 24e+003 n-Butane 1. 75e+000 6 . 50e+003 Isopentane 4 . 57e-001 2 .10e+003 n-Pentane 3 . 96e-001 1 . 82e+003 Cyclopentane 2 . 73e-002 1 .22e+002 n-Hexane 6 . 97e-002 3 . 83e+002 Cyciohexane 1 . 37e-002 7. 35e+001 Other Hexanes 1 .33e-001 7. 32e+002 Page : 7 Heptanes 3 . 13e-002 2 . 00e+002 • Methylcyclohexane 9 . 09e-003 5 . 69e+001 Benzene 7 . 99e-003 3 . 9Se+001 Toluene 5 . 70e-003 3 .35e+001 Ethylbenzene 2 . OOe-004 1 .35e+000 Xylenes 3 . 20e-003 2 .16e+001 C8+ Heavies 1 . 77e-002 1 .92e+002 Total Components 100 . 00 1 .40e+005 DRY GAS STREAM Temperature: 80 . 00 deg. F Pressure: 914 .70 psia Flow Rate: 2 . 42e+006 scfh Component Conc. Loading (vol%) (lb/hr) Water 3 . 63e-003 4 .16e+000 Carbon Dioxide 2 . 27e+000 6 .37e+003 Nitrogen 4 . 21e 001 7 .51e+002 Methane 7 . 51e+001 7 . 67e+004 • Ethane 1 . 28e+001 2 .46e+004 Propane 5 . 59e+000 1 . 57e+004 Isobutane 8 . 75e-001 3 .24e+003 n-Butane 1 . 75e+000 6 .50e+003 Isopentane 4 . 57e-001 2.10e+003 n-Pentane 3 . 96e-001 1. 82e+003 Cyclopentane 2 . 72e-002 1. 21e+002 n-Hexane 6 . 97e-002 3 . 82e+002 Cyclohexane 1 . 36e-002 7.28e+001 Other Hexanes 1 .33e-001 7.31e+002 Heptanes 3 .12e-002 1. 99e+002 Methylcyclohexane 9 . 02e-003 5 . 64e+001 Benzene 7 .28e-003 3 . 62e+001 Toluene 5 . 01e-OC3 2 . 94e+001 Ethylbenzene 1 . 70e-OC4 1 . 15e+000 Xylenes 2 . 55e-OC3 1 . 72e+001 C8+ Heavies 1 .76e 002 1 . 91e+002 Total Components 100. 00 1.40e+005 • LEAN GLYCOL STREAM Temperature : 80.00 deg. F p Page : e • Flow Rate : 7 . S0e+000 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9 . 85e+001 4 . 16e+003 Water 1. 50e+000 6 .33e+001 Carbon Dioxide 2 .95e-011 1.24e-009 Nitrogen 2 . 85e-013 1 . 20e-011 Methane 8 . 27e-018 3 .49e-016 Ethane 1 .10e-007 4 .64e-006 Propane 9 . 14e-009 3 . 86e-007 Isobutane 1 . 84e 009 7 . 76c-008 n-Butane 4 . 03e-009 1 .70e-007 Isopentane 2 .51e-004 1.06e-002 n-Pentane 2 . 81e-004 1. 19e-002 Cyclopentane 8 .31e-005 3 .51e-003 n-Hexane 9 . 03e-005 3 .81e-003 Cyclohexane 5 .33e-004 2 .25e-002 Other Hexanes 2 . 66e-004 1 .12e-002 Heptanes 8 .19e-005 3 .46e-003 Methylcyclohexanc 5 .36e-004 2 .26e-002 Benzene 4 .48e-003 1 . 89e-001 Toluene 8 . 28e-003 3 .49e-001 Ethylbenzene 5.53e-004 2.34e-002 Xylenes 1 . 56e-002 6 . 57e-001 C8+ Heavies 3 . 25e-003 1 .37e-001 Total Components 100 .00 4 .22e+003 RICH GLYCOL AND PUMP GAS STREAM Temperature : 80 . 00 deg. F Pressure: 914 .70 psia Flow Rate: 8 . 17e+000 gpm NOTE: Stream has more than one phase. Component Conc. Loading (wt%) (lb/hr) TEG 9 .16e4001 4 . 16e4003 Water 3 .17e+000 1 .44e+002 Carbon Dioxide 4 .36e-001 1. 98e+001 Nitrogen 2 . 17e-002 9 .84e-001 Methane 2 .17e+000 9 . 86e+001 Ethane 8 .40e-001 3 . 81e+001 Propane 6 .08e-001 2.76e+001 Isobutane 1 .39e-001 6 .31e+000 n-Butane 3 . 16e-001 1 .43e+001 Page : 9 • Isopentane 9 . 99e-002 4 . 53e+000 • n-Pentane 9 . 85e-002 4 . 47e+000 Cyclopentane 1 . 86e-002 8 .42e-001 n-Hexane 2 . 65e-002 1 .20e+000 Cyclohexane 1 . 74e-002 7 . 87e-001 Other Hexanes 4 . 34e-002 1 .97e+000 Heptanes 2 . 03e-0C2 9 . 21e-001 Methylcyclohexane 1 .39e-002 6 .31e- 001 Benzene 8 .44e-002 3 .83e+000 Toluene 9 .83e-002 4 .46e+000 Ethylbenzene 4 . 98e-003 2 . 26e-001 Xylenes 1.13e-001 5.11e+000 C8+ Heavies 3 .00e-002 1 .36e+000 Total Components 100. 00 4 .54e+003 FLASH TANK OFF GAS STREAM Temperature: 120 .00 deg. F Pressure: 64 .70 psia Flow Rate: 3 . 37e+003 scfh �• Component Conc . Loading (vol%) (lb/hr) Water 2 .07e-001 3 . 32e-001 Carbon Dioxide 4 .65e+000 1.82e+001 Nitrogen 3 . 93e-001 9 . 78e-001 Methane 6 .87e+001 9 . 79e+001 Ethane 1 .39e+001 3 .72e+001 Propane 6 . 66e+000 2 .61e+001 Isobutane 1. 12e+000 5 . 81e+000 n-Butane 2 .49e+000 1.29e+001 Isopentane 6 .23e-001 3 .99e+000 n-Pentane 5.95e-001 3 .82e+000 Cyclopentane 8 . 09e-002 5 . 04e-001 n-Hexane 1.20e-001 9. 16e-001 Cyclohexane 4 .59e-002 3 .43e-001 Other Hexanes 2.07e-001 1 .59e+000 Heptanes 6 . 24e-002 5 . 55e-001 Methylcyclohexane 2 .67e-002 2.33e-001 Benzene 5 .11e-002 3 .55e-001 Toluene 3 . 18e-002 2 . 60e-001 Ethylbenzene 7 . 89e-004 7 .44e-003 Xylenes 1 .20e-002 1.14e-001 C8+ Heavies 9 .29e-003 1.41e-001 • Page : 10 Total Components 100 . 00 2 . 12e+002 FLASH TANK GLYCOL STREAM Temperature : 120 . 00 deg. F Flow Rate : 7 . 70e+000 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9 . 61e+001 4 . 16e+003 Water 3 . 32e4000 1 .44e+002 Carbon Dioxide 3 . 72e-002 1 .61e+000 Nitrogen 1 . 55e-004 6 .69e-003 Methane 1 . 60e-002 6 . 92e-001 Ethane 2 .20e-002 9 . 51e-001 Propane 3 .39e-002 1.47e+000 Isobutane 1 .17e-002 5 .05e-001 n-Butane 3 .42e-002 1 .48e+000 Isopentane 1.25e-002 5 .40e-001 n-Pentane 1. 50e-002 6 .50e-001 Cyclopentane 7 . 82e-003 3 .36e-001 •tb n-Hexane 6 . 65e-003 2 .88e-001 Cyclohexane 1 . 03e-002 4 .44e-001 Other Hexanes 8 . 76e-0C3 3 . 78e-001 Heptanes 8 .47e-003 3 .66e-001 Methylcyclohexane 9 . 21e-003 3. 98e-001 Benzene 8 .04e-002 3 .47e+000 Toluene 9 .71e-002 4 .20e+000 Ethylbenzene 5 .05e-003 2 . 18e-001 Xylenes 1 . 16e-001 5. 00e+000 C8+ Heavies 2 . 82e-002 1 .22e+000 Total Components 100.00 4 .32e+003 FLASH GAS EMISSIONS Control Method: Recycle/recompression Control Efficiency: 100 . 00 Note: Flash Gas Emissions are zero with the Recycle/recompression control option. REGENERATOR OVERHEADS STREAM Temperature : 212 .00 deg. F Page : 11 • Pressure : 14 . 70 psia Flow Rate : 1 . 83e4003 scfh • Component Cone. Loading (von) (1b/hr) Water 9 . 27e+001 8 . 03e+001 Carbon Dioxide 7 . 60e-001 1. 61e+000 Nitrogen 4 . 97e-003 6.69e-003 Methane 8 . 96e-001 6. 92e-001 Ethane 6 .58e-001 9 .51e-001 Propane 6 .92e-0C1 1 .47e+000 Isobutane 1. 80e-001 5. 05e-001 n-Butane 5 . 29e-001 1.48e+000 Isopentane 1 . 53e-001 5 .30e-001 n-Pentane 1 .84e-001 6 .38e-001 Cyclopentane 9 . 92e-002 3 .35e-001 n-Hexane 6 . 85e-002 2. 84e-001 Cyclohexane 1 . 04e-001 4.22e-001 Other Hexanes 8 . 86e-002 3 .67e-001 Heptanes 7 . 52e-002 3 . 63e-001 Methylcyclohexane 7. 95e-002 3 . 76e-001 Benzene 8 .74e-001 3 .29e+000 • Toluene 6 .68e-001 3 .85e+000 Ethylbenzene 3 .82e-002 1.95e-001 Xylenes 8 .49e-001 4 .34e+000 C8+ Heavies 1 .32e-001 1. 08e+000 Total Components 100 . 00 1.03e+002 CONDENSER VENT GAS STREAM Temperature: 120 . 00 deg. F Pressure : 14 .70 psia Flow Rate: 9 .77e+001 scfh Component Conc. Loading (vol ) (lb/hr) Water 1 . 16e+001 5.38e-001 Carbon Dioxide 1 .41e+001 1.59e+000 Nitrogen 9 .25e-002 6 . 67e-003 Methane 1 .67e+001 6 . 91e-001 Ethane 1 .22e+001. 9 .44e-001 Propane 1 .25e+001 1.42e+000 Isobutane 3 . 15e+000 4.71e-001 N n-Butane 8 . 99e+000 1. 35e+000 Isopentane 2 .28e+000 4 . 24e-001 n-Pentane 2.57e+000 4 . 78e-001 Page: 12• Cyclopentane 1 . 28e+000 2 .32e-001 • n-Hexane 7 .27e-001 1 . 61e-001 Cyclohexane 9 .41e-001 2 . 04e-001 Other Hexanes 1 . 08e+000 2 .41e-001 Heptanes 4 .48e-001 1 .16e-001 Methylcyclohexane 4 .64e-001 1.17e-001 Benzene 6 . 69e+000 1 .35e+000 Toluene 3 . 35e+000 7 .48e-001 Ethylbenzene 5 .46e-002 1 .49e-002 Xylenes 1 . 01e+000 2 . 75e-001 O8+ Heavies 3 .15c-003 1 .38e-003 Total Components 100 . 00 1. 14e+001 CONDENSER PRODUCED WATER STREAM Temperature: 120 . 00 deg. F Flow Rate: 1.60e-001 gpm Component Conc. Loading (wt%) (1b/hr) (ppm) •• Water 9 .99e+001 7 . 97e+001 999122. Carbon Dioxide 1.23e-002 9 . 85e-003 123 . Nitrogen 1. 35e-006 1 . 08e-006 0. Methane 2 . 69e-004 2.15e C04 3 . Ethane 4 . 18e-004 3 .34e-004 4 . Propane 6 .47e-004 5 . 16e-004 6 . Isobutane 1 . 17e-004 9 .35e-005 1 . n-Butane 4 . 44e-004 3 .55e-004 4 . Isopentane 9.86e-005 7 .87e-005 1 . n-Pentane 1 . 19e-004 9 .52e-005 1 . Cyclopentane 4 . 07e-004 3.25e-004 4 . n-Hexane 3 .34e-005 2.66e-005 0 . Cyclohexane 2 .38e-004 1. 90e-004 2. Other Hexanes 4 .01e-005 3 . 20e-005 0 . Heptanes 1 .32e-005 1 . 06e-005 0 . Methylcyclohexane 6 . 53e-005 5 .21e-005 1 . Benzene 4 .42e-002 3 .53e-002 442 . Toluene 2 . 02e-002 1 .61e-002 202 . Ethylbenzene 3 . 04e-004 2 .43e-004 3 . Xylenes 7 . 76e-003 6 . 19e-003 78 . C8+ Heavies 9 .97e-008 7 . 96e-008 0 . Total Components 100 . 00 7.98e+001 1000000 . Page: 13 . CONDENSER RECOVERED OIL STREAM • Temperature : 120 . 00 deg. F Flow Rate : 2 . 79e-002 gpm Component Conc . Loading (wt%) (1b/hr) Water 5.20e-002 6 .18e-003 Carbon Dioxide 5.40e-002 6 .42e-003 Nitrogen 1.49e-004 1 .77e-005 Methane 7. 36e-003 8 .75e-004 Ethane 5 .47e-D02 6 .50e-003 Propane 4 . 19e-001 4 . 98e-002 Isobutane 2 . 80e-001 3 .33e-002 n-Butane 1 .11e+000 1.32e-001 Isopentane 8 .89e-001 1. 06e-001 n-Pentane 1 .34e+000 1. 60e-001 Cyclopentane 8 .65e-001 1 . 03e-001 n-Hexane 1 .03e+000 1. 22e-001 Cyclohexane 1.83e+000 2 , 18e-001 Other Hexanes 1.07e+000 1 .27e-001 Heptanes 2.08e+000 2.47e-001 .• Methylcyclohexane 2 . 17e+000 2 .58e-001 Benzene 1. 60e+001 1.90e+000 Toluene 2 . 60e+001 3 .08e+000 Ethylbenzene 1 . 51e+000 1.80e-001 Xylenes 3 .41e+001 4 . 06e+000 C8+ Heavies 9 .11e+000 1. 08e+000 Total Components 100.00 1. 19e+001 p. • 0 Duke Energy Fler., Services, Inc. • Minden Plant Laboratory Minden, LA 323 ANGI Road, Highway 159 Nerth, Minden.LQUISIANA Extended Analysis of Gas Sample Date of Sample: 25-Sep-01 Date of Analysis: 04-Oct-01 Lease Number: 0 • Lease Name: Marla comp. Before contactors Producer: D.E.F.S. Component MoI% Wt% Nitrogen 0.4210- 0.5380 Methane 75.0640' 54.9387 CO2 2.2770 4.5717 Ethane 12.8390- 17.6127 Propane 5.5950- 11.2557 . 4116. Iso-Butane 0.8750 2.3202 N-Butane 1.7560 4.6562 Iso-Pentane 0.4570 1.5042 N-Pentane 0.3960 1.3034 2,2-Dimethylbutane(Neohexane) i 0.0051 0.0202 ,2,3-Dimethylbutane(Cyclopentane) 0.0273 0.0973 2-Methylpentane 0.0710 0.2791 3-Methylpentane 0.0348 0.1367 N-Hexane 0.0698 0.2746 2,2-Dimethylpentane 0.0011 0.0049 Methylcyclopentane . 0.0224 0.0861 2,4-Dimethylpentane 0.0014 0.0064 2,2,3-Trimethy butane 0.0002 0.0011 Benzene 0.0080 0.0284 3,3-Dimethylpentane 0.0004 0.0018 Cyclohexane 0.0137 0.0526 2-Methylhexane 0.0062 0.0284 2,3-Dimethylpentane 0.0016 0.0075 1,1-Dimethylcyclopentane 0.0010 0.0047 3-Methylhexane 0.0057 0.0260 • 1,t-3-Dimethylcyclopentane 0.0015 0.0067 1,c-3-Dimethylcyclopentane 0.0016 0.0072 1,t-2-Dimethylcyclopentane 0.0020 0.0088 N-Heptane 0.0086 0.0392 NMethlycyclohexane 0.0091 0.0408 • Component Mot% Wt 1c2 DimethylCycloPentane 0.0000 0 0000 2,5-Dimethylhexane 0.0002 0.0012 2-4 Dimethyhexane 0.0005 0.0027 3,3 DimethylHexane 0.0031 0.0161 • 1,t-2,c-3-Trimethylcyclopentane 0.0002 0.0009 2,3,4-Trimethylpentane 0.0000 0.0001 2.3 DimethylHexane 0.0000 0.0000 Toluene 0.0057 0.0239 1,1,2-Trimethytcyclopentane 0.0002 0.0009 MethytHeptanes 0.0000 0.0000 2-Methytheptane 0.0013 0.0068 4-Mettiylheptane 0.0004 0.0018 3,4-Dimethythexane 0.0001 0.0004 3-Methytheptane 0.0010 0.0052 3-Ethylhexane 0.0000 0.0000 1,c-3-Dimethylcyclohexane 0.0009 0.0045 1,t-4-Dimethylcydohexane 0.0004 0.0021 •' 2,2,5-Trimethylhexane 0.0000 0.0001 . 1,1 DimethyCydoHexane 0.0002 0.0010 1 mt3 EthytCydoPentane 0.0000 0.0000 1mc3£thylCydoPentane 0.0000 0.0002 lmt2 EthylCydoPentane 0.0001 0.0003 . . CycloHeptane 0.0000 0.0000 N-Octane 0.0026 0.0134 Trimethylhexanes 0.0000 0.0002 1,t-3-Dinmethytcydohexane 0.0002 0.0011 Isopropylcyclopentane 0.0000 0.0001 2,3,5 TrimethytHexane 0.0000 0.0001 2,2, DimethytHeptane 0.0001 0.0005 2,4, DimethytHeptane 0.0001 0.0008 2,2,3 TrimethytHeptane 0.0000 0.0000 2,6 DimethytHeptane 0.0002 0.0015 N-Propylcyclopentane 0.0001 0.0004 2,5 DimethytHeptane 0.0007 0.0041 Ethytcyclohexane 0.0000 0.0000 3,3 DimethylHeptane 0.0002 0.0011 1,1,4 TrimethylCydoHexane 0.0001 0.0003 Trimethylhexanes 0.0000 0.0001 Ethylbenzene 0.0002 0.0012 N 1t2t4 TrimethylCycloHexane 0.0000 0.0000 1 c3t5TrimethylCydoHexane 0.0003 0.0017 M& P-Xylenes • 0.0027 0.0132 2&4-Methyloctane 0.0006 0.0033 • • Component Mol% Wt 3-Methyloctane 0.0004 0.0023 112c3 Trimethylcyciohexane 0.0001 0.0003 Ortho-Xylene 0.0005 0.0025 • 1,1,2 Trimethylcyclohexane 0.0001 0.0005 1c2t4 Trimethylcyclohexane 0.0002 0.0010 1c2c4 Trimethylcyclohexane 0.0001 0.0005 N-Nonane 0.0011 0.0065 2,5,5 Trimethy1Heptane 0.0000 0.0001 . C9 Naphthenes/C10 Paraffins 0.0000 _ 0.0002 1c2t3 TrimethylCydoHexane 0.0001 0.0005 C9 Naphthenes/C10 Paraffins 0.0000 0.0002 C9 Naphthenes/C10 Paraffins 0.0001 0.0007 lsopropylbenzene 0.0000 0.0001 Isopropylcyclohexane 0.0002 0.0009 CycloOctane 0.0000 0.0000 C9 Naphthenes/C10 Paraffins 0.0000 0.0001 C9 Naphthenes/C10 Paraffins 0.0000 0.0002 . N-Propylcyclohexane 0.0003 0.0017 • CS Naphthenes 1 C10 Paraffins 0.0000 0.0002 C9 Naphthenes 1 C10 Paraffins 0.0000 0.0002 C9 Naphthenes I C10 Paraffins 0.0000 0.0002 N-Propylbenzene 0.0001 0.0005 C9 Naphthenes I C10 Paraffins 0.0000 0.0001 1m3 EthylBenzene/M/EthylToluene 0.0002 0.0009 1m4 EthylBenzene/P/EthylTotuene 0.0001 0.0008 4,5-Methylnonane(Ave 4 85) 0.0002 0.0016 2-Methylnonane • 0.0001 0.0006 • C9 Naphthenes/C10 Paraffins 0.0000 0.0002 3-Methylnonane 0.0001 0.0004 C9 Naphthenes/C10 Paraffins 0.0000 0.0002 C9 Naphthenes/C10 Paraffins 0.0000 0.0002 tert-Butylbenzene 0.0002 0.0012 tert-Butylcydohexane 0.0000 0.0002 IsoButylCydoHexane 0.0000 0.0001 N-Decane 0.0002 0.0014 Isobutylbenzene 0.0000 0.0001 sec-butylbenzene 0.0000 0.0001 1m31soPropylBenzene 0.0000 0.0000 1.2,3-Trimethylbenzene 0.0000 0.0002 N C10 Aromatics/C11 Paraffins 0.0000 0.0002 C10 Aromatics /C11 Paraffins 0.0000 0.0002 1 m2 IsoPropyI6enzene 0.0000 0.0000 C10 Aromatics/C11 Paraffins 0.0000 0.0001 N-Butylcyclohexane 0.0000 0 0000 Component Mol°/p Wt 6/0 C10 Aromatics/C11 Paraffins 0.0000 0.0002 C10 Aromatics/ C11 Paraffins 0.0000 0.0001 1,3-Diethylbenzene 0 0000 0.0001 1,2-Diethylbenzene/N-Butylbenzene 0.0000 0.0002 1,4,-Diethlybenzene 0.0000 0.0001 C10 Aromatics/C11 Paraffins 0.0000 0.0001 lmethyl2PropylBenzerte 0.0000 0.0001 C10 Aromatics/C11 Paraffins 0.0000 0.0001 C10 Aromatics/C11 Paraffins 0.0000 0.0001 C10 Aromatics/C11 Paraffirts 0.0000 0.0000 C10 Aromatics/C11 Paraffins 0.0000 0.0000 N.Undecane 0.0000 0.0002 1,2,4,5 TetMethBenzene 0.0000 0.0000 1,2,3,5 TetMethBenzene 0.0000 0.0000 Unknown C12s 0.0000 0.0000 Unknown C12s 0.0000 0.0000 1,2,3,4 TetMethBenzene 0.0000 0.0000 • Unknown C12s 0.0000 0.0000 • Unknown C12s 0.0000 0.0000 Napthalene 0.0000 0.0000 N_0odecane 0.0000 0.0000 TOTALS 100.0000 100.0000 Total BTEX: 0.0171273 0.069137729 Total Aromatics: 0.0179722 0.07404981 Data For 06+ Fraction Real Relative Density @ 60F (Air=1) 3.0725 Molecular Weight: 88.9893 Compressability Factor(a: 1.0000 Cu. Ft.Vapor/Gal @ 14.896 PSIA/60 deg, 25.119 Cu. Ft. Vapor/Gal @ 14.650 PS1A/60 deg. 25,198 BTU/Cu. Ft. @ 14.696 PS1A, Dry(Ideal): 4834.20 BTU/Cu. Ft. @ 14.650 PSIA, Dry(Ideal): 4819.06 BTU/Lb.: 20459 Data For Total Sample Real Relative Density 60F(Air=1) 0.7598 Molecular Weight: 21.9199 • Compressability Factor(a: 0.9961 BTU/Cu. Ft @ 14.696 PSIA, Dry(Real): 1266.40 BTU/Cu. Ft. @ 14.650 PS1A, Dry(Real): 1262.44 BTU/Lb.: 21838 • Duke Energy Field Services, Inc. Gas Analysis Report stein N Snook Date Analy.Datc Duke Energy Field Services,lor. 0 1 09/25/01 10/04!01 Minden Laboratory 323 ANC[Road Station Namelfmn Highway 159 North Minden, Louisiana Marla comp. Before contactors 134 Lab Na:(318)377-3880 Fax No:(318)371-3686 Producer Pressure D.EF.S. 900 Component GPM GPM@ GPM . Mork Vila'/'/0 14.650 14.73 15.025 Nitrogen 0.4210 0,5380 Methane 75.0640 54.9387 •• Carbon Dioxide 2.2770 4.5717 Ethane 12.8390 17.6127 3.4131 3.4317 3.5005 Propane 5,5950 I[.2557 1.5322 1.5405 1.5714 Iso-Butane 0.8750 2.3202 0.2847 0.2862 0.2919 Normal-Butane 1.7560 4.6562 0.5506 0.5536 0.5647 Iso-Pentane- 0.4570 1.5042 0.1663 0.1672 0.1706 Normal-Pentane 0.3960 1.3034 0.1426 0.1434 0.1463 Hexane Plus 0.3200 1.2991 0.1285 0.1292 0.1318 100 100 6.2180 _ _ 6.2519 63772 Data to GPA 2145 Gross (ai1 60 Dee. F BTU(Real)@14.650 c Dry 1262.44 Sat 124035 BTU(Real)@14.730 cA Dry 1269.33 Sat 1247.25 0 BTU(Real)@15.025= Dry 1294.75 Sat 1272.67 Molecular Density(Reidy-- 0.7598 Weight= 21.920 'Z'Factor= 0.9961 • • APPENDIX B Application APENs .• APPLICATION FOR CONSTRUCTION PERMIT OR PERMIT MODIFICATION (previously referred to as EMISSION PERMIT) • This application must be filled out completely except for#14 and#15:otherwise,application will be considered incomplete E INSTRUCTIONS ON REVERSE SIDE. Mail completed application,APENs,and filing fee to: iiiColorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South,APCD-SS-BI Denver,Colorado 80246-1530 Telephone: (303)692-3I50 1. Permit to be issued to: Duke Energy Field Services,LP—Marta Compressor Station 2. Mailing Address:P.O.Box 5493,Denver State: CO Zip Code: 80217 3a. Agent for Service(See No. 3 on reverse):NA 3b. Federal Tax Identification Number:84-1041166 4a. General Nature of Business:Natural Gas Compression 4b.SIC Code: 1311 5a. Air Pollution Source Description: TEG Unit 5b.Days per year source will operate:365 6a. Source Location Address(Include Location Map): 6b.UTM Coordinates(in km) Site is located at the junction ofCR55 and CR40.1Sec28T4NR64W1 ___._H ____._V (If using Township and Range,give directions and distance from teares(town or intersection.) County: Weld 7. ESTIMATED COSTS: Air Pollution Control Procedures or Equipment 7a. Source, Process Equipment or Project: 7b. Capital Cost:$ � Cap.Cost$ 7c. Operating Cost:$ a. STATUS ❑ New Air Pollution Source • Modification to Permitted Source(Control Equipment added,process change, etc.): ❑ Transfer of Ownership—Transferred from: ❑ Existing Source-not permitted(Include Date of Source Start-up). ❑ Requesting to limit a source's Potential to Emit for criteria or Hazardous Air Pollutants using Regulation No. 3(for new and existing sources) ❑ Requesting to limit a source's Potential to Emit for Hazardous Air Pollutants only using Regulation No. 8(for existing sources only) O Other: Projected Dates for Construction to: 8d.Projected Source Startup Date: December 2001 Sb.Begin: NA 8c.End: NA 9. Enclose check to cover APEN FILING FEES. One APEN should be filed for each emission point NOTE: Additional processing fees must also be paid prior to permit issuance. 1 APENS @$119.96 per APEN=$ 119.96 (Please Invoke) 10. SIGNATURE OF LEGALLY AUTHORIZED PERSON(NOT Vendor or I la.Date Signed: l lb. akk Equipment Manufacturer) Phone:(720)944-9386 e,,,,,,,,„4,,, .' 94 z Fax: (303)389-1957 12. Type or Print name and official title of person signing item 10. for Agency Use Only 14, DATE RECEIVED Ashley Campsie,Environmental Engineer .i3. Check appropriate box if you want: 15. PERMIT NUMBER • Copy of preliminary analysis conducted by Division b.■ To review a draft of the permit prior to issuance Note:Gherkins either kern eould rang in iocrurtd f an&or Pmmri,g tine.See&none. -— 1:\CPUFORMS.95A\CP_APPM.9SA ------------- • STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT oF,cozott AIR POLLUTION CONTROL DIVISION �ti TELEPHONE: (303)692-3150 Nr a . * G.9 * ■ CONSTRUCTION PERMIT F`B°fi. PERMIT NO: 05WE0579 INITIAL APPROVAL DATE ISSUED: FEBRUARY 22, 2006 ISSUED TO: Duke Energy Field Services, LP THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: One Natural gas dehydration unit associated with a facility known as Maria Compressor Station, located in SE%Section 28, T4NS, R64W in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: One(1) P-113, TEG Dehydration System, rated at 45 mmscf per day. This emission unit removes water from pipeline gas. • THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: 1. 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. EPA Method 9 shall be used to measure opacity. (Reference: Regulation 1, Section II.A.1.&4.) 2. The permit number shall be marked on the subject equipment for ease of identification. (Reference: (Reference: Regulation No. 3, Part B, III.E.) 3. The manufacturer, model number and serial number of the subject equipment shall be provided to the Division prior to Final Approval. (Reference: Regulation No. 3, Part B, III.E.) 4. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis): (Reference: Regulation 3, Part B, II.A.4) Volatile Organic Compounds(VOC): 0.19 pounds per month and 2.23 tons per year Each Individual Hazardous Air Pollutant: 0.68 pounds per month and 8.00 tons per year All Hazardous Air Pollutants Combined: 1.70 pounds per month and 20.00 tons per year. (Note: Monthly emissions are based on 31 day month) During the first twelve (12) months of operation, compliance with both the monthly and yearly emission limitations shall be required.After the first twelve (12) months of operation, compliance • with only the yearly limitation shall be required. By the end of each month a new twelve month total is calculated based on the previous twelve months data. Monthly records of the actual emissions shall be maintained by the applicant and made available to the Division for inspection upon request. Compliance with the annual limits shall be determined on a rolling (12) month total. 123102341063 Page 2 Colorado Department of Public Health and Environment Air Pollution Control Division . Duke Energy Field Services, LP Permit No. 05WE0579 INITIAL APPROVAL 5. This source shall be limited to a maximum process and consumption rates as listed below and all other activities, operational rates and numbers of equipment as stated in the application. Daily records of the actual production rate shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3. Part a II.A.4) Natural gas processing shall not exceed 1,395 mmscf per month and 16,425 mmscf per year (Note: Monthly processing rate is based on 31 day month) During the first twelve(12)months of operation,compliance with both the monthly and yearly process rate limitations shall be required.After the first twelve(12)months of operation, compliance with only the yearly limitation shall be required. Compliance with the yearly consumption limits shall be determined on a rolling twelve(12) month total. 6. This source shall be limited to a maximum lean glycol pump rate as listed below and all other activities, operational rates and numbers of equipment as stated in the application. Annual records of the actual pump rate shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation No. 3, Part B, The maximum pumping rate of lean glycol shall not exceed 5.0 gallons per minute 7. This source shall be equipped with a condenser and flare control devices capable of reducing uncontrolled emissions of VOC and Hazardous Air Pollutants by at least 98%. Operating parameters of the control • equipment shall be identified prior to final approval of this permit. The identified operating parameters will replace the control efficiency requirement on the final permit. (Reference: Regulation No. 3, Part B, Section III.E.). 8. Prior to final approval being issued,the applicant shall submit to the Division for approval an operating and maintenance plan for all control equipment and control practices, and a proposed record keeping format that will outline how the applicant will maintain compliance on an ongoing basis with the requirements of conditions no. 4, 5, 6 and 7 listed above. (Reference: Reg. 3, Part B.III.G.4) 9. Running the GRI GlyCalc version 4.0 or higher model, on a monthly basis,shall demonstrate compliance with this permit. 10. A source compliance test shall be conducted during the summer quarter to measure the emission rate(s) for the pollutants listed below in order to show compliance with VOC emission limit.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 30 days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any stack 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 (Reference: Regulation No. 3, Part B., Section III.G.3) Volatile Organic Compounds (VOC) using EPA approved methods. 11. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 12. A revised Air Pollutant Emission Notice(APEN) shall be filed: (Reference: Reg. 3, Part A,II,C) a. Annually whenever a significant increase in emissions occurs as follows: • 123/0234/063 Page 3 Colorado Department of Public Health and Environment Air Pollution Control Division Duke Energy Field Services, LP Permit No. 05WE0579 INITIAL APPROVAL For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five tons per year or more, above the level reported on the last APEN; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5)tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. a. Whenever there is a change in the owner or operator of any facility, process, or activity; or b. Whenever new control equipment is installed,or whenever a different type of control equipment replaces an existing type of control equipment; or c. Whenever a permit limitation must be modified; or d. No later than 30 days before the existing APEN expires. 13. Prevention of Significant Deterioration(PSD)requirements shall apply to this source at any such time that this source modification becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable PSD threshold will require a full PSD • review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit is granted. (Reference: Regulation No. 3, Part B, IV.D.3.b.(iv)) 14. This source is subject to the provisions of Regulation No.3,Part C,Operating Permits(Title V of the 1990 Federal Clean Air Act Amendments).The provisions of this construction permit must be incorporated into the operating permit associated with this permit The application forthe modification to the Operating Permit is due within one year of commencing operation of the equipment covered by this perm*. (Reference Reg. 3, Part C, II.B.2) 15. Within one hundred and eighty days (180) after commencement of operation, compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee's responsibility to self certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Information on how to certify compliance was mailed with the permit.) 16. This permit shall expire if the owner or operator of the source for which this permit was issued:(i)does not commence construction/modification or operation of this source within 18 months after either the date of issuance of this initial approval permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii)discontinues construction for a period of eighteen months or more; or(iii)does not complete construction within a reasonable time of the estimated completion date(See General Condition No.6., Item 1.). Upon a showing of good cause by the permittee, the Division may grant extensions of the permit. (Reference: Regulation No. 3, Part B. Section III.F.4.) • By: r \:1 11. y Sunday A. Fadeyi, P.E. R K Hancock III, P.E. Permit Engineer Unit Leader 123/0234/063 Page 4 Colorado Department of Public Health and Environment Air Pollution Control Division • Duke Energy Field Services, LP Permit No. 05WE0579 INITIAL APPROVAL Notes to permit holder: 1) The production or raw material processing limits and emission limits contained in this permit are based on the production/processing rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice(APEN)and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Upset Conditions and Breakdowns. The permittee shall notify the Division of any upset condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than two(2) hours after the start of the next working day,followed by written notice to the Division explaining the cause of the occurrence and that proper action has been or is being taken to correct the conditions causing said violation and to prevent such excess emission in the future. 3) The emission levels contained in this permit are based on the following normalized emission factors (any change in operations may change these factors): Volatile Organic Compound (VOC): 0.2703 pounds per mmscf 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the throughput as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds. This information is listed on the Division's emission inventory system. • C.A.S.# SUBSTANCE [BIN] EMISSIONS [LB/YR] 71-43-2 Benzene (A) 483 1330-20-7 Xylenes (C) 404 1004414 Ethyl benzene(C) 37 108-88-3 Toluene (C) 811 5) This source is classified as a: Synthetic Minor source for Operating Permit Synthetic Minor source for PSD At a: Synthetic Minor facility for PSD facility Major facility for Operating Permit • 123/0234/063 Page 5 Colorado Department of Public Health and Environment • Air Pollution Control Division Duke Energy Field Services, LP Permit No,05WE0579 INITIAL APPROVAL GENERAL TERMS AND CONDITIONS: (IMPORTANTI READ ITEMS 5,6,7 AND 8) 1. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity,or construction,installation and operation of the source,in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 2. Unless specifically stated otherwise,the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 3. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of,a condition hereof shall constitute a rejection of the entire permit and upon such occurrence,this permit shall be deemed denied eh initio. This permit may be revoked at any time prior to final approval by the Air Pollution Control Division(APCD)on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission(AQCC),including failure to meet any express term or condition of the permit. If the Division denies a permit,conditions imposed upon a permit are contested by the applicant,or the Division revokes a permit,the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 4. This permit and any required attachments must be retained and made available for inspection upon request at the location set forth herein. With respect to a portable source that is moved to a new location,a copy of the Relocation Notice(required by law to be submitted to the APCD whenever a portable source is relocated) should be attached to this permit. 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. • 5. Issuance(initial approval)of an emission permit does not provide"final"authority for this activity or operation of this source. Final approval 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 II I.G.Final approval 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. If the APCD so determines,it will provide written documentation of such final approval,which does constitute"final"authority to operate.Compliance with the permit conditions must be demonstrated within 180 days after commencement of operation. 6. THIS PERMIT AUTOMATICALLY EXPIRES IF you(1)do not commence construction or operation within 18 months after either the date of issuance of this permit or the date on which such construction or activity was scheduled to commence as set forth in the permit,whichever is later;(2)discontinue construction for a period of 18 months or more;or(3)do not complete construction within a reasonable time of the estimated completion date. Extensions of the expiration date may be granted by the APCD upon a showing of good cause by the permittee prior to the expiration date. 7. YOU MUST notify the APCD at least thirty days (fifteen days for portable sources) prior to commencement of the permitted operation or activity. Failure to do so is a violation of Section 25-7- 114.5(12)(a),C.R.S.and AQCC Regulation No.3,Part B,Section III.G.1.,and can result in the revocation of the permit. You must demonstrate compliance with the permit conditions within 180 days alter commencement of operation as stated in condition 5. 8. Section 25-7-114.7(2)(a),C.R.S.requires that all sources required to file an Air Pollution Emission Notice (APEN)must pay an annual fee to cover the costs of inspections and administration.If a source or activity is to be discontinued,the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification,annual fee billing will terminate. 9. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and control Actor the regulations of the AQCC may result in administrative,civil or criminal enforcement actions under Sections 25-7-115(enforcement),-121(injunctions),-122(civil penalties),-122.1(criminal penalties),C.R.S. • 123/02341063 • Appendix E • Plot Plans and Process Flow Diagrams i Wz v o e a a Ow i g U o�4 ° H m ' a `Ea e` = I-CI i 3 W a z < .,.,.>e gZ L,,,....2 G L'rivl Erl H In 1 `o 2 13 .- o ' pY1:F;;t1 O fit- VC 3 o m 3 ';ieosb�`.! d c19 to cL L'' ¢ > m EE. Eto U cF ; LL in Q °0 0d$r ea_ V VZ 0 g li I s C 3 SS as uNflO3 I \ 3 3 \ 3 iLIE ,� U l uw-o gyp+ J eB�J '.. e a m/° ,9 lc 391„ �� a Ego j oii 1 - ggI c4 lclaa •@@ < d 4 g �g--O.W s!a• r-- W /N . 6 O sg o o m s a T3 ° k1a q q • 4g �' W le-J 1 1 al _L r`l I ae ,_ 03O--- 1, it °T. .1 ,., . z0 I II ,/ * I '/,, ,:i. ..2., ED- -'...' RI O iten.won . 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