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Home My WebLink About20121200.tiff . • STATE OF COLORADO John W.Hickenlooper,Governor aF.co�� Christopher E.Urbina,MD, MPH , .O Executive Director and Chief Medical Officer Fc Dedicated to protecting and improving the health and environment of the people of Colorado . o .1 4300 Cherry Creek Dr.S. Laboratory Services Division 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 May 1, 2012 Mr. Steve Moreno Weld County Clerk 1402 N. 17`h Ave. Greeley, CO 80631 Dear Mr. Moreno: On May 5, 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 ("Thank 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, cith { Ellen Evans Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure • .1)IAL 6.,. ��ti�/(( � � � ?�) i4 Fj -1 I .l '1= 2012-1200 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION OPERATING PERMIT RENEWAL SUMMARY PERMIT NUMBER: 95OPWE103 AIRS ID* 1230277 DATE: May 1, 2012 APPLICANT: DCP Midstream, LP— Enterprise Compressor Station, REVIEW ENGINEER: Bailey Kai Smith SOURCE DESCRIPTION DCP, Midstream, LP has applied for renewal of their Operating Permit issued for the Enterprise Compressor Station located in SWSW Section 30 T3N R63W, in between the towns of Keensburg and Roggen, Adams County. The Enterprise Compressor Station consists of six engines, two glycol dehydrators, fugitive emissions from equipment leaks, a condensate loadout, a condensate tank battery, and control flares and is classified under SIC 4922. 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. There are no 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 Putall at to {tvnsryeag N0x CO - Four G3612 engines 96.00 109.68 96.00 Two G3616 engines 64.02 73.16 64.02 Fugitive `' 1822 Cond Tanks - 128 Loadout 0.71 Dehy1 11.95 Dehy2 5.06 Flare 0.47 2.57 Total 160.47 185.42 197.22 EMISSION SOURCES The following discussion identifies the changes that were made in the renewal permit. Engines — Provisions to construct two new compressor engines were added in the renewal operating permit. The horsepower rating and emission limitations of the existing engines were adjusted. Dehydrator — Provisions to construct a new glycol dehydrator were added to the renewal permit. Requirements associated with a flare installed to control emissions from the dehydrator was included in the permit. The capacity of the existing dehydrator was increased and emission limits increased accordingly. Condensate Tank — The condensate throughput was increased and four new stabilized condensate tanks were added to the battery. Requirements for the control device installed on the tank battery were added to the operating permit. Other—The condensate loadout and fugitive emissions limits were increased in accordance with the increased capacity at the facility. ALTERNATIVE OPERATING SCENARIOS The most recent version of the engine replacement alternative operations scenarios was included in the operating permit. The two new compressor engines are also capable of using the engine replacement AOS. INSIGNIFICANT ACTIVITIES An updated list of insignificant activities was included in the operating permit. PERMIT SHIELD No changes were made to the permit shield. N o -07 � �rl SINE r�vsnl�w& t \ - 16 ,si; o4c * Ac0}0_,1876 Colorado Department of Public Health and Environment OPERATING PERMIT DCP Midstream, LP Enterprise Compressor Station Issued: May 1, 1999 Renewed: DRAFT AIR POLLUTION CONTROL DIVISION COLORADO OPERATING PERMIT FACILITY NAME: Enterprise OPERATING PERMIT NUMBER Compressor Station FACILITY ID: 1230277 95OPWE 103 RENEWED DATE: 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 sec and applicable rules and regulations. ISSUED TO: FACILITY LOCATION: DCP Midstream, LP SW 1/4 of SW 1/4, Section 30, T3N, R63W 370 17`h Street, Suite 2500 Between Keenesburg and Roggen, Colorado Denver, CO 80202 Weld County INFORMATION RELIED UPON Operating Permit Renewal Application Received: November 21, 2011 And Additional Information Received: April 5, 2010, January 13, 2012 Nature of Business: Natural Gas Liquids Processing and Gathering Primary SIC: 4922 RESPONSIBLE OFFICIAL FACILITY CONTACT PERSON Name: Joseph Kuchinski Name: Wesley Hill Title: Vice President Area North Operations Title: Senior Environmental Specialist 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, 2008 & 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 purposes of determining the timely receipt of those reports/certifications. Table of Contents: SECTION I - General Activities and Summary 1 1. Permitted Activities 1 2. Alternative Operating Scenarios (ver 10/1/2011) 2 3. Prevention of Significant Deterioration/New Source Review (PSD/NSR) 8 4. Accidental Release Program (112(r)) 9 5. Compliance Assurance Monitoring (CAM) 9 6. Summary of Emission Units 10 SECTION II - Specific Permit Terms 11 1. C-238 - Caterpillar 3550 HP Compressor Engine with oxidation catalyst 11 C-235 - Caterpillar 3550 HP Compressor Engine with oxidation catalyst 11 C-236 - Caterpillar 3550 HP Compressor Engine with oxidation catalyst 11 P018 - Caterpillar 3550 HP Compressor Engine with oxidation catalyst 11 2. C-237 and C-239 -Caterpillar 4735 HP Compressor Engines with oxidation catalyst 18 3. D2 and D3 - Triethylene Glycol Regeneration Units 27 4. P016 —Condensate Truck Loadout Rack controlled with a combustor 33 5. P012 - Fugitive VOC Emissions from Equipment Leaks 35 6. P013- Stabilized Condensate Tanks controlled with a combustor 37 7. Comb-1 —Dehy Combustor 39 8. Portable Monitoring (ver 6/1/2006) 41 9. Compliance Assurance Monitoring 42 SECTION III - Permit Shield 47 1. Specific Conditions 47 2. General Conditions 49 3. Stream-lined Conditions 49 SECTION IV- General Permit Conditions (Ver 11/16/2010) 50 1. Administrative Changes 50 2. Certification Requirements 50 3. Common Provisions 50 4. Compliance Requirements 54 5. Emergency Provisions 55 6. Emission Controls for Asbestos 55 7. Emissions Trading, Marketable Permits, Economic Incentives 56 8. Fee Payment 56 9. Fugitive Particulate Emissions 56 10. Inspection and Entry 56 11. Minor Permit Modifications 56 12. New Source Review 57 13. No Property Rights Conveyed 57 14. Odor 57 15. Off-Permit Changes to the Source 57 16. Opacity 57 Table of Contents: 17. Open Burning 57 18. Ozone Depleting Compounds 57 19. Permit Expiration and Renewal 57 20. Portable Sources 58 21. Prompt Deviation Reporting 58 22. Record Keeping and Reporting Requirements 58 23. Reopenings for Cause 59 24. Section 502(b)(10) Changes 60 25. Severability Clause 60 26. Significant Permit Modifications 60 27. Special Provisions Concerning the Acid Rain Program 60 28. Transfer or Assignment of Ownership 60 29. Volatile Organic Compounds 61 30. Wood Stoves and Wood burning Appliances 61 APPENDIX A Inspection Information 1 APPENDIX B Reporting Requirements and Definitions 1 Monitoring and Permit Deviation Report - Part 1 6 Monitoring and Permit Deviation Report - Part II 8 APPENDIX C Required Format for Annual Compliance Certification Report (ver 2/20/07) 1 APPENDIX D Notification Addresses 1 APPENDIX E Permit Acronyms 1 APPENDIX F Permit Modifications 1 APPENDIX G 1 Compliance Assurance Monitoring Plan - Engines 1 Compliance Assurance Monitoring Plan - Dehydrators 4 APPENDIX H Applicability Reports 1 Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 1 SECTION I - General Activities and Summary 1. Permitted Activities 1.1 The Enterprise Compressor Station is classified as a natural gas compressor station on a gas transmission line as set forth under Standard Industrial Classification Code 4922. The facility uses six (6) gas-fired internal combustion engines to drive compressors to boost the inlet gas pressure from about 80 PSIG to about 1050 PSIG to facilitate movement of the gas in the pipeline. All six (6) engines have individual stacks to vent the products of combustion. The station also includes two (2) triethylene glycol (TEG) dehydrator units which contacts "lean" triethylene glycol with the inlet natural gas stream to remove moisture. The "rich" glycol mixture is regenerated in a still for reuse in the process. The still vent exhaust stream is sent to an enclosed flare where it is combusted. The TEG dehydration systems operate with a flash tank. The flash tank emissions are routed back into the process. A condensate product is generated when the inlet gas is routed through the inlet scrubber, the gas is stabilized, and transferred to eight (8) 300 barrel stabilized condensate storage tanks. A loading system is provided for moving the liquid condensate material from the tanks into a truck for transport offsite. The condensate tanks and loadout are controlled with an enclosed combustor. The plant is located one (1) mile north of US Highway 76 on the Gutterson Road between the towns of Keenesburg and Roggen, Weld County, Colorado. The area in which the plant 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 ILA.16. There are no affected states within 50 miles of the facility. Rocky Mountain National Park is a Federal Class I designated areas within 100 kilometers of the facility. 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 This Operating Permit incorporates the applicable requirements contained in the underlying construction permits, and does not affect those applicable requirements, except as modified during review of the application or as modified subsequent to permit issuance using the modification procedures found in Regulation No. 3, Part C. These Part C procedures meet all applicable substantive New Source Review requirements 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 Operating Permit incorporates the applicable requirements (except as noted in Section II) from the following Colorado Construction Permit(s): 97WE0553 00WE0470 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit/I 95OPWE103 Page 2 1.4 All conditions in this permit are enforceable by the US Environmental Protection Agency, Colorado Air Pollution Control Division (hereinafter Division) and its agents, and citizens unless otherwise specified. State-only enforceable conditions are: Section II, Condition 2.8, 3.5.1, 6.3, and 7.4 and Section IV, Conditions 3.d, 3.g (last paragraph), 14 and 18 (as noted). 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. 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 compliance demonstrations or periodic monitoring required by this permit All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit (including monitoring and record keeping), and shall be subject to any shield afforded by this permit The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The permittee shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 3 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 requirements 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 NOx and CO from the temporary replacement engine must be less than or equal to the potential annual emissions of NOx and CO from the original grandfathered or permit exempt engine or for the engine that is not subject to emission limits, as determined by applying appropriate emission factors (e.g. AP-42 or manufacturer's emission factors) 2.1.2 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 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit # 95OPWE103 Page 4 and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The permittee shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. Nothing in this AOS shall preclude the Division from taking an action, based on any permanent engine replacement(s), for circumvention of any state or federal PSD/NANSR requirement. Additionally, in the event that any permanent engine replacement(s) constitute(s) a circumvention of applicable PSD/NANSR requirements, nothing in this AOS shall excuse the permittee from complying with PSD/NANSR and applicable permitting requirements. 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. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWEI03 Page 5 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. 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 PMio attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOx and SO2, as precursors to PMio, 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. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 6 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. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVII E—State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: 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 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 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 7 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, (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 Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 8 Table 1 Internal Combustion Engine Information For AOS Emission Replacement Engine Periodic Monitoring Subject to Point CAM? C-238 Caterpillar Model G361251 Natural Gas Fired Internal Portable Monitoring Yes Combustion Reciprocating Engine, 4-cycle, Standard Lean Quarterly Burn;powering a natural gas compressor C-235 Caterpillar Model G361251 Natural Gas Fired Internal Portable Monitoring Yes Combustion Reciprocating Engine, 4-cycle, Standard Lean Quarterly Burn;powering a natural gas compressor C-236 Caterpillar Model G361251 Natural Gas Fired Internal Portable Monitoring Yes Combustion Reciprocating Engine, 4-cycle, Standard Lean Quarterly Burn;powering a natural gas compressor P018 Caterpillar Model G3612S1 Natural Gas Fired Internal Portable Monitoring Yes Combustion Reciprocating Engine, 4-cycle, Standard Lean Quarterly Burn;powering a natural gas compressor C-237 Caterpillar Model G3616 Natural Gas Fired Internal Portable Monitoring Yes Combustion Reciprocating Engine, 4-cycle, Standard Lean Quarterly Burn;powering a natural gas compressor C-239 Caterpillar Model G3616 Natural Gas Fired Internal Portable Monitoring Yes Combustion Reciprocating Engine, 4-cycle, Standard Lean Quarterly Burn;powering a natural gas compressor 3. Prevention of Significant Deterioration/New Source Review (PSD/NSR) 3.1 This facility is located in an area designated as attainment for all pollutants except ozone. Based on the information provided in the Title V application, this facility is categorized as a NANSR major stationary source (Potential to Emit of VOC or 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 (use 100 TPY if a listed source category)) 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 the purposes of determining the applicability of the PSD regulations. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 9 4. Accidental Release 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). 5. 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: C235, C236, C238, P018, C-237, and C-239— Caterpillar Engines D-2 and D-3 — Glycol Dehydrator Regeneration Units Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit ft 95OPWE103 Page 10 6. Summary of Emission Units 6.1 The emissions units regulated by this permit are the following: AIRS Plant Pollution Stack Description Construction Number Identifier P Size Control Permit Device Caterpillar Model G3612S1 Natural Gas Fired Internal 053 C-238 Combustion Reciprocating Engine,4-cycle,Standard 3550 HP Oxidation Lean Burn, Serial No. I YG00047;powering a natural Catalyst gas compressor Caterpillar Model G3612SI Natural Gas Fired Internal 055 C-235 Combustion Reciprocating Engine,4-cycle, Standard 3550 HP Oxidation Lean Burn, Serial No. 1YG00028;powering a natural Catalyst gas compressor 97WE0553 Caterpillar Model G361251 Natural Gas Fired Internal 056 C-236 Combustion Reciprocating Engine,4-cycle,Standard 3550 HP Oxidation Lean Burn, Serial No. I YG00027;powering a natural Catalyst gas compressor 062 P012 Compressor Station Fugitive Emissions N/A Uncontrolled 066 P016 Stabilized Condensate truck loadout N/A Combustor 063 P013 Eight(8)vertical stablized condensate tanks 300 bbl each Combustor N/A Triethylene glycol dehydrator equipped with an electric glycol pump and a flash tank. Flash gas is 068 D2 recycled to the inlet via a VRU. Equipped with a 110 MMscfd Flare 00WE0470 condenser routed to an enclosed flare for the control of VOC emissions.35 gpm recirculation rate Caterpillar Model G3612 Natural Gas Fired Internal 070 P018 Combustion Reciprocating Engine.4-cycle, Standard 3550 HP Oxidation Lean Burn,Serial No. BKE00356; powering a natural Catalyst gas compressor Caterpillar Model G3616 Natural Gas Fired Internal 071 C-237 Combustion Reciprocating Engine,4-cycle, Standard 4735 HP Oxidation Lean Burn, Serial No.:TBD; powering a natural gas Catalyst compressor Caterpillar Model G3616 Natural Gas Fired Internal 072 C-239 Combustion Reciprocating Engine,4-cycle,Standard 4735 HP Oxidation N/A Lean Burn, Serial No:TBD;powering a natural gas Catalyst compressor Triethylene glycol dehydrator equipped with an electric glycol pump and a flash tank. Flash gas is 073 D3 recycled to the inlet via a VRU. Equipped with a 60 MMscfd Flare condenser routed to an enclosed flare for the control of VOC emissions, 15 gpm recirculation rate 074 Comb-1 Flare used to control still vent emission from both N/A N/A dehydrators Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit ft 95OPWE103 Page 11 SECTION II - Specific Permit Terms 1. C-238 - Caterpillar G3612 3550 HP Compressor Engine with oxidation catalyst C-235 - Caterpillar G3612 3550 HP Compressor Engine with oxidation catalyst C-236 - Caterpillar G3612 3550 HP Compressor Engine with oxidation catalyst P018 - Caterpillar G3612 3550 HP Compressor Engine with oxidation catalyst NOTE: The following terms and conditions apply to each engine individually Permit Monitoring Condition Parameter Number Compliance Limits Emission Factor Method Interval NOx 1.1 24.00 tons/year 0.228 Ib/MMBtu Recordkeeping& Monthly Calculation CO 27.42 tons/year 0.261 lb/MMBtu 12 month rolling total VOC 1.2 24.00 tons/year 0.228 lb/MMBtu Portable Monitoring 1.1 2 �r - llit ,n:33',• 2'r' Flue Gas Analyzer Quarterly Natural Gas Consumption 1.3 185.01 million �ti: Plant Fuel Meter Monthly scf/year ; .-a X't '" "•: 12 month rolling total Btu Heat Content 14 '_ ASTM or other Semi-Annually Division Approved 11 Method Operating Hours 1 5 Recordkeeping Monthly Opacity 1.6 Except as provided below,not to exceed 20% Fuel Restriction Only Natural Gas is Used During startup,not to exceed 30% Oxidation Catalyst 1.7 r • ° _ ., t Recordkeeping Monthly NESHAP ZZZZ 1.8 P018 only: Reduce CO by 93%or Limit See Condition 1.8 HCHO emission to 14 ppmvd at 15%Oz NESHAP Subpart A 19 See Condition 1.9 Compliance Assurance 1 10 See Condition 9 Monitoring 1.1 Emissions of Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from each engine shall not exceed the limitations stated in the table above (Colorado Construction Permit 97WE0553). Compliance with the emission limitations shall be monitored as follows: Except as provided below, the emission factors listed above have been approved by the Division and shall be used to calculate emissions from these engines. 1.1.1 Monthly emissions shall be calculated by the end of the subsequent month using the above emission factor, the natural gas consumption (as required by Condition 1.3) and the Btu content of the natural gas (as required by Condition 1.4) in the following equation: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit/4 95OPWE103 Page 12 tons/mo=JEF(lbs/MMBtu)x natural gas consumption(MMscf/year)x heat content of fuel(MMBtu/MMscfll 2000 lbs/ton Monthly emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month a new twelve month total shall he calculated using the previous twelve months data. If the results of the portable analyzer testing conducted under the provisions of Condition 1.1.2 show that either the NOx or CO emission rates/factors are greater than the emission rates/factors 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. 1.1.2 Portable monitoring shall be conducted quarterly as required by Condition 8. 1.2 Volatile Organic Compounds (VOC) emissions from each engine shall not exceed the annual emission limitation stated in the tables above (Colorado Construction Permit 97WE0553). Monthly emissions shall be calculated by the end of the subsequent month using the VOC emission factor in the table above, the monthly natural gas consumption (as required by Condition 1.3) and the Btu content of the natural gas (as required by Condition 1.4) in the following equation: tons/mo=JEF(lbs/MMBtu)x natural gas consumption(MMscf/year)x heat content of fuel(MMBtu/MMscf)J 2000 lbs/ton Monthly emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month a new twelve month total shall be calculated using the previous twelve months data. 1.3 Natural gas consumption from each engine shall not exceed the limitation in the table above (Colorado Construction Permit 97WE0553). 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 Horsepower)individual engine Fuel Consumption= x Total Engine Fuel Use E(Design Heat Rate x Hours of Operation x Site Rated Horsepower)eaeh 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. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 13 1.4 The Btu content of the natural gas used to fuel these engines shall be verified semi-annually, or once every six months, using 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 higher heating value of the fuel. Calculation of monthly emissions shall be made using the heat content derived from the most recent required analysis. 1.5 Hours of operation of each engine shall be recorded for each calendar month. Records shall be made available for Division review upon request. 1.6 Visible emissions shall not exceed 20% opacity (Colorado Construction Permit 97WE0553 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 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. 1.7 These engines shall be equipped with oxidation catalyst (Colorado Regulation No. 7, XVI.B.2). Parameters associated with the catalyst shall be monitored as follows for all engines except P018: 1.7.1 The pressure drop across the catalyst shall be monitored and recorded monthly. The pressure drop shall not exceed 2 inches of water column from the baseline value established by the source when the engine is operating at maximum achievable load. This baseline pressure drop shall be established by the source during each initial compliance and portable analyzer test, and as noted below. If the pressure is outside this range then the appropriate maintenance shall be performed to bring the pressure back into range. In lieu of maintenance the source may choose to perform a portable analyzer test of the engine to establish a new pressure drop value. If the test demonstrates that the engine is in compliance with its emission limits, the pressure drop value at which the engine is tested shall become the new baseline. The catalyst will be cleaned, reconditioned and replaced per the manufacturer's recommended schedule and a copy of maintenance reports shall be kept for Division review upon request. For new, cleaned or reconditioned catalyst: the new pressure drop baseline must be established by the operator within the first 7 days of engine/catalyst operation and re-established during the next regularly scheduled emission test. 1.7.2 The catalyst inlet temperature shall be monitored and recorded daily and kept between 450°F and 1350°F. 1.7.3 When portable monitoring is scheduled, the above parameters in Conditions 1.7.2 and 1.7.3 shall be recorded during the portable monitoring event. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit # 95OPWE103 Page 14 1.7.4 All control equipment required by Condition 1.7 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. Manufacturer specifications or equivalent shall be kept on file. 1.8 P018 only: This engine is 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: (Colorado Regulation No. 8, Part E, Subpart III.FFFF) 1.8.1 The engine shall meet either of the following emissions limitations at all times except during startup: 1.8.1.1 Carbon Monoxide (CO) shall be reduced by 93 percent or more (Table 2a of Subpart ZZZZ, Item 2.a), or 1.8.1.2 Formaldehyde emission shall be limited to 14 ppmvd at 15% O2 (Table 2a of Subpart ZZZZ, Item 2.b). 1.8.2 For the oxidizing catalytic reduction device installed to meet the emissions limitations in Condition 1.8.1, the following operating requirements shall apply (Table 2b of Subpart ZZZZ, Item 1): 1.8.2.1 Maintain the 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 1.8.2.2 Maintain the temperature of the engine's exhaust so the catalyst inlet temperature is greater than or equal to 450°F and less than or equal to 1350°F. Performance Tests 1.8.3 Performance tests must be conducted using the appropriate ASTM methods or equivalent, if approved in advance by the Division, as described in Table 4 to Subpart ZZZZ, according to the following protocol: If complying with the requirement to reduce CO emissions: (Table 4, Item 1) 1.8.3.1 Measure O2 at the inlet and outlet of the control device using a portable CO and O2 analyzer. a. Measurements to determine O2 concentration must be made at the same time as the measurements for CO concentration. 1.8.3.2 Measure CO at the inlet and the outlet of the control device using a portable CO and O2 analyzer. a. CO concentration must be at 15 percent O2, dry basis. Operating Permit Number: 95OPWE103 FIRST ISSUED: May I, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWEI03 Page 15 If complying with the requirement to limit formaldehyde concentration: (Table 4, Item 3) 1.8.3.3 Select the sampling port location and the number of traverse points and measure the O2 concentration, moisture content, and formaldehyde concentration. a. The sampling site must be located at the outlet of the control device. b. Measurements to determine O2 concentration and moisture content must be made at the same time and location as the measurements for the formaldehyde concentration. c. Formaldehyde concentration must be at 15 percent O2, dry basis. Results of this test consist of the average of three 1-hour or longer runs. Demonstrating Compliance 1.8.4 Demonstrate continuous compliance with the limitations in Condition 1.8.1 using the following methods described in Table 6 of Subpart ZZZZ. (§63.6640(a)): 1.8.4.1 Conduct performance tests according to Condition 1.8.3 semiannually to demonstrate that the required CO percent reduction or required formaldehyde concentration is met; (Table 6 of Subpart ZZZZ, Item 1.a.i or 8.a.i) and 1.8.4.2 Collect the catalyst inlet temperature data according to §63.6625(b); (Table 6 of Subpart ZZZZ, Item 1.a.ii or 8.a.ii) and 1.8.4.3 Reduce these data to 4-hour rolling averages; (Table 6 of Subpart ZZZZ, Item 1.a.iii or 8.a.iii) and 1.8.4.4 Maintain the 4-hour rolling averages within the operating limitations for the catalyst inlet temperature; (Table 6 of Subpart ZZZZ, Item 1.a.iv or 8.a.iv) and 1.8.4.5 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 1.a.v or 8.a.v) 1.8.4.6 After the facility has demonstrated compliance for two consecutive tests, the frequency of subsequent performance tests may be reduced to annually. If the results of any subsequent annual performance test indicate the stationary RICE is not in compliance with the CO or formaldehyde emission limitation semiannual performance tests must resume. (Table 6 of Subpart ZZZZ, footnote a) Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit/4 95OPWE103 Page 16 Notification and Reporting Requirements 1.8.5 Submit compliance reports semiannually according to the requirements in §63.6650(b). The report must contain the following: 1.8.5.1 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 continuous monitoring system 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) 1.8.5.2 If there is a deviation from any emission limitation or operating limitation during the reporting period, include the information in §63.6650(d). If there were • periods during which the continuous monitoring system was out-of-control, as specified in §63.8(c)(7), include the information in §63.6650(e). (Table 7 of Subpart ZZZZ, Item I.b) 1.8.5.3 If there was a malfunction during the reporting period, include the information in §63.6650(c)(4). (Table 7, Item l.c) 1.8.6 Submit a Notification of Compliance Status according to §63.6645(h). 1.8.7 Submit all notifications that are applicable in §§63.7(b) and (c), 63.8(e), (f)(4) and (I)(6), 63.9(b) through (e), (g) and (h). (§63.6645(a)) 1.8.8 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 1.8.9 Compliance with the emission limitations and operating limitations in this subpart must be achieved at all times. (§63.6605(a)) 1.8.10 At all times the engine 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)) 1.8.11 Comply with the monitoring, installation, collection, and maintenance requirements in §63.6625. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit # 95OPWE103 Page 17 1.8.12 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)) 1.9 These engine are subject to the requirements in 40 CFR Part 63 Subpart A "General Provisions", as adopted by reference in Colorado Regulation No. 8, Part E, Section I as specified in 40 CFR Part 63 Subpart ZZZZ § 63.6665. These requirements include, but are not limited to the following 1.9.1 Prohibited activities and circumvention in § 63.4. 1.9.2 Performance testing in §63.7. 1.9.3 Monitoring in §63.8. 1.9.4 Notification in §63.9. 1.9.5 Recordkeeping and reporting in §63.10. 1.10 The source shall follow the Compliance Assurance Monitoring (CAM) requirements for the engines as outlined in Section II, Condition 9 of this permit. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit # 95OPWE103 Page 18 2. C-237 and C-239 -Caterpillar G3616 4735 HP Compressor Engines with oxidation catalyst NOTE: The following terms and conditions apply to each engine individuallx Permit Monitoring Condition Compliance Parameter Number Limits Emission Factor Method Interval NOx 2.1 32.01 tons/year 0.206 Ib/MMBtu Recordkceping& Monthly Calculation CO 36.58 tons/year 0.236 lb/MMBtu 12 month rolling total VOC 2.2 32.01 tons/year 0.206 lb/MMBtu Portable Monitoring 2.1.2 =-y. `s ' ;. Flue Gas Analyzer Quarterly .-.xU.S. 5r• Y Q Y Natural Gas Consumption 2.3 273.08 n —;`-`t- 3,-, Plant Fuel Meter Monthly MMscf/year >`..-4 fix' 12 month rolling total Btu Heat Content 2.4 tft ASTM or other Semi-Annually t. . tak Division Approved z r .6'.4c itAf-7-7717E-a_ '-.' Method Operating Hours 2 5 a � - ' Recordkeeping Monthl" P g Y Opacity 2.6 Except as provided below, not to Fuel Restriction Only Natural exceed 20% Gas is Used During startup,not to exceed 30% Oxidation Catalyst 2 7 v,-. Y �' .� � ,� See Condition 2.7 [Federal-Only]NSPS 2.8 NOx- 1.0 g/hp-hr or 82 ppmvd* Performance Tests Every 8,760 Subpart JJJJ CO-2.0 g/hp-hr or 270 ppmvd* hours of VOC-0.7 g/hp-hr or 60 ppmvd* operation or 3 years NESHAP Subpart ZZZZ 2.9 Reduce CO by 93%or Limit HCIIO Sec Condition 2.9 emission to 14 ppmvd at 15%02 IFederal-Onlyl NSPS 2 10 : r See Condition 2.10 Subpart A v. NESHAP Subpart A 2.11 w �`.`K.,. n sr x" _ -. See Condition 2.11 Construction Requirements 2.12 -.W--.794774',7 ywe See Condition 2.12 Compliance Assurance 2.13 ""*-4-Wrralex7., See Condition 9 Monitoring ;t' 2.1 Emissions of Nitrogen Oxides (NOx) and Carbon Monoxide (CO) from each engine shall not exceed the limitations stated in the table above. Compliance with the emission limitations shall be monitored as follows: Except as provided below, the emission factors listed above have been approved by the Division and shall be used to calculate emissions from these engines. 2.1.1 Monthly emissions shall be calculated by the end of the subsequent month using the above emission factor, the natural gas consumption (as required by Condition 2.3) and Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 19 the Btu content of the natural gas (as required by Condition 2.4) in the following equation: tons/mo=fEF(lbs/MMBtu)x natural gas consumption(MMscf/year)x heat content of fuel(MMBtu/MMscf)1 2000 lbs/ton Monthly emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month a new twelve month total shall be calculated using the previous twelve months data. If the results of the portable analyzer testing conducted under the provisions of Condition 2.1.2 show that either the NOx or CO emission rates/factors are greater than the emission rates/factors listed above, and in the absence of subsequent testing results to the contrary (as approved by the Division), the permittee shall apply for a modification to this permit to reflect, at a minimum, the higher emission rates/factors within 60 days of the completion of the test. 2.1.2 Portable monitoring shall be conducted quarterly as required by Condition 8. 2.2 Volatile Organic Compounds (VOC) emissions from each engine shall not exceed the annual emission limitation stated in the tables above. Monthly emissions shall be calculated by the end of the subsequent month using the VOC emission factor in the table above, the monthly natural gas consumption (as required by Condition 2.3), and the Btu content of the natural gas (as required by Condition 2.4) in the following equation: tons/mo=JEF(lbs/MMBtu)x natural gas consumption(MMscf/vear)x heat content of fuel(MMBtu/MMscfll 2000 lbs/ton Monthly emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month a new twelve month total shall be calculated using the previous twelve months data. 2.3 Natural gas consumption from each engine shall not exceed the limitation in the table above. 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 2.5. Allocation of natural gas to each engine will be calculated using the following calculation: Fuel Consumption= (Design Heat Rate x Hours of Operation x Site Rated Horsepower) d.iduai en6inC x Total Engine Fuel Use E(Design Heat Rate x Hours of Operation x Site Rated Horsepower)CCCh 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. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit # 95OPWE103 Page 20 2.4 The Btu content of the natural gas used to fuel these engines shall be verified semi-annually, or once every six months, using 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 higher heating value of the fuel. Calculation of monthly emissions shall be made using the heat content derived from the most recent required analysis. 2.5 Hours of operation of each engine shall be recorded for each calendar month. Records shall be made available for Division review upon request. 2.6 Visible emissions shall not exceed 20% opacity (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 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. 2.7 This engine shall be equipped with oxidation catalyst (Colorado Regulation No. 7, XVI.B.2). All control equipment required by Condition 2.7 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. Manufacturer specifications or equivalent shall be kept on file. 2.8 [Federal-Only] These engines are subject to the requirements in 40 CFR Part 60 Subpart JJJJ, "Standards of Performance for Stationary Spark Ignition Internal Combustion Engines", including but not limited to the following requirements: Note that as of the date of revised permit issuance [DATE], the requirements in 40 CFR Part 60 Subpart JJJJ have not been adopted into Colorado Regulation No. 6, Part A 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. 2.8.1 These engines must comply with the specific emission limitations shown in the table below: (Table 1 of Subpart JJJJ) Engine Type and Fuel: Non-Emergency SI Natural Gas and Non-Emergency SI Lean Burn LPG (except lean burn 500≥hp< 1,350) Maximum Engine Power: > 500 hp Manufacturer Date: July 1,2010 Emission Standards(g/hp-hr) Emission Standards(ppmvd at 15%O2) NOx CO VOC NOx CO VOC 1.0 2.0 0.7 82 270 60 2.8.1.1 For engines manufactured prior to January 1, 2011 that were certified to the certification emission standards in 40 CFR part 1048 applicable to engines that are not severe duty engines, if such stationary SI ICE was certified to a carbon monoxide (CO) standard above the standard in Condition 2.8.1 above, then the Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 21 source may meet the CO certification (not field testing) standard for which the engine was certified. (§ 60.4233(e)) Compliance Requirements 2.8.2 This facility shall keep a maintenance plan and records of conducted maintenance and, to the extent practicable, maintain and operate the engine in a manner consistent with good air pollution control practice for minimizing emissions. In addition, this facility shall conduct an initial performance test and conduct subsequent performance testing every 8,760 hours or 3 years, whichever comes first, thereafter to demonstrate compliance. (§ 60.4243(b)(2)(ii)) Notification, Reporting, and Recordkeeping Requirements 2.8.3 The facility must keep records of the following information: 2.8.3.1 All notifications submitted to comply with this subpart and all documentation supporting any notification. (§ 60.4245(a)(1)) 2.8.3.2 Maintenance conducted on the engine. (§ 60.4245(a)(2)) 2.8.3.3 If the engine is not a certified engine or is a certified engine operating in a non-certified manner and subject to §60.4243(a)(2), documentation that the engine meets the emission standards. (§ 60.4245(a)(4)) 2.8.4 Engines that not been certified by an engine manufacturer to meet the emission standards in §60.4231 must submit an initial notification as required in §60.7(a)(1). The notification must include the information in paragraphs (c)(1) through (5) of this section. (§ 60.4245(c)) 2.8.5 The source must submit a copy of each performance test as conducted in §60.4244 within 60 days after the test has been completed. (§ 60.4245(d)) 2.9 These engine 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: (Colorado Regulation No. 8, Part E, Subpart III.FFFF) 2.9.1 These engines must comply with the applicable limitations upon startup (§63.6595(a)(1)) 2.9.2 The engines shall meet either of the following emissions limitations at all times except during startup: 2.9.2.1 Carbon Monoxide (CO) shall be reduced by 93 percent or more (Table 2a of Subpart ZZZZ, Item 2.a), or 2.9.2.2 Formaldehyde emission shall be limited to 14 ppmvd at 15% O2 (Table 2a of Subpart ZZZZ, Item 2.b). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit ft 95OPWE103 Page 22 2.9.3 For each oxidizing catalytic reduction device installed to meet the emissions limitations in Condition 2.9.2, the following operating requirements shall apply (Table 2b of Subpart ZZZZ, Item 1): 2.9.3.1 Maintain the 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 2.9.3.2 Maintain the temperature of the engine's exhaust so the catalyst inlet temperature is greater than or equal to 450°F and less than or equal to 1350°F. Performance Tests 2.9.4 Initial performance tests must be conducted within 180 days after the compliance date specified in Condition 2.9.1 according to the provisions of§63.7(a)(2). (§63.6610(a)) 2.9.4.1 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 §63.6610(d)(1) through (4). (§63.6610(d)) 2.9.4.2 Catalyst pressure drop and catalyst inlet temperature shall be recorded during the initial performance test. 2.9.5 Performance tests must be conducted using the appropriate ASTM methods or equivalent, if approved in advance by the Division, as described in Table 4 to Subpart ZZZZ, according to the following protocol: If complying with the requirement to reduce CO emissions: (Table 4, Item I) 2.9.5.1 Measure 02 at the inlet and outlet of the control device using a portable CO and 02 analyzer. a. Measurements to determine 02 concentration must be made at the same time as the measurements for CO concentration. 2.9.5.2 Measure CO at the inlet and the outlet of the control device using a portable CO and 02 analyzer. a. CO concentration must be at 15 percent 02, dry basis. If complying with the requirement to limit formaldehyde concentration: (Table 4, Item 3) 2.9.5.3 Select the sampling port location and the number of traverse points and measure the 02 concentration, moisture content, and formaldehyde concentration. a. The sampling site must be located at the outlet of the control device. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit # 95OPWE103 Page 23 b. Measurements to determine O2 concentration and moisture content must be made at the same time and location as the measurements for the formaldehyde concentration. c. Formaldehyde concentration must be at 15 percent O2, dry basis. Results of this test consist of the average of three 1-hour or longer runs. Demonstrating Compliance 2.9.6 Initial compliance with the requirement to limit formaldehyde concentration or reduce CO emissions in Condition 2.9.2 is demonstrated by achieving the following: 2.9.6.1 The average reduction of emissions of CO determined from the initial performance test achieves the required CO percent reduction or the average formaldehyde concentration, corrected to 15% O2, dry basis, from the three test runs is less than or equal to formaldehyde emission limitation (Table 5 of Subpart ZZZZ, Item 1.a.i or 10.a.i) and 2.9.6.2 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 1.a.ii or 10.a.ii) and 2.9.6.3 The catalyst pressure drop and catalyst inlet temperature have been recorded during the initial performance test. (Table 5 of Subpart ZZZZ, Item 1.a.iii or 10.a.iii) 2.9.7 Demonstrate continuous compliance with the limitations in Condition 2.9.2 using the following methods described in Table 6 of Subpart ZZZZ. (§63.6640(a)): 2.9.7.1 Conduct performance tests according to Condition 2.9.5 semiannually to demonstrate that the required CO percent reduction or required formaldehyde concentration is met; (Table 6 of Subpart ZZZZ, Item 1.a.i or 8.a.i) and 2.9.7.2 Collect the catalyst inlet temperature data according to §63.6625(b); (Table 6 of Subpart ZZZZ, Item 1.a.ii or 8.a.ii) and 2.9.7.3 Reduce these data to 4-hour rolling averages; (Table 6 of Subpart ZZZZ, Item 1.a.iii or 8.a.iii) and 2.9.7.4 Maintain the 4-hour rolling averages within the operating limitations for the catalyst inlet temperature; (Table 6 of Subpart ZZZZ, Item 1.a.iv or 8.a.iv) and 2.9.7.5 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 1.a.v or 8.a.v) 2.9.7.6 After the facility has demonstrated compliance for two consecutive tests, the frequency of subsequent performance tests may be reduced to annually. If the Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit/4 95OPWE103 Page 24 results of any subsequent annual performance test indicate the stationary RICE is not in compliance with the CO or formaldehyde emission limitation semiannual performance tests must resume. (Table 6 of Subpart ZZZZ, footnote a) Notification and Reporting Requirements 2.9.8 Submit compliance reports semiannually according to the requirements in §63.6650(b). The report must contain the following: 2.9.8.1 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 continuous monitoring system 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) 2.9.8.2 If there is a deviation from any emission limitation or operating limitation during the reporting period, include the information in §63.6650(d). If there were periods during which the continuous monitoring system 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) 2.9.8.3 If there was a malfunction during the reporting period, include the information in §63.6650(c)(4). (Table 7, Item l.c) 2.9.9 Submit a Notification of Compliance Status according to §63.6645(h). 2.9.10 Submit all notifications that are applicable in §§63.7(b) and (c), 63.8(e), (f)(4) and (f)(6), 63.9(b) through (e), (g) and (h). (§63.6645(a)) 2.9.11 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 2.9.12 Compliance with the emission limitations and operating limitations in this subpart must be achieved at all times. (§63.6605(a)) 2.9.13 At all times the engine 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)) Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 25 2.9.14 Comply with the monitoring, installation, collection, and maintenance requirements in §63.6625. 2.9.15 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)) 2.10 [Federal-Only] These engines are subject to the requirements in 40 CFR Part 60 Subpart A "General Provisions". These requirements include, but are not limited to the following 2.10.1 No article, machine, equipment or process shall be used to conceal an emission which would otherwise constitute a violation of an applicable standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based on the concentration of a pollutant in the gasses discharged to the atmosphere. (40 CFR 60 Subpart A § 60.12, as adopted by reference in Colorado Regulation No. 6, Part A). 2.10.2 Performance tests shall be conducted in accordance with the requirements in 40 CFR Part 60 Subpart A § 60.8. 2.11 These engine are subject to the requirements in 40 CFR Part 63 Subpart A "General Provisions", as adopted by reference in Colorado Regulation No. 8, Part E, Section I as specified in 40 CFR Part 63 Subpart ZZZZ § 63.6665. These requirements include, but are not limited to the following: 2.11.1 Prohibited activities and circumvention in § 63.4. 2.11.2 Performance testing in §63.7. 2.11.3 Monitoring in §63.8. 2.11.4 Notification in §63.9. 2.11.5 Recordkeeping and reporting in §63.10. 2.12 The following requirements apply to the construction of engines C-237 and C-239: 2.12.1 The source must submit a Notice of Startup (NOS) form to the Division by no later than fifteen (15) days after the commencement of the operation of this engine. The NOS form may be downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. (Colorado Regulation No. 3, Part B, Section III.G.1). The NOS form shall include model and serial number of the engine installed. 2.12.2 The permit to construct this engine shall expire if the facility: (i) does not commence construction or operation of this source within 18 months after either, the date of issuance Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit # 95OPWE103 Page 26 of the this permit, DATE, or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Colorado Regulation No. 3, Part B, III.F.4.b. (Colorado Regulation No. 3, Part B, Section III.F.4.) 2.12.3 Initial performance tests shall be conducted within 180 days of the commencement of operation of this engine, to demonstrate compliance with the NOx and CO emission limitations. The performance test shall be conducted using the appropriate EPA Test Methods. A stack testing protocol shall be submitted for Division approval at least thirty (30) calendar days prior to performance of the test required under this condition. No stack test required herein shall be performed without prior written approval of the protocol by the Division. The Division reserves the right to witness the test. In order to facilitate the Division's ability to make plans to witness the test, notice of the date (s) for the stack test shall be submitted to the Division at least thirty (30) calendar days prior to the test. The Division may for good cause shown, waive this thirty (30) day notice requirement. In instances when a scheduling conflict is presented, the Division shall immediately contact the permittee in order to explore the possibility of making modifications to the stack test schedule. The required number of copies of the compliance test results shall he submitted to the Division within forty-five (45) calendar days of the completion of the test unless a longer period is approved by the Division. 2.13 The source shall follow the Compliance Assurance Monitoring (CAM) requirements for the engines as outlined in Section II, Condition 9 of this permit. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 27 3. D2 and D3 - Triethylene Glycol Regeneration Units NOTE: The following terms and conditions apply to each dehydrator individually, unless otherwise noted I Permit Compliance Monitoring Condition Emission Parameter Number Compliance Limits Factor Method Interval V0C 3.1 D2: 11.95 tons/year Based on Input Parametric Monthly D3: 5.06 tons/year to GLYCaIe Model HAPs Both D2&D3 together: Individual: 8.0 tons/year Total:20.0 tons/year Extended Gas 3.1.3 ,� �s.#s EPA Reference Annually Analysiss. =, Methods "4 --T ry,^ r. 2'Pht z Hours of Operation 3.2 - ' s.= Recordkeeping Monthly Gas Processed 3.3 D2: 40,150 MMsct/year "- : Flow Meter Continuous D3: 21,900 MMscf/year ' x Glycol Flow Rate 3.4 D2: 35 gallons/min E ri Recordkeeping Monthly D3: 15 gallons/min ' * f' Kaa Control System 3.5 95%reduction °eic ; See Condition 3.5 m rt, Compliance 3.6 `'3"S rte.,�., "' e See Condition 9 Assurance -'£z '' "',- ti Monitoring �'. c�; �r`,a _. MACT Subpart I-Ill 3.7 mot -�J .. s.^�- See Condition 3.7 Area Source .37z--r-77,7"---1,--e.3.. �-s 4-- Requirements =- =CI '� MACT Subpart A 3.8 See Condition 3.8 Construction 3.9 See Condition 3.9 Requirements . 3.1 Emissions of air pollutants from each dehydrator shall not exceed the limitations listed in the table 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 permittee and made available to the Division for inspection upon request. (Construction Permit 00WE0470, as modified in accordance with Section I, Condition 1.4) 3.1.1 VOC and HAP emissions shall be calculated monthly using the Gas Research Institute's GLYCalc Model, Version 4.0 or higher. Monitoring of the following parameters to be entered into the GLYCaIc Model shall be monitored weekly: condenser outlet temperature, flash tank temperature and pressure, and inlet (wet) gas pressure and temperature. Monitoring of the following parameters to be entered into the GLYCalc Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit # 95OPWE103 Page 28 Model shall be monitored daily: triethylene glycol circulation rate,. The condenser outlet temperature recorded shall be the highest temperature reading recorded on the strip chart for any calendar day (midnight to midnight). Values of parameters shall be representative of the unit's operation during the month. 3.1.2 Flash gas emissions shall be vented back into the process at all times, resulting in zero emissions from the flash tank. 3.1.3 Samples of inlet gas shall be collected and analyzed (extended gas analysis) annually to determine C1 to C6, 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. The BTEX values listed in the table below referred to in the language shall be set at these maximum values used in the GLYCalc run used to set the permit limits. Component Value Criteria Benzene Content of Gas 401 ppm At or Below Toluene Content of Gas 429 ppm At or Below Ethyl Benzene Content of Gas 14 ppm At or Below Xylene Content of Gas 126 ppm At or Below 3.2 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. 3.3 Processing of natural gas through each dehydrator shall not exceed the limitations listed in the table above (Construction Permit 00WE0470, as modified in accordance with Section I, Condition 1.3) The gas throughput for the dehydration unit shall be recorded monthly using the existing flow meter(s). A twelve (12) month rolling total shall be maintained to determine compliance with annual processing limitation. By the end of each new calendar month a total shall be calculated for the previous 12 calendar months, and compliance determined. Records of the calculations and compliance determinations shall be maintained. The calculation and compliance determination records shall be made available to the Division for review upon request. Operating Permit Number: 95OPWE103 FIRST ISSUED: May I, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 29 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 model runs required by Condition 3.1. 3.4 Lean glycol flow rate shall not exceed the limitations in the table above (a pump stroke correlation can be used to show compliance). Monthly records of the actual pumping rate shall be maintained by the permittee and made available to the Division for inspection upon request. (Construction Permit 00WE0470) 3.5 This emission unit is designed with a control system that shall be capable of reducing the emissions of volatile organic compounds by at least 95%. (Construction Permit 00WE0470) 3.5.1 [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. Fluctuations in emissions that occur when the separator dumps into the tank are reasonably foreseeable. (Colorado Regulation No. 7, Section XVII.B.1.a) 3.6 The source shall follow the Compliance Assurance Monitoring (CAM) requirements for the dehydrators as outlined in Section II, Condition 9 of this permit. 3.7 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: 3.7.1 These dehydrators are exempt from all requirements, save recordkeeping in §63.774(d)(1), provided the criterion in Condition 3.7.1.1 or 3.7.1.2 below is met: (§63.764(e)(1)) 3.7.1.1 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 3.7.3 (§63.764 (e)(1)(ii)). OR 3.7.1.2 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 3.7.4 (§63.764(e)(1)(i).) 3.7.2 Records shall be kept of the actual average benzene emissions (in terms of benzene emissions per year) as determined in accordance with Condition 3.7.3 §63.772(b)(2) (§63.774(d)(1)(ii)). Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit # 95OPWE103 Page 30 3.7.3 The determination of actual average benzene emissions from this glycol dehydration unit shall be made using the procedure described in Condition 3.7.3.1 below. Emissions shall be determined with federally enforceable controls in place. 3.7.3.1 The actual average benzene emissions shall be determined using the model GRI- GLYCaIc, Version 3.0 or higher, and the procedures presented in the associated GRI-GLYCaIc, 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)). 3.7.4 The determination of actual flowrate of natural gas to the glycol dehydration unit shall be made using the procedure described in Condition 3.7.4.1 below. 3.7.4.1 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)) Note: If the exemption criterion in Condition 3.7.1 are not met, the source is subject the requirements in Conditions 3.7.5 and 3.7.6 below: 3.7.5 Each owner or operator of an area source not located in a UA plus offset and UC boundary (as defined in §63.761) shall comply with the provisions specified in paragraphs (d)(2(i) through (iii) of this section. (§63.764(d)(2)) 3.7.5.1 Determine the optimum glycol circulation rate using the following equation: (§63.764 (d)(2)(i)) gal TEG ( Fx(I-O) l LoPT=1.15x3.0 lb H2O 124 hr/dayl Where: Loin- = Optimal circulation rate, gal/hr. F=Gas flowrate (MMscf/D) I =Inlet water content(lb/MMscf) O= Outlet water content (lb/MMscf) 3.0 = The industry accepted rule of thumb for a TEG-to water ratio (gal TEG/lb H2O) 1.15 = Adjustment factor included for a margin of safety. 3.7.5.2 Operate the TEG dehydration unit such that the actual glycol circulation rate does not exceed the optimum glycol circulation rate determined in accordance with paragraph (d)(2)(i) of this section. If the TEG dehydration unit is unable to meet the sales gas specification for moisture content using the glycol circulation rate Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 31 determined in accordance with paragraph (d)(2)(i), the owner or operator must calculate an alternate circulation rate using GRI—GLYCalcTM, Version 3.0 or higher. The owner or operator must document why the TEG dehydration unit must be operated using the alternate circulation rate and submit this documentation with the initial notification in accordance with §63.775(c)(7). (§63.764(d)(2)(ii)) 3.7.5.3 Maintain a record of the determination specified in paragraph (d)(2)(ii) in accordance with the requirements in §63.774(f) and submit the Initial Notification in accordance with the requirements in §63.775(c)(7). If operating conditions change and a modification to the optimum glycol circulation rate is required, the owner or operator shall prepare a new determination in accordance with paragraph (d)(2)(i) or (ii) of this section and submit the information specified under §63.775(c)(7)(ii) through (v). (§63.764(d)(2)(iii)) 3.7.6 Except as specified in paragraphs (c), (d), and (f) of this section, each owner or operator of a facility subject to this subpart shall maintain the records specified in paragraphs (b)(1) through (11) of this section: (§63.774(b)) 3.7.6.1 The owner or operator of an affected source subject to the provisions of this subpart shall maintain files of all information (including all reports and notifications) required by this subpart. The files shall be retained for at least 5 years following the date of each occurrence, measurement, maintenance, corrective action, report or period. (§63.774(b)(1)) a. All applicable records shall be maintained in such a manner that they can be readily accessed. (63.774(b)(1)(i)) b. The most recent 12 months of records shall be retained on site or shall be accessible from a central location by computer or other means that provides access within 2 hours after a request. (§63.774(b)(1)(ii)) c. The remaining 4 years of records may be retained offsite. (§63.774(b)(1)(iii)) d. Records may be maintained in hard copy or computer-readable form including, but not limited to, on paper, microfilm, computer, floppy disk, magnetic tape, or microfiche. (§63.774(b)(1)(iv)) 3.7.6.2 The owner or operator of an area source not located within a UA plus offset and UC boundary must keep a record of the calculation used to determine the optimum glycol circulation rate in accordance with §63.764(d)(2)(i) or §63.764(d)(2)(ii), as applicable. (§63.774 (f)) 3.8 This unit is subject to the requirements in 40 CFR part 63 Subpart A "General Provisions", as adopted by reference in Colorado Regulation No. 8, Part E, Section I as specified in 40 CFR Part 63 Subpart HH § 63.764. These requirements include, but are not limited to the following: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit # 95OPWE103 Page 32 3.8.1 Prohibited activities and circumvention in § 63.4. 3.8.2 Operation and maintenance requirements in § 63.6(e)(1). 3.8.3 Notification requirements in § 63.9(j). 3.8.4 Recordkeeping and reporting requirements in § 63.10(b), except as provided in § 63.774(b)(1). 3.9 The following requirements apply to the construction of TEG dehydrator D-3. 3.9.1 The source must submit a Notice of Startup (NOS) form to the Division by no later than fifteen (15) days after the commencement of the operation of this dehydrator. The NOS form may be downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. (Colorado Regulation No. 3, Part B, Section III.G.1). The NOS form shall include make, model and serial number of the dehydrator installed. 3.9.2 The permit to construct this dehydrator shall expire if the facility: (i) does not commence construction or operation of this source within 18 months after either, the date of issuance of the this permit, DATE, or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Colorado Regulation No. 3, Part B, III.F.4.b. (Colorado Regulation No. 3, Part B, Section III.F.4.) Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 33 4. P016—Condensate Truck Loadout Rack controlled with a combustor Permit Monitoring Condition Compliance Parameter Number Compliance Limits Emission Factor Method Interval VOC 4.1 0.7 tons/year 4.42 pounds per Recordkeeping and Monthly 1000 gallons calculation 4 12 month rolling total Condensate Loaded 4.2 153,884.4 bbl/year - • - Visible Emissions 4.3 Not to exceed 30% `° EPA Method 22 Daily Pilot Flame 4.4 Present at all times ,- Thermocouple Continuous 4.1 VOC emissions from condensate truck loading shall not exceed the limitations stated above (Colorado Construction Permit 97WE0553). VOC emissions shall be calculated monthly using the compliance emission factor above (calculated from methodology in AP 42 Chapter 5-2) in the following equation: tons/mo=EF (lb/Mgallons) x Condensate Throughput (gallon/mo) x Control Efficiency 1000 gallons x 2000 (lb/ton) A control efficiency of 95% may be used for the combustion device. The parameters used to determine the emissions factor are as follows. The Division shall be notified should there be any change in these parameters that would result in a higher emission factor. Truck Loadout Emissions (lb/1000 gallons loaded) = (12.46 x S x P x M) /(T x CF) where: S = Saturation Factor 0.6 Submerged loading, dedicated normal service P =Ave Vapor Pressure 4.65 psi M = Molecular Weight 66.0 lb/lb mole T = Average Temperature 518.83 degrees R (based on 58.16° F) CF=Control Efficiency 1 Monthly emissions of VOC will be used in a rolling twelve month total to monitor compliance with the annual limitation. Each month a new twelve month total shall be calculated using the previous twelve months' data. 4.2 The quantity of condensate loaded into trucks shall not exceed the limitations stated above (Colorado Construction Permit 97WE0553). The quantity of condensate loaded into trucks shall be monitored and recorded monthly and used to calculate emissions as required by Condition 4.1. Monthly condensate throughput shall be the sum of all loading activities within that month. This sum will be used in a rolling twelve month total to monitor compliance with the annual limitation. Each month a new twelve month total shall be calculated using the previous twelve months' data. Records of condensate throughput shall be kept in a log to be made available to the Division upon request. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit # 95OPWE103 Page 34 4.3 Visible emission from the combustor shall not exceed 30% opacity for a period or periods aggregating six minutes in any sixty consecutive minutes (Colorado Regulation No. 1, Section II.A.5). Compliance shall be monitored by conducting EPA Method 22 observations for one minute daily. If visible emissions are observed, an EPA Reference Method 9 opacity observation shall be performed the next day that truck loading occurs. The result(s) of the visual observations and the Method 9 observations shall be kept on file and made available for Division review upon request. The EPA Reference Method 9 opacity observations shall be performed by an observer with a current and valid Method 9 certification. A clear and readable copy of the observer's certificate and any opacity observations shall be kept on file and made available to the Division for review upon request. Subject to the provisions of §25-7-123.1, C.R.S., and in the absence of credible evidence to the contrary, exceedance of the opacity limit shall be considered to exist from the time a Method 9 reading is taken that shows an exceedance of the opacity limit until a Method 9 reading is taken that shows the opacity is less than the opacity limit. 4.4 The combustor shall be operated at all times when emissions are routed to it. The combustor shall be operated with a pilot flame present at all times. The presence of a pilot flame shall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame. The device shall be equipped with an alarm to indicate no ignition of the pilot flame. Records of the times and duration of all periods of pilot flame outages, and estimated emissions shall be maintained and made available to the Division upon request. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 35 5. P012 - Fugitive VOC Emissions from Equipment Leaks Permit Monitoring Condition Compliance Parameter Number Limits Compliance Emission Factor Method Interval Recordkeeping and Emission VOC 5.1 18.22 tons/yr By Component-EPA Protocol for Annually Calculations Equipment Leak Estimates Leak Detection 5.2 p'e?s ._ Audio,Visual,and Olfactory Weekly 5.1 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-95-017. These emission factors are fixed until changed by established permit modification procedures. tngo fi ' %hatieom ery e iquid 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 Open-Ended Lines 4.41 x 10-3 3.09 x 10-3 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. Calculation of annual 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. The annual inlet gas analysis shall be used to determine the appropriate Weight%VOC to use in the above equation. Operating Permit Number: 95OPWE103 FIRST ISSUED: May I, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit ft 95OPWE103 Page 36 5.1.1 The emission limitation was developed based on the following component count, which includes a 20% buffer on actual component count: Component dtnponent Count Gas snriinol,... Light Liquid, Valves 710 158 Connectors 4,371 474 Flanges 506 194 Pump Seals 8 6 Open-Ended Lines 17 Other* 60 9 Total 5,655 858 *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms,hatches, instrument meters,polish rods,and vents. A running total shall then be kept of all additions and subtractions to the component count. A manual component count shall be performed at least once every five (5) calendar years as a check against the running total. As of the issuance of this permit, the last component hard count was conducted October 2009. The most recent running total shall be used for emission calculation purposes. The records shall be kept at the site and made available for Division review upon request. 5.2 The facility shall conduct weekly audio, visual, and olfactory inspections for indications of equipment leaks. Documentation of the weekly inspections will be kept onsite for Division review upon request. 5.2.1 If a leak is found, it will be tagged and a first attempt to fix the leak will be made within 5 days from the time the leak was detected 5.2.2 If the leak is unable to be fixed on the first attempt, a second attempt will be made within 15 days unless a facility shutdowns required to isolate the component to fix the leak. In that situation, the leak will be fixed during the next shutdown. 5.2.3 A soap test or equivalent will be used to ensure the leak is fixed. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit # 95OPWE103 Page 37 6. P013—Stabilized Condensate Tanks controlled with a combustor Permit Monitoring Condition Emission Parameter Number Compliance Limits Factor Method Interval VOC 6.1 1.28 tons/yr 0.33 lb/bbl Recordkeeping and Monthly calculation Condensate Throughput 6.2 153,884.4 bbl/yr 12 month rolling total - [State-only] Visible Emissions 6.3 No visible emissions ` _ EPA Method 22 Daily Control Device 6.4 >95%VOC Destruction See Condition 6.4 Pilot Flame 6.5 Present at all times ��.£.- Thermocouple Continuous Construction Requirements 6.6 - See Condition 6.6 6.1 Emissions of VOC from the tank battery shall not exceed the limitations listed above. Compliance with the annual limit shall be monitored 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 emissions of VOC shall be calculated using monthly condensate production (as required by Condition 6.2) and the emission factor provided above (derived from EPA TANKS model) in the equation below: bbl tons Condensate Throughput (/ ) ]xEmission Factor (( Ib mo bbl) xControl Efficiency mo lb 2000—t — n A control efficiency of 95% may be used for the combustor. Records of the actual emissions shall be maintained and made available to the Division for inspection upon request. 6.2 The quantity of condensate processed through the tank battery shall not exceed the limit above. The quantity of condensate processed through the tank battery shall be monitored and recorded monthly and used to calculate emissions as required by Condition 6.1. The monthly quantity of condensate processed 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. 6.3 [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) 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. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 38 6.4 The condensate tanks shall be equipped with a control system that shall be capable of reducing the emissions of volatile organic compounds by at least 95%. (Colorado Regulation No. 7, Section XII.G.5.b) 6.4.1 All air pollution control equipment used to demonstrate compliance with Section XII shall be operated and maintained consistent with manufacturer specifications and good engineering and maintenance practices. The owner or operator shall keep manufacturer specifications on file. In addition, all such air pollution control equipment shall be adequately designed and sized to achieve the control efficiency rates required by this Section XII and to handle reasonably foreseeable fluctuations in emissions of volatile organic compounds. Fluctuations in emissions that occur when the separator dumps into the tank are reasonably foreseeable. (Colorado Regulation No. 7, Section XII.C.1.a) 6.4.2 All condensate collection, storage, processing and handling operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. (Colorado Regulation No. 7, Section XII.C.1.b) 6.5 The combustor shall be operated at all times when emissions are routed to it. The combustor shall be operated with a pilot flame present at all times. The presence of a pilot flame shall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame. The device shall be equipped with an alarm to indicate no ignition of the pilot flame. Records of the times and duration of all periods of pilot flame outages, and estimated emissions shall be maintained and made available to the Division upon request. 6.6 The following requirements apply to the construction of four additional condensate tanks: 6.6.1 The source must submit a Notice of Startup (NOS) form to the Division by no later than fifteen (15) days after the commencement of the operation of these tanks. The NOS form may be downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. (Colorado Regulation No. 3, Part B, Section III.G.1). 6.6.2 The permit to construct these tanks shall expire if the facility: (i) does not commence construction or operation of this source within 18 months after either, the date of issuance of the this permit, DATE, or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Colorado Regulation No. 3, Part B, III.F.4.b. (Colorado Regulation No. 3, Part B, Section III.F.4.) Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 39 7. Comb-1 —Dehy Combustor Permit Monitoring Condition Compliance Parameter Number Compliance Limits Emission Factor Method Interval NOx 7.1 0.5 tons/yr 0.068 lb/MMBtu Recordkeeping and Monthly calculation CO 2.6 tons/yr 0.37 lb/MMBtu 12 month rolling total Flare Supplemental Fuel 7.2 >0.106 MMBtu/hr = Flow Meter Continuous Control Requirements 7.3 95%destruction See Condition 7.3 [State-only] Flare Opacity 7.4 No visible emissions ' , EPA Method 22 Daily Pilot Flame 7.5 Present at all times a Thermocouple Continuous 7.1 Emissions of NOx and CO from the flare shall not exceed the limitations listed above. Monthly emissions shall be calculated by the end of the subsequent month using the above emission factor, the Btu content of the natural gas (as required by Condition 3.1), and the monthly fuel consumption, calculated by summing the assist gas used (as recorded pursuant to Condition 7.2) and the GLYCalc output from each dehydrator, in the equation below: tons/mo=JEF(lb/MMBtu)x total fuel consumption(MMscf/year)x heat content of fuel(MMBtu/MMscf)1 2000 lbs/ton Monthly emissions shall be used in a twelve month rolling total to monitor compliance with the annual limitations. Each month a new twelve month total shall be calculated using the previous twelve months data. 7.2 Supplemental fuel to the flare shall not be less than 0.106 MMBtu/hr. A flow meter shall be used to measure the gas flow rate. The heat rate shall be calculated from the fuel use rate and the heat content of the gas determined from the most recent gas analysis. The calculations shall be maintained and made available for inspection upon request. (Construction Permit 00WE0470) Fuel meter measurements will be recorded monthly and divided by the number of hours per month. 7.3 This control system that shall be capable of reducing the dehydrator emissions of volatile organic compounds by at least 95%. The flare shall be equipped with a heat sensing monitoring device, equipped with an alarm that indicates no ignition of the pilot flame. Records of the times and duration of all pilot flame outages shall be kept. (Construction Permit 00WE0470). Compliance with the 95% reduction shall be monitored using the combination of: 1) The total supplemental heat rate provided to the flare exceeding the supplemental heat rate required in Condition 7.2., Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 40 2) the pilot flame operation records required by Condition 7.5, and 3) the lean glycol flow rate records required by Condition 3.4. Records of the compliance monitoring results shall be maintained for Division inspection upon request. 7.4 [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.I.c) 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. 7.5 The flare shall be operated at all times when emissions are routed to it. The flare shall be operated with a pilot flame present at all times. The presence of a flare pilot flame shall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame. The device shall be equipped with an alarm to indicate no ignition of the pilot flame. Records of the times and duration of all periods of pilot flame outages, and estimated emissions shall be maintained and made available to the Division upon request. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 41 8. 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 The mV reading or O2% shall be recorded during portable monitoring testing to establish a baseline. 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. 8.1 The outlet oxygen content of the exhaust stream shall be measured during portable monitoring when measurement of the outlet CO content is being conducted. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 42 9. Compliance Assurance Monitoring 9.1 The Compliance Assurance Monitoring (CAM) requirements in 40 CFR Part 64, as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV, apply to six (6) Caterpillar compressor engines, C-238, C-235, C-236 and P018, with respect to the VOC limitations identified in Condition 1.2 and C-237 and C-239 with respect to the CO limitation identified in Condition 2.1. The requirements also apply to the triethylene glycol regeneration unit, D2 and D3, with respect to the VOC and HAP limitations identified in Section II, Condition 3.1. The requirements are as follows: 9.1.1 The permittee shall follow the CAM Plan provided in Appendix G of this permit. 9.1.1.1 For the glycol dehydration unit, 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. 9.1.1.2 For the engines, an excursion, for purposes of reporting is any daily engine exhaust (catalyst inlet) temperature reading that is less than 450°F or greater than 1350°F Excursions shall be reported as required by Section IV, Conditions 21 and 22.d of this permit. 9.1.2 Operation of Approved Monitoring 9.1.2.1 At all times, the owner or operator shall maintain the monitoring, including but not limited to, maintaining necessary parts for routine repairs of the monitoring equipment (40 CFR Part 64 § 64.7(b), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 9.1.2.2 Except for, as applicable, monitoring malfunctions, associated repairs, and required quality assurance or control activities (including, as applicable, calibration checks and required zero and span adjustments), the owner or operator shall conduct all monitoring in continuous operation (or shall collect data at all required intervals) at all times that the pollutant-specific emissions unit is operating. Data recorded during monitoring malfunctions, associated repairs, and required quality assurance or control activities shall not be used for purposes of these CAM requirements, including data averages and calculations, or fulfilling a minimum data availability requirement, if applicable. The owner or operator shall use all the data collected during all other periods in assessing the operation of the control device and associated control system. A monitoring malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring to provide valid data. Monitoring failures that are caused in part by poor maintenance or 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). 9.1.2.3 Response to excursions or exceedances Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 43 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). 9.1.2.4 After approval of the monitoring required under the CAM requirements, if the owner or operator identifies a failure to achieve compliance with an emission limitation or standard for which the approved monitoring did not provide an indication of an excursion or exceedance while providing valid data, or the results of compliance or performance testing document a need to modify the existing indicator ranges or designated conditions, the owner or operator shall promptly notify the Division and, if necessary submit a proposed modification for this permit to address the necessary monitoring changes. Such a modification may include, but is not limited to, reestablishing indicator ranges or designated conditions, modifying the frequency of conducting monitoring and collecting data, or the monitoring of additional parameters (40 CFR Part 64 § 64.7(e), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 9.1.3 Quality Improvement Plan (QIP) Requirements 9.1.3.1 Based on the results of a determination made under the provisions of Condition 9.1.2.3.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). 9.1.3.2 The owner or operator shall maintain a written QIP, if required, and have it Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 44 available for inspection (40 CFR Part 64 § 64.8(b)(1), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 9.1.3.3 The QIP initially shall include procedures for evaluating the control performance problems and, based on the results of the evaluation procedures, the owner or operator shall modify the plan to include procedures for conducting one or more of the following actions, as appropriate: a. Improved preventative maintenance practices (40 CFR Part 64 § 64.8(b)(2)(i), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). b. Process operation changes (40 CFR Part 64 § 64.8(b)(2)(ii), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). c. Appropriate improvements to control methods (40 CFR Part 64 § 64.8(b)(2)(iii), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). d. Other steps appropriate to correct control performance (40 CFR Part 64 § 64.8(b)(2)(iv), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). e. More frequent or improved monitoring (only in conjunction with one or more steps under Conditions 9.1.3.3.a-d above) (40 CFR Part 64 § 64.8(b)(2)(v), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 9.1.3.4 If a QIP is required, the owner or operator shall develop and implement a QIP as expeditiously as practicable and shall notify the Division if the period for completing the improvements contained in the QIP exceeds 180 days from the date on which the need to implement the QIP was determined (40 CFR Part 64 § 64.8(c), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 9.1.3.5 Following implementation of a QIP, upon any subsequent determination pursuant to Condition 9.1.2.3.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). 9.1.3.6 Implementation of a QIP shall not excuse the owner or operator of a source from Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 45 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). 9.1.4 Reporting and Recordkeeping Requirements 9.1.4.1 Reporting Requirements: The reports required by Section IV, Condition 22.d, shall contain the information specified in Appendix B of the permit and the following information, as applicable: a. Summary information on the number, duration and cause (including unknown cause, if applicable), for monitor downtime incidents (other than downtime associated with zero and span or other daily calibration checks, if applicable) ((40 CFR Part 64 § 64.9(a)(2)(ii), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV); and b. The owner or operator shall submit, if necessary, a description of the actions taken to implement a QIP during the reporting period as specified in Condition 9.1.3 of this permit. Upon completion of a QIP, the owner or operator shall include in the next summary report documentation that the implementation of the plan has been completed and reduced the likelihood of similar levels of excursions or exceedances occurring (40 CFR Part 64 § 64.9(a)(2)(iii), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 9.1.4.2 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 9.1.3 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). 9.1.5 Savings Provisions 9.1.5.1 Nothing in these CAM requirements shall excuse the owner or operator of a Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 46 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). 9.1.5.2 Nothing in these CAM requirements shall restrict or abrogate the authority of the U.S. EPA or the Division to impose additional or more stringent monitoring, recordkeeping, testing or reporting requirements on any owner or operator of a source under any provision of the federal clean air act, including but not limited to sections 114(a)(1) and 504(b), or state law, as applicable (40 CFR Part 64 § 64.10(a)(2), as adopted by reference in Colorado Regulation No. 3, Part C, Section XIV). 9.1.5.3 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 Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 47 SECTION III - Permit Shield Regulation No. 3, 5 CCR 1001-5, Part C, $§ LA.4, V.D. & XIII.B; § 25-7-114.4(3)(a), C.R.S. 1. Specific Conditions Based upon the information available to the Division and supplied by the applicant, the following parameters and requirements have been specifically identified as non-applicable to the facility to which this permit has been issued. This shield does not protect the source from any violations that occurred prior to or at the time of permit issuance. In addition, this shield does not protect the source from any violations that occur as a result of any modification or reconstruction on which construction commenced prior to permit issuance. Emission Unit Description& Applicable Number Requirement Justification II I. LA.I.b- C-238 Caterpillar O361251 3300 Reg Internal combustion engines are not considered fuel burning equipment HP SN 1 YG00047 Particulate emissions for the applicable requirements of Regulation I. from fuel-burning C-234 Caterpillar O361251 3300 equipment HP SN 1YO00027 Reg I.VLB.5.a- C-235 Caterpillar G3612SI 3300 Sulfur dioxide HP SN IYG00028 emissions from fuel- burning equipment C-236 Caterpillar G361251 3300 HP SN 11/G00029 P018 Caterpillar G3612 3550 HP SN BEK00356 Facility-wide Reg 3.B.IV.D.3 - Activities at this site have not yet required Prevention of Significant PSD Review Deterioration(PSD)review or permitting. Requirements Reg 3.B.X-Air Activities at this site have not resulted in the facility being classified as a Quality Modeling major source for PSD,nor has there been any major modification. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 48 Emission Unit Description& Applicable Number Requirement Justification Reg 3.B.XI.- Facility-wide Visibility The facility has not been identified as a source that may impact the visibility in a Federal Class I area. Requirements Reg 4-Wood This facility does not include any wood burning stoves or wood burning Burning Stoves appliances,or advertise,or sell such devices. Reg 6 Part A- None of these provisions currently apply to any of the sources at the Adoption of Federal facility. NSPS Requirements Reg 6 Part B-State None of these State-only provisions currently apply to any of the sources Only NSPS at the facility. Requirements Reg 7 V.C The facility is not a gasoline terminal, bulk gasoline plant or the type of gasoline dispensing plant subject to the provisions. Reg 7 VLB.I These provisions apply to the storage of petroleum liquids in tanks with Reg 7 VI.B.2 greater than 40,000 gallons capacity. Storage of Petroleum Distillates Reg 7 VILC-Crude These provision apply to the storage of crude oil in tanks with greater Oil Storage than 40,000 gallons capacity. Reg 10-SIP Rules Conformity of federal actions to SIPs and FIPs Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit # 95OPWE103 Page 49 2. General Conditions Compliance with this Operating Permit shall be deemed compliance with all applicable requirements specifically identified in the permit and other requirements specifically identified in the permit as not applicable to the source. This permit shield shall not alter or affect the following: 2.1 The provisions of §§ 25-7-112 and 25-7-113, C.R.S., or § 303 of the federal act, concerning enforcement in cases of emergency; 2.2 The liability of an owner or operator of a source for any violation of applicable requirements prior to or at the time of permit issuance. 2.3 The applicable requirements of the federal Acid Rain Program, consistent with § 408(a) of the federal act; 2.4 The ability of the Air Pollution Control Division to obtain information from a source pursuant to § 25-7-111(2)(I), C.R.S., or the ability of the Administrator to obtain information pursuant to § 114 of the federal act; 2.5 The ability of the Air Pollution Control Division to reopen the Operating Permit for cause pursuant to Regulation No. 3, Part C, § XIII. 2.6 Sources are not shielded from terms and conditions that become applicable to the source subsequent to permit issuance. 3. Stream-lined Conditions 3.1 The following applicable requirements have been subsumed within this operating permit using the pertinent streamlining procedures approved by the U.S. EPA. For purposes of the permit shield, compliance with the listed permit conditions will also serve as a compliance demonstration for purposes of the associated subsumed requirements. Permit Condition I Streamlined(Subsumed)Requirements Section II,Condition 1,7 Colorado Regulation No. 7, Section XVII.E.3.b.(i) [control requirements]—State-only Section II, Condition 3.8 Colorado Regulation No. 7, Section XII.H [dehy control requirements] Section II,Condition 3.8 Colorado Regulation No. 7, Section XVII.D [dehy control requirements]—State-only Section II,Condition 6.3 Colorado Regulation No. 1, Section II.A.5 [opacity limit] Section II, Condition 6.4 Colorado Regulation No. 7, Section XVII.C[tank control requirements]—State-only Section 17, Condition 7.4 Colorado Regulation No. 1, Section II.A.5 [opacity limit] Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 50 SECTION IV - General Permit Conditions(ver 11/16/2010) Administrative Changes Regulation No. 3, 5 CCR 1001-5, Part A, ¢ III. The permittee shall submit an application for an administrative permit amendment to the Division for those permit changes that are described in Regulation No. 3, Part A, § I.B.I. The permittee may immediately make the change upon submission of the application to the Division. 2. Certification Requirements Regulation No. 3, 5 CCR 1001-5, Part C, §§ III.B.9.,V.C.16.a.&e. and V.C.17. a. Any application, report, document and compliance certification submitted to the Air Pollution Control Division pursuant to Regulation No. 3 or the Operating Permit shall contain a certification by a responsible official of the truth, accuracy and completeness of such form,report or certification stating that, based on information and belief formed after reasonable inquiry,the statements and information in the document are true,accurate and complete. b. All compliance certifications for terms and conditions in the Operating Permit shall be submitted to the Air Pollution Control Division at least annually unless a more frequent period is specified in the applicable requirement or by the Division in the Operating Permit. c. Compliance certifications shall contain: (i) the identification of each permit term and condition that is the basis of the certification; (ii) the compliance status of the source; (iii) whether compliance was continuous or intermittent; (iv) method(s)used for determining the compliance status of the source, currently and over the reporting period; and (v) such other facts as the Air Pollution Control Division may require to determine the compliance status of the source. d. All compliance certifications shall be submitted to the Air Pollution Control Division and to the Environmental Protection Agency at the addresses listed in Appendix D of this Permit. e. If the permittee is required to develop and register a risk management plan pursuant to § 112(r)of the federal act,the permittee shall certify its compliance with that requirement;the Operating Permit shall not incorporate the contents of the risk management plan as a permit term or condition. 3. Common Provisions Common Provisions Regulation, 5 CCR 1001-2 ¢§ ILA., II.B., II.C., II.E., II.F., 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 Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 51 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 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit ft 95OPWE103 Page 52 circumstances beyond the owner or operator's control,compliance may, upon the Division's approval,be determined using the arithmetic mean of the results of the two other runs. Nothing in this section shall abrogate the Division's authority to conduct its own performance test(s) if so warranted. d. Affirmative Defense Provision for Excess Emissions during Malfunctions Note that until such time as the U.S. EPA approves this provision into the Colorado State Implementation Plan (SIP), it shall be enforceable only by the State. 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. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 53 The Affirmative Defense Provision does not apply to failures to meet federally promulgated performance standards or emission limits, including, but not limited to,new source performance standards and national emission standards for hazardous air pollutants. The affirmative defense provision does not apply to state implementation plan(sip) limits or permit limits that have been set taking into account potential emissions during malfunctions, including, but not necessarily limited to, certain limits with 30-day or longer averaging times, limits that indicate they apply during malfunctions, and limits that indicate they apply at all times or without exception. e. Circumvention Clause A person shall not build, erect, install,or use any article,machine, equipment, condition, or any contrivance,the use of which, without resulting in a reduction in the total release of air pollutants to the atmosphere,reduces or conceals an emission which would otherwise constitute a violation of this regulation.No person shall circumvent this regulation by using more openings than is considered normal practice by the industry or activity in question. f Compliance Certifications For the purpose of submitting compliance certifications or establishing whether or not a person has violated or is in violation of any standard in the Colorado State Implementation Plan,nothing in the Colorado State Implementation Plan shall preclude the use, including the exclusive use,of any credible evidence or information,relevant to whether a source would have been in compliance with applicable requirements if the appropriate performance or compliance test or procedure had been performed. Evidence that has the effect of making any relevant standard or permit term more stringent shall not be credible for proving a violation of the standard or permit term. When compliance or non-compliance is demonstrated by a test or procedure provided by permit or other applicable requirement,the owner or operator shall be presumed to be in compliance or non-compliance unless other relevant credible evidence overcomes that presumption. g. Affirmative Defense Provision for Excess Emissions During Startup and Shutdown An affirmative defense is provided to owners and operators for civil penalty actions for excess emissions during periods of startup and shutdown. To establish the affirmative defense and to be relieved of a civil penalty in any action to enforce an applicable requirement,the owner or operator of the facility must meet the notification requirements below in a timely manner and prove by a preponderance of the evidence that: (i) The periods of excess emissions that occurred during startup and shutdown were short and infrequent and could not have been prevented through careful planning and design; (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, Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 54 (viii) At all times,the facility was operated in a manner consistent with good practices for minimizing emissions. This subparagraph is intended solely to be a factor in determining whether an affirmative defense is available to an owner or operator,and shall not constitute an additional applicable requirement. The owner or operator of the facility experiencing excess emissions during startup and shutdown shall notify the Division verbally as soon as possible, but no later than two(2)hours after the start of the next working day, and shall submit written quarterly notification following the initial occurrence of the excess emissions. The notification shall address the criteria set forth above. The Affirmative Defense Provision contained in this section shall not be available to claims for injunctive relief The Affirmative Defense Provision does not apply to State Implementation Plan provisions or other requirements that derive from new source performance standards or national emissions standards for hazardous air pollutants,or any other federally enforceable performance standard or emission limit with an averaging time greater than twenty- four hours. In addition, an affirmative defense cannot be used by a single source or small group of sources where the excess emissions have the potential to cause an exceedance of the ambient air quality standards or Prevention of Significant Deterioration(PSD) increments. In making any determination whether a source established an affirmative defense,the Division shall consider the information within the notification required above and any other information the Division deems necessary, which may include,but is not limited to,physical inspection of the facility and review of documentation pertaining to the maintenance and operation of process and air pollution control equipment. 4. Compliance Requirements Regulation No. 3, 5 CCR 1001-5, Part C, §§ III.C.9., V.C.11.& 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. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 55 e. Any schedule for compliance for applicable requirements with which the source is not in compliance at the time of permit issuance shall be supplemental, and shall not sanction noncompliance with,the applicable requirements on which it is based. f. For any compliance schedule for applicable requirements with which the source is not in compliance at the time of permit issuance,the permittee shall submit, at least every 6 months unless a more frequent period is specified in the applicable requirement or by the Air Pollution Control Division,progress reports which contain the following: (i) dates for achieving the activities,milestones, or compliance required in the schedule for compliance, and dates when such activities, milestones, or compliance were achieved; and (ii) an explanation of why any dates in the schedule of compliance were not or will not be met, and any preventive or corrective measures adopted. g. The permittee shall not knowingly falsify,tamper with,or render inaccurate any monitoring device or method required to be maintained or followed under the terms and conditions of the Operating Permit. 5. Emergency Provisions Regulation No. 3, 5 CCR 1001-5, Part C, 6 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." Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 56 7. Emissions Trading, Marketable Permits,Economic Incentives Regulation No. 3, 5 CCR 1001-5, Part C, § V.C.13. No permit revision shall be required under any approved economic incentives, marketable permits, emissions trading and other similar programs or processes for changes that are specifically provided for in the permit. 8. Fee Payment C.R.S &&25-7-114.1(6)and 25-7-114.7 a. The permittee shall pay an annual emissions fee in accordance with the provisions of C.R.S. § 25-7-114.7. A 1% per month late payment fee shall be assessed against any invoice amounts not paid in full on the 91st day after the date of invoice, unless a permittee has filed a timely protest to the invoice amount. b. The permittee shall pay a permit processing fee in accordance with the provisions of C.R.S. § 25-7-114.7. If the Division estimates that processing of the permit will take more than 30 hours, it will notify the permittee of its estimate of what the actual charges may be prior to commencing any work exceeding the 30 hour limit. c. The permittee shall pay an APEN fee in accordance with the provisions of C.R.S. § 25-7-114.1(6)for each APEN or revised APEN filed. 9. Fugitive Particulate Emissions Regulation No. 1, 5 CCR 1001-3, $ III.D.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, § 111.O.1. 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, §§ 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. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 57 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.11.d. This permit does not convey any property rights of any sort, or any exclusive privilege. 14. Odor Regulation No. 2, 5 CCR 1001-4, Part A As a matter of state law only,the permittee shall comply with the provisions of Regulation No. 2 concerning odorous emissions. 15. Off-Permit Changes to the Source Regulation No. 3, 5 CCR 1001-5, Part C, 6 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., MD., 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, 66 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. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit#95OPWE103 Page 58 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: a. Any definition of"prompt"or a specific timeframe for reporting deviations provided in an underlying applicable requirement as identified in this permit;or b. Where the underlying applicable requirement fails to address the time frame for reporting deviations, reports of deviations will be submitted based on the following schedule: (i) For emissions of a hazardous air pollutant or a toxic air pollutant(as identified in the applicable regulation) that continue for more than an hour in excess of permit requirements,the report shall be made within 24 hours of the occurrence; (ii) For emissions of any regulated air pollutant, excluding a hazardous air pollutant or a toxic air pollutant that continue for more than two hours in excess of permit requirements,the report shall be made within 48 hours; and (iii) For all other deviations from permit requirements,the report shall be submitted every six(6)months, except as otherwise specified by the Division in the permit in accordance with paragraph 22.d. below. c. If any of the conditions in paragraphs b.i or b.ii above are met,the source shall notify the Division by telephone (303-692-3155)or facsimile(303-782-0278)based on the timetables listed above. [Explanatory note: Notification by telephone or facsimile must sped that this notification is a deviation report for an Operating Permit.] A written notice,certified consistent with General Condition 2.a. above(Certification Requirements), shall be submitted within 10 working days of the occurrence. All deviations reported under this section shall also be identified in the 6-month report required above. "Prompt reporting"does not constitute an exception to the requirements of"Emergency Provisions" for the purpose of avoiding enforcement actions. 22. Record Keeping and Reporting Requirements Regulation No. 3, 5 CCR 1001-5, Part A, & II.;Part C, $& V.C.6.,V.C.7. a. Unless otherwise provided in the source specific conditions of this Operating Permit,the permittee shall maintain compliance monitoring records that include the following information: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit# 95OPWE103 Page 59 (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. 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, § 1I.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, § III., except that proceedings to reopen and reissue permits affect only those parts of the permit for which cause to reopen exists. b. The Division shall reopen a permit whenever additional applicable requirements become applicable to a major source with a remaining permit term of three or more years, unless the effective date of the requirements is later than the date on which the permit expires, or unless a general permit is obtained to address the new requirements; whenever additional requirements(including excess emissions requirements)become applicable to an affected Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit # 95OPWE103 Page 60 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. 25. Severability Clause Regulation No. 3, 5 CCR 1001-5,Part C, 6 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, $ 111.B.2. The permittee shall not make a significant modification required to be reviewed under Regulation No. 3, Part B ("Construction Permit" requirements)without first receiving a construction permit. The permittee shall submit a complete Operating Permit application or application for an Operating Permit revision for any new or modified source within twelve months of commencing operation,to the address listed in Item 1 in Appendix D of this permit. If the permittee chooses to use the "Combined Construction/Operating Permit" application procedures of Regulation No. 3, Part C,then the Operating Permit must be received prior to commencing construction of the new or modified source. 27. Special Provisions Concerning the Acid Rain Program Regulation No. 3, 5 CCR 1001-5, Part C, S'$ 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, & II.C. 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 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division DCP Midstream, LP Colorado Operating Permit Enterprise Compressor Station Permit # 95OPWE103 Page 61 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, §$ Ill &V. The requirements in paragraphs a,b and e apply to sources located in an ozone non-attainment area or the Denver 1-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 V1II.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 be transferred using submerged or bottom filling equipment. For top loading,the fill tube shall reach within six inches of the bottom of the tank compartment. For bottom-fill operations,the inlet shall be flush with the tank bottom. c. 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 Number: 95OPWE103 FIRST ISSUED: May 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 H - AOS APPLICABILITY REPORTS *DISCLAIMER: None of the information found in these Appendices shall be considered to be State or Federally enforceable, except as otherwise stated in this permit, and is presented to assist the source, permitting authority, inspectors, and citizens. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix A Inspection Information Page 1 APPENDIX A Inspection Information 1. Directions to Facility: The station is in the Southwest quarter of the Southwest quarter Section of Section 30, Township 3 North, Range 63 West in Weld County. The station is one (1) mile North of US Highway 76 on the Gutterson Road between the towns of Keenesburg and Roggen. 2. Safety Equipment Required: Hard Hat, Safety Shoes, Ear Protection, Eye Protection, Fire Retardant Clothing 3. Facility Plot Plan: Figure 1 shows the plot plan as submitted on February 3, 2012. 4. List of Insignificant Activities: The following list of insignificant activities was provided in the initial Title V renewal application: • One (1) 2.5 MMBtu/hr dehy reboiler burner • One (1) 1.5 MMBtu/hr dehy reboiler burner • One (1) 0.75 MMBtu/hr natural gas-fired separator • One (1) 0.006 MMBtu/hr shed heater • One(1) 0.004 MMBtu/hr shed heater • Six (6) Engine Blowdown Vents • Two (2) 30,000 gallon pressurized bullet tanks • One (1) 210 bbl lube oil tank • One (1) 100 bbl produced water tank • Seven (2) 80 bbl sump tanks • One (1) 68 bbl used oil tanks • One (1) 475 gal sump tanks • Two (2) 475 gal used oil tanks • Two (2) 8 gal lube oil day tanks • Two (2) 10 acfm remediation skimmers/bubblers • One (I) 1136.3 Btu/scf tank vapor combustor Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix A Inspection Information Page 2 - yy l 1' 9 g T1}r i' <> !iii ill I il .4. t ! I i 1-i-+ ri. 1, , .I t!,,pi ,,ori.. Iti ig .:a: I I::I, I e'!:I r Y k ii h Jh •i. I II I ot:� T'.: ..I ;'!:-111 .; I I Iti III Z`I-7n a ,,,,, !id i 1 . N.,,,, ,.; , .. :., ,,, , , .:, . , '3 ; i : jl ....6.i 1.1 Aid.®:g�E�Y I�i _'�- ..: 'i I1 it 1 A S J f ■y am ♦ ` �''. 11'..1 ® \ . �n I I ...lIS S i Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Reporting Requirements and Definitions Page 1 APPENDIX B Reporting Requirements and Definitions with codes ver 2/20/07 Please note that, pursuant to 113(c)(2) of the federal Clean Air Act, any person who knowingly: (A) makes any false material statement, representation, or certification in, or omits material information from, or knowingly alters, conceals, or fails to file or maintain any notice, application, record, report, plan, or other document required pursuant to the Act to be either filed or maintained (whether with respect to the requirements imposed by the Administrator or by a State); (B) fails to notify or report as required under the Act; or (C) falsifies, tampers with, renders inaccurate, or fails to install any monitoring device or method required to be maintained or followed under the Act shall, upon conviction, be punished by a fine pursuant to title 18 of the United States Code, or by imprisonment for not more than 2 years, or both. If a conviction of any person under this paragraph is for a violation committed after a first conviction of such person under this paragraph, the maximum punishment shall be doubled with respect to both the fine and imprisonment. The permittee must comply with all conditions of this operating permit. Any permit noncompliance constitutes a violation of the Act and is grounds for enforcement action; for permit termination, revocation and reissuance, or modification; or for denial of a permit renewal application. The Part 70 Operating Permit program requires three types of reports to be filed for all permits. All required reports must be certified by a responsible official. Report#t: Monitoring Deviation Report (due at least every six months) For purposes of this operating permit, the Division is requiring that the monitoring reports are due every six months unless otherwise noted in the permit. All instances of deviations from permit monitoring requirements must be clearly identified in such reports. For purposes of this operating permit, monitoring means any condition determined by observation, by data from any monitoring protocol, or by any other monitoring which is required by the permit as well as the recordkeeping associated with that monitoring. This would include, for example, fuel use or process rate monitoring, fuel analyses, and operational or control device parameter monitoring. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Reporting Requirements and Definitions Page 2 Report #2: Permit Deviation Report (must be reported "promptly") In addition to the monitoring requirements set forth in the permits as discussed above, each and every requirement of the permit is subject to deviation reporting. The reports must address deviations from permit requirements, including those attributable to malfunctions as defined in this Appendix, the probable cause of such deviations, and any corrective actions or preventive measures taken. All deviations from any term or condition of the permit are required to be summarized or referenced in the annual compliance certification. For purposes of this operating permit, "malfunction" shall refer to both emergency conditions and malfunctions. Additional discussion on these conditions is provided later in this Appendix. For purposes of this operating permit, the Division is requiring that the permit deviation reports are due as set forth in General Condition 21. Where the underlying applicable requirement contains a definition of prompt or otherwise specifies a time frame for reporting deviations, that definition or time frame shall govern. For example, quarterly Excess Emission Reports required by an NSPS or Regulation No. 1, Section IV. In addition to the monitoring deviations discussed above, included in the meaning of deviation for the purposes of this operating permit are any of the following: (1) A situation where emissions exceed an emission limitation or standard contained in the permit; (2) A situation where process or control device parameter values demonstrate that an emission limitation or standard contained in the permit has not been met; (3) A situation in which observations or data collected demonstrates noncompliance with an emission limitation or standard or any work practice or operating condition required by the permit; or, (4) A situation in which an excursion or exceedance as defined in 40CFR Part 64 (the Compliance Assurance Monitoring (CAM) Rule) has occurred. (only if the emission point is subject to CAM) For reporting purposes, the Division has combined the Monitoring Deviation Report with the Permit Deviation Report. All deviations shall be reported using the following codes: 1 = Standard: When the requirement is an emission limit or standard 2 = Process: When the requirement is a production/process limit 3 =Monitor: When the requirement is monitoring 4 =Test: When the requirement is testing 5 = Maintenance: When required maintenance is not performed 6 = Record: When the requirement is recordkeeping 7= Report: When the requirement is reporting Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Reporting Requirements and Definitions Page 3 8=CAM: A situation in which an excursion or exceedance as defined in 40CFR Part 64 (the Compliance Assurance Monitoring (CAM) Rule) has occurred. 9= Other: When the deviation is not covered by any of the above categories Report #3: Compliance Certification (annually, as defined in the permit) Submission of compliance certifications with terms and conditions in the permit, including emission limitations, standards, or work practices, is required not less than annually. Compliance Certifications are intended to state the compliance status of each requirement of the permit over the certification period. They must be based, at a minimum, on the testing and monitoring methods specified in the permit that were conducted during the relevant time period. In addition, if the owner or operator knows of other material information (i.e. information beyond required monitoring that has been specifically assessed in relation to how the information potentially affects compliance status), that information must be identified and addressed in the compliance certification. The compliance certification must include the following: • The identification of each term or condition of the permit that is the basis of the certification; • Whether or not the method(s) used by the owner or operator for determining the compliance status with each permit term and condition during the certification period was the method(s) specified in the permit. Such methods and other means shall include, at a minimum, the methods and means required in the permit. If necessary, the owner or operator also shall identify any other material information that must be included in the certification to comply with section 113(c)(2) of the Federal Clean Air Act, which prohibits knowingly making a false certification or omitting material information; • The status of compliance with the terms and conditions of the permit, and whether compliance was continuous or intermittent. The certification shall identify each deviation and take it into account in the compliance certification. Note that not all deviations are considered violations.' • Such other facts as the Division may require, consistent with the applicable requirements to which the source is subject, to determine the compliance status of the source. For example, given the various emissions limitations and monitoring requirements to which a source may be subject, a deviation from one requirement may not be a deviation under another requirement which recognizes an exception and/or special circumstances relating to that same event. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Reporting Requirements and Definitions Page 4 The Certification shall also identify as possible exceptions to compliance any periods during which compliance is required and in which an excursion or exceedance as defined under 40 CFR Part 64 (the Compliance Assurance Monitoring (CAM) Rule) has occurred. (only for emission points subject to CAM) Note the requirement that the certification shall identify each deviation and take it into account in the compliance certification. Previously submitted deviation reports, including the deviation report submitted at the time of the annual certification, may be referenced in the compliance certification. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Reporting Requirements and Definitions Page 5 Startup, Shutdown, Malfunctions and Emergencies, Understanding the application of Startup, Shutdown, Malfunctions and Emergency Provisions, is very important in both the deviation reports and the annual compliance certifications. Startup, Shutdown, and Malfunctions Please note that exceedances of some New Source Performance Standards (NSPS) and Maximum Achievable Control Technology (MACT) standards that occur during Startup, Shutdown or Malfunctions may not be considered to be non-compliance since emission limits or standards often do not apply unless specifically stated in the NSPS. Such exceedances must, however, be reported as excess emissions per the NSPS/MACT rules and would still be noted in the deviation report. In regard to compliance certifications, the permittee should be confident of the information related to those deviations when making compliance determinations since they are subject to 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. Emergency Provisions Under the Emergency provisions of Part 70 certain operational conditions may act as an affirmative defense against enforcement action if they are properly reported. DEFINITIONS Malfunction (NSPS) means any sudden, infrequent, and not reasonably preventable failure of air pollution control equipment, process equipment, or a process to operate in a normal or usual manner. Failures that are caused in part by poor maintenance or careless operation are not malfunctions. Malfunction (SIP) means any sudden and unavoidable failure of air pollution control equipment or process equipment or unintended failure of a process to operate in a normal or usual manner. Failures that are primarily caused by poor maintenance, careless operation, or any other preventable upset condition or preventable equipment breakdown shall not be considered malfunctions. Emergency means any situation arising from sudden and reasonably unforeseeable events beyond the control of the source, including acts of God, which situation requires immediate corrective action to restore normal operation, and that causes the source to exceed a technology-based emission limitation under the permit, due to unavoidable increases in emissions attributable to the emergency. An emergency shall not include noncompliance to the extent caused by improperly designed equipment, lack of preventative maintenance, careless or improper operation, or operator error. Operating Permit Number: 950PWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Reporting Requirements and Definitions Page 6 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 —Enterprise Compressor Station OPERATING PERMIT NO: 95OPWE103 REPORTING PERIOD: (see first page of the permit for specific reporting period and dates) Operating Permit Unit Description Deviations noted Deviation Code 2 Malfunction/Emergency Unit ID During Period?' Condition Reported During Period? YES NO YES NO C-238 Caterpillar Model G3612SI Compressor Engine C-235 Caterpillar Model 63612S1 Compressor Engine C-236 Caterpillar Model G3612SI Compressor Engine P018 Caterpillar Model G3612 Compressor Engine D2 Natural Gas Dehydration System; using triethylene glycol P012 Equipment leak fugitive VOC emissions P016 Condensate truck loadout rack P013 Stabilized condensate tanks C-237 Caterpillar Model G3616 Compressor Engine C-239 Caterpillar Model G3616 Compressor Engine D3 TEG Dehydrator Comb-1 Combustion Device Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Reporting Requirements and Definitions Page 7 Operating Permit Unit Description Deviations noted Deviation Code 2 Malfunction/Emergency Unit ID During Period?' Condition Reported During Period? YES NO YES NO'matMy . ls General Conditions , Insignificant • `E- g:, 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 40 CFR Part 64 (the Compliance Assurance Monitoring(CAM)Rule)has occurred. 9=Other: When the deviation is not covered by any of the above categories Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Reporting Requirements and Definitions Page 8 Monitoring and Permit Deviation Report- Part II FACILITY NAME: DCP Midstream, LP—Enterprise Compressor Station OPERATING PERMIT NO: 95OPWE103 REPORTING PERIOD: Is the deviation being claimed as an: Emergency Malfunction N/A, (For NSPS/MACT) Did the deviation occur during: Startup Shutdown Malfunction Normal Operation OPERATING PERMIT UNIT IDENTIFICATION: Operating Permit Condition Number Citation Explanation of Period of Deviation Duration(start/stop date &time) Action Taken to Correct the Problem Measures Taken to Prevent a Reoccurrence of the Problem Dates of Malfunctions/Emergencies Reported (if applicable) Deviation Code Division Code QA: SEE EXAMPLE ON THE NEXT PAGE Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Reporting Requirements and Definitions Page 9 EXAMPLE FACILITY NAME: Acme Corp. OPERATING PERMIT NO: 96OPZZXXX REPORTING PERIOD: 1/1/04 - 6/30/06 Is the deviation being claimed as an: Emergency Malfunction XX N/A (For NSPS/MACT) Did the deviation occur during: Startup Shutdown Malfunction Normal Operation OPERATING PERMIT UNIT IDENTIFICATION: Asphalt Plant with a Scrubber for Particulate Control - Unit XXX Operating Permit Condition Number Citation Section II, Condition 3.1 - Opacity Limitation Explanation of Period of Deviation Slurry Line Feed Plugged Duration START- 1730 4/10/06 END- 1800 4/10/06 Action Taken to Correct the Problem Line Blown Out Measures Taken to Prevent Reoccurrence of the Problem Replaced Line Filter Dates of Malfunction/Emergencies Reported (if applicable) 5/30/06 to A. Einstein, APCD Deviation Code Division Code QA: Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix B Reporting Requirements and Definitions Page 10 APPENDIX B: Monitoring and Permit Deviation Report- Part III REPORT CERTIFICATION SOURCE NAME: DCP Midstream, LP—Enterprise Compressor Station FACILITY IDENTIFICATION NUMBER: 123/0277 PERMIT NUMBER: 95OPWE103 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 are true, accurate and complete. Please note that the Colorado Statutes state that any person who knowingly, as defined in Sub-Section 18- 1-501(6), C.R.S., makes any false material statement, representation, or certification in this document is guilty of a misdemeanor and may be punished in accordance with the provisions of Sub-Section 25-7 122.1, C.R.S. Printed or Typed Name Title Signature of Responsible Official Date Signed Note: Deviation reports shall be submitted to the Division at the address given in Appendix D of this permit. No copies need be sent to the U.S. EPA. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix C Required Format for Annual Compliance Certification Report Page 1 APPENDIX C Required Format for Annual Compliance Certification Report (ver 2/20/07) 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—Enterprise Compressor Station OPERATING PERMIT NO: 95OPWE103 REPORTING PERIOD: I. Facility Status During the entire reporting period, this source was in compliance with ALL terms and conditions contained in the Permit, each term and condition of which is identified and included by this reference. The method(s) used to determine compliance is/are the method(s) specified in the Permit. With the possible exception of the deviations identified in the table below, this source was in compliance with all terms and conditions contained in the Permit, each term and condition of which is identified and included by this reference, during the entire reporting period. The method used to determine compliance for each term and condition is the method specified in the Permit, unless otherwise indicated and described in the deviation report(s). Note that not all deviations are considered violations. Operating Unit Description Deviations Monitoring Was compliance continuous or Permit Unit ID Reported Method per intermittent?3 Permit?2 Previous Current YES NO Continuous Intermittent C-238 Caterpillar Model G3612SI Compressor Engine C-235 Caterpillar Model G3612SI Compressor Engine, C-236 Caterpillar Model G361251 Compressor Engine P018 Caterpillar Model O3612 Compressor Engine D2 Natural Gas Dehydration System;using triethylene glycol Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix C Required Format for Annual Compliance Certification Report Page 2 Operating Unit Description Deviations Monitoring Was compliance continuous or Permit Unit ID Reported Method per intermittent?3 Permit?2 Previous Current YES NO Continuous Intermittent P012 Equipment leak fugitive VOC emissions P016 Condensate truck loadout rack P013 Stabilized condensate tanks C-237 Caterpillar Model G36I6 Compressor Engine C-239 Caterpillar Model G3616 Compressor Engine D3 TEG Dehydrator Comb-I Combustion device General Conditions r x'x s,. Insignificant k Activities' If deviations were noted in the previous deviation report (i.e., for the first six months of the annual reporting period), 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. NOTE: The Periodic Monitoring requirements of the Operating Permit program rule are intended to provide assurance that even in the absence of a continuous system of monitoring the Title V source can demonstrate whether it has operated in continuous compliance for the duration of the reporting period. Therefore, if a source 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. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix C Required Format for Annual Compliance Certification Report Page 3 Compliance status for these sources shall be based on a reasonable inquiry using readily available information. II. Status for Accidental Release Prevention Program: A. This facility is subject is not subject to the provisions of the Accidental Release Prevention Program (Section 112(r) of the Federal Clean Air Act) B. If subject: The facility is is not in compliance with all the requirements of section 112(r). 1. A Risk Management Plan will be has been submitted to the appropriate authority and/or the designated central location by the required date. III. Certification I have reviewed this certification in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this certification are true, accurate and complete. Please note that the Colorado Statutes state that any person who knowingly, as defined in § 18-1-501(6), C.R.S., makes any false material statement, representation, or certification in this document is guilty of a misdemeanor and may be punished in accordance with the provisions of§ 25-7 122.1, C.R.S. Printed or Typed Name Title Signature of Responsible Official Date Signed NOTE: All compliance certifications shall be submitted to the Air Pollution Control Division and to the Environmental Protection Agency at the addresses listed in Appendix D of this Permit. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix D Notification Addresses Page 1 APPENDIX D Notification Addresses 1. Air Pollution Control Division Colorado Department of Public Health and Environment Air Pollution Control Division Operating Permits Unit APCD-SS-B 1 4300 Cherry Creek Drive S. Denver, CO 80246-1530 ATTN: Matt Burgett 2. United States Environmental Protection Agency Compliance Notifications: Office of Enforcement, Compliance and Environmental Justice Mail Code 8ENF 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 Mail Stop 8P-AR U.S. Environmental Protection Agency, Region VIII 1595 Wynkoop Street Denver, CO 80202-1129 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix E Permit Acronyms Page 1 APPENDIX E Permit Acronyms Listed Alphabetically: AIRS - Aerometric Information Retrieval System AP-42 - EPA Document Compiling Air Pollutant Emission Factors APEN - Air Pollution Emission Notice (State of Colorado) APCD - Air Pollution Control Division (State of Colorado) ASTM - American Society for Testing and Materials BACT - Best Available Control Technology BTU - British Thermal Unit CAA - Clean Air Act (CAAA = Clean Air Act Amendments) CCR - Colorado Code of Regulations CEM - Continuous Emissions Monitor CF - Cubic Feet (scf= Standard Cubic Feet) CFR - Code of Federal Regulations CO - Carbon Monoxide COM - Continuous Opacity Monitor CRS - Colorado Revised Statute EPA - Environmental Protection Agency FR - Federal Register G - Grams Gal - Gallon HAPs - Hazardous Air Pollutants HP - Horsepower HP-HR - Horsepower Hour (G/HP-HR= Grams per Horsepower Hour) LAER - Lowest Achievable Emission Rate LBS - Pounds M - Thousand MM - Million MMscf - Million Standard Cubic Feet MMscfd - Million Standard Cubic Feet per Day N/A or NA - Not Applicable NOx - Nitrogen Oxides NESHAP - National Emission Standards for Hazardous Air Pollutants NSPS - New Source Performance Standards PA() - Particulate Matter Under 10 Microns PSD - Potential for Significant Deterioration PTE - Potential To Emit Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix E Permit Acronyms Page 2 RACT - Reasonably Available Control Technology SCC - Source Classification Code SIC - Standard Industrial Code SO2 - Sulfur Dioxide TPY - Tons Per Year TSP - Total Suspended Particulate VOC - Volatile Organic Compounds Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix F Permit Modifications Page 1 APPENDIX F Permit Modifications SECTION NUMBER, DATE OF REVISION CONDITION NUMBER DESCRIPTION OF REVISION Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix G Compliance Assurance Monitoring Plan Page 1 APPENDIX G Compliance Assurance Monitoring Plan - Engines Background a. Emission Unit Description: Six (6) Caterpillar Natural Gas Fired Internal Combustion Engines, turbocharged, 4-cycle, Lean Burn, powering a natural gas compressor. Engine ratings for each engine are as follows: AIRS ID Facility ID Site Rating 053 C-238 3550 HP 055 C-235 3550 HP 056 C-236 3550 HP 070 P018 3550 HP 071 C-237 4735 HP 072 C-239 4735 HP b. Applicable Regulation, Emission Limit, Monitoring Requirements: Engines C-238, C-235, C-236, and P018: Regulations: Operating Permit Condition 1.2 Emission Limitations: VOC 24.0 tons/yr Monitoring Requirements: Catalyst inlet temperature Engines C-237 and C-239: Regulations: Operating Permit Condition 2.1 Emission Limitations: CO 36.6 tons/yr Monitoring Requirements: Catalyst inlet temperature Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix G Compliance Assurance Monitoring Plan Page 2 c. Control Technology: Each engine is equipped with an oxidation catalyst to control CO and VOC emissions. II. Monitoring Approach Indicator I. Indicator Catalyst Inlet Temperature Measurement Approach The temperature of the exhaust gas into the catalyst will be measured using an in line thermocouple. II. Indicator Range The exhaust gas into the catalyst shall be greater than or equal to 450°F and less than or equal to 1350°F. Excursions trigger the permitee to investigate the engine performance and make any repairs or adjustments necessary. Any adjustments or repairs shall be recorded in the log to be made available to the Division upon request. III. Performance Criteria a. Data Representativeness The catalyst inlet temperature is measured upstream of the catalyst. The minimum accuracy is +/- 5°F b. Verification of Operational Status Guarantee from the thermocouple manufacturer. c. QA/QC Practices and Criteria Thermocouples shall be calibrated and replaced in accordance with manufacturer's recommendations. d. Monitoring Frequency Daily e. Data Collection Procedures Temperature data will be recorded once a day. No observation is required for days when the engine is not operated. f. Averaging Period None, unless more than one reading is taken and then a daily average. III. Justification a. Background: The pollutant specific emission units are six (6) internal combustion engines used to drive compressors. Each engine is equipped with a selective catalytic oxidation unit to control CO and VOC emissions. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix G Compliance Assurance Monitoring Plan Page 3 b. Rational for Selection of Performance Indicators: The Division selected the inlet temperature to the catalyst was approved as an indicator since the temperature is important for the proper activation of the catalyst. The Division approved inlet temperature to the catalyst as it is an indicator of the catalyst performance. The temperature into the oxidation catalyst unit is measured because the catalytic reactions that destroy pollutants are temperature-dependent. The reactions occur favorably if the engine exhaust temperature into the catalyst is greater than 450°F. Catalyst damage will occur if the inlet temperature is too high and deterioration of the catalyst would reduce emission destruction efficiency. Either excessive or inadequate temperature indicated possible problems with the engine operation that might be correctable after investigation. Monitoring of the temperature-sensing device of the inlet exhaust gas into the catalyst will ensure the presence of optimum conditions for the catalytic reaction. c. Rational for Selection of Indicator Ranges: The indicator range for the catalyst inlet temperature was selected based on available operational data from compliance tests, observations, and manufacturer data for lean burn engines equipped with catalytic control. The indicator range for the catalyst inlet temperature and the pressure drop cross the catalyst are the same ranges as specified in the final RICE MACT. The Division considers that the indicator range is also presumptively acceptable. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix G Compliance Assurance Monitoring Plan Page 4 Compliance Assurance Monitoring Plan - Dehydrators Background a. Emission Unit Description: Natural Gas Dehydration Systems using triethylene glycol (D-2 and D-3); b. Applicable Regulation, Emission Limit, Monitoring Requirements: D-2: Regulations: Operating Permit Condition 3.1 Emission Limitations: VOC 11.95 tons/yr Individual HAP 8 tons/yr Total HAP 20 tons/yr D-3: Regulations: Operating Permit Condition 3.1 Emission Limitations: VOC 5.06 tons/yr Individual HAP 8 tons/yr Total HAP 20 tons/yr c. Control Technology: Condenser and Flash Tank Flare II. Monitoring Approach Indicator No. 1 Indicator No. 2 I. Indicator Condenser Outlet Temperature Flare Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix G Compliance Assurance Monitoring Plan Page 5 Indicator No. I Indicator No. 2 Measurement The outlet temperature is measured continuously Presence of a flame is continuously monitored Approach with a 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. H. 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. The minimum accuracy is+/- 5 °F. 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. Practices/Criteria d. Monitoring Frequency Daily. Heat sensor will be monitored continuously. e. 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. f. 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). * = Proper ranges for the parametric monitoring in this plan are to be verified with actual testing data. Ranges may be modified dependent upon testing results. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H AOS Applicability Reports Page 1 APPENDIX H Applicability Reports ver 10/1/11 Note: A MS Word version of this Appendix can be found at: http://wwvv.cdphe.state.co.us/ap/oilgaspermitting.html DISCLAIMER: These are only example reports and do not cover all possible requirements. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H AOS Applicability Reports Page 2 Engine AOS Applicability Report Certification Language All information for the Applicability Reports must be certified by either 1) for Operating Permits, a Responsible Official as defined in Colorado Regulation No. 3, Part A, Section I.B.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. Printed or Typed Name Title Signature Date Signed Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H 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, 2004. ❑ Does apply to this engine and applicable emissions controls have been installed. Regulation No. 7, § XVII.E ❑ Does not apply to this engine. Engine does not have a maximum horsepower greater than 100 or the construction or relocation date precedes the applicability dates. ❑ Does apply to this engine. The following emission limits apply to the engine: NOx (g/hp-hr): 2.0 CO (g/hp-hr): 4.0 VOC (g/hp-hr): 1.0 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 I, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H 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 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/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 Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H 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@15% O2 Other Requirements for Owners and Operators 60.4234 Emission standards must be met for the lifetime of the engine. 60.4235 N/A - Sulfur content of gasoline. 60.4236 N/A (for now) - After July 1, 2009 owners and operators may not install engines with a power rating> 500HP that do not meet the emissions standards in 60.4230. 60.4237 N/A - Emergency Engines. 60.4238 - 60.4242 Compliance Requirements for Manufacturers —(Not Applicable) 60.4243 Compliance Requirements for Owners and Operators (b)(2)(ii) To maintain compliance with the emission limits in 60.4233, owners of SI ICE > 500HP must: • Keep a maintenance plan; • Keep records of conducted maintenance; • Maintain and operate the engine in a manner consistent with good air pollution control practice for minimizing emissions; • Conduct an initial performance test; and • Conduct subsequent performance tests every 8,760 hours or every three years, which ever comes first, in order to demonstrate compliance with the emission limits. (g) Air to fuel ratio controllers (AFRCs) must be maintained and operated appropriately in order to ensure proper operation of the engine and control device to minimize emissions at all times. 60.4244 Testing Requirements for Owners and Operators Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H AOS Applicability Reports Page 6 (a) Each performance test must be conducted within 10% of the highest achievable load and must comply with the testing requirements listed in 60.8 and Table 2 of NSPS JJJJ. (b) Performance tests may not be conducted during periods of startup, shutdown, or malfunction, as specified in 60.8(c). If the engine is non-operational when a performance test is due, the engine does not need to be started up just to test it, but will need to be tested immediately upon startup. (c) Three separate test runs must be conducted for each performance test as specified by 60.8(f). Each run must be within 10% of max load and be at least 1 hour in duration. (d) To determine compliance with the NOx, CO, and VOC mass per unit output emission limitations, the measured concentration must be converted using the equations outlined in this section of NSPS JJJJ. 60.4245 Notification, Reports, and Records for Owners and Operators (a) Owners of all stationary SI ICE must keep records of the following: (1) All notifications submitted to comply with this subpart; (2) Maintenance conducted on the engine; (3) N/A - Manufacturer information for certified engines, and (4) Documentation that shows non-certified engines are in compliance with the emission standards. (b) N/A— For emergency engines only. (c) Owners of non-certified engines ≥ 500HP must submit an initial notification as required in 60.7(a)(1) which includes the following information: (1) Name and address of the owner or operator; (2) The address of the affected source; (3) Engine information including make, model, engine family, serial number, model year, maximum engine power, and engine displacement; (4) Emission control equipment; and (5) Fuel used. CONCLUSION OF FINDINGS (EXAMPLE ONLY) In general, Acme's 1,235HP, Waukesha 7042 GSI engine is subject to the emissions limitations summarized in Table 1 of NSPS JJJJ. ACME will meet these emission limitations using an AFRC and a non-selective catalytic converter (NSCR). These emission rates will be met throughout the life of the engine. A maintenance plan will be kept and all maintenance activities will be recorded. Compliance with the emission limits will be confirmed by the initial performance tests, which shall be conducted following the procedures outlined in 60.4244. Copies of performance test results will be submitted within 60 days of the completion of each test. Since this is an uncertified engine, an initial notification will be submitted including all of the requested information in 40.4245 within 30 days of startup. ACME will keep records of all compliance related materials. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H 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. ❑ 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. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H AOS Applicability Reports Page 8 63.6600 Emission and operating limitations for RICE site rated at more than 500 hp (a) The engine is subject to the emission limits in table la and the operating limits in table 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. 63.6610 Initial performance test (a) the performance tests specified in Table 4 (select sampling port and measure O2, moisture and formaldehyde at inlet and outlet of the control device) shall be conducted within 180 days of startup. (b) & (c) not applicable construction did not commence between 12/19/02 and 6/15/04. (d) previous performance tests have not been conducted on this unit within two years, therefore, this provision does not apply. 63.6615 Subsequent performance tests Subsequent tests will be conducted as specified in Table 3. No additional testing is required for 4SRB engines meeting the formaldehyde percent reduction requirements. 63.6620 Performance test procedures (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 Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix I-I AOS Applicability Reports Page 9 (a), (c) & (d) Not applicable (b) a continuous parameter monitoring system (CPMS) shall be installed to measure the catalyst inlet temperature. The CPMS will meet the requirements in § 63.8 63.6630 Demonstrating initial compliance (a) initial compliance shall be determined in accordance with table 5 (initial performance test must indicate formaldehyde reduction of 76 percent or more, a CPMS must be installed to measure inlet temperature of the catalyst and the pressure drop and catalyst inlet temperature must be recorded during the initial performance test). (b) pressure differential will be established during the initial performance test. (c) Notification of compliance status will be submitted and will contain the results of the initial compliance demonstration. 63.6635 Monitoring to demonstrate continuous compliance (b) except for monitor malfunctions, associated repairs, and required QA/QC activities monitoring must be continuous at all time the engine is operating. (c) data recorded during monitoring malfunctions, associated repairs and required QA/QC activities must not be used in data averages and calculations to report operating levels, however, all the valid data collected during other periods shall be used. 63.6640 Demonstrating continuous compliance (a) continuous compliance will be demonstrated as specified in table 6 (collect catalyst inlet temperature data, reduce that data to 4-hr rolling average and maintain the 4-hr rolling averages to within the operating limitation and measuring the pressure drop across the catalyst once per month and demonstrating that the pressure drop meets the operating limitation. (b) deviations from the emission and operating limitations must be reported per § 63.6550. If catalyst is changed the operating parameters established during the initial performance test must be re-established. When operating parameters re-established a performance test must also be conducted. 63.6645 Notifications (a) Submit notifications in §§ 63.7(b) & (c), 63.8(e), (O(4) and (O(6), 63.9(b) thru (e) & (g) & (h) that apply by dates specified. (b) Not applicable. Acme unit started after effective dated for Subpart ZZZZ. (c) Submit initial notification within 120 days after becoming subject to Subpart ZZZZ. (d) thru (f) Not applicable. Acme engine greater than 500 hp and subject to requirements in Subpart ZZZZ. (g) & (h) Submit notification of intent to conduct performance test and notification of compliance status. 63.6650 Reports (a) Submit reports required by table 7 (compliance report and SSM reports (if actions inconsistent with SSM plan) Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT Air Pollution Control Division Colorado Operating Permit Appendix H AOS Applicability Reports Page 10 (b) Not applicable, an alternate schedule for report submittal has been approved. Reports will be submitted with title v reports (c) Compliance reports to contain the following information: company name and address, statement by responsible official certifying accuracy, date of report and beginning and end of reporting period, if SSM the information in 63.10(d)(5)(i), if no deviations a statement saying that, if no periods when CPMS out of control a statement saying that. (d) Not applicable, using CPMS (e) For each deviation the information in (e)(I) 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 semi-annual compliance reports. Operating Permit Number: 95OPWE103 FIRST ISSUED: May 1, 1999 RENEWED: DRAFT TECHNICAL REVIEW DOCUMENT For RENEWAL OF OPERATING PERMIT 95OPWE103 DCP Midstream, LP — Enterprise Compressor Station Weld County Source ID 1230277 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 Enterprise Compressor Station. The previous Operating Permit for this facility was issued on December 1, 2007 and will expire on December 1, 2012. 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 November 21, 2011, additional information submitted January 13, 2012, 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 Enterprise Compressor Station classified as a natural gas compressor station on a gas transmission line as set forth under Standard Industrial Classification Code 4922. The plant uses six (6) gas-fired internal combustion engines to drive compressors to boost the inlet gas pressure from about 80 PSIG to about 1050 PSIG to facilitate 123/0277 Page 1 of 9 DCP Midstream, LP— Enterprise Compressor Station Operating Permit No. 95OPWE103 Technical Review Document— Renewal 2 movement of the gas in the pipeline. All six (6) engines have individual stacks to vent the products of combustion. The station also includes two (2) triethylene glycol (TEG) dehydrator units which contacts "lean" triethylene glycol with the inlet natural gas stream to remove moisture. The "rich" glycol mixture is regenerated in a still for reuse in the process. The still vent exhaust stream is sent to a flare where it is combusted. The TEG dehydration systems operate with a flash tank. The flash tank emissions are used as fuel for the TEG regenerator boilers. A condensate product is generated when the inlet gas is routed through the inlet scrubber and transferred to eight (8) 300 barrel condensate storage tanks. A loading system is provided for moving the liquid condensate material from the tanks into a truck for transport offsite. The condensate tanks and loadout are controlled with a combustor. The plant is located one (1) mile north of US Highway 76 on the Gutterson Road between the towns of Keenesburg and Roggen, Weld County, Colorado. The area in which the plant 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 affected states within 50 miles of the plant. Rocky Mountain National Park is a Federal Class I designated areas within 100 kilometers of the plant. This plant is located in an area designated as attainment for all pollutants except ozone. Based on the information provided in the Title V application, this facility is categorized as a NANSR major stationary source (Potential to Emit of VOC or 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 (use 100 TPY if a listed source category)) 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. 123/0277 Page 2 of 9 DCP Midstream, LP— Enterprise Compressor Station Operating Permit No. 95OPWE103 Technical Review Document—Renewal 2 Emissions at the facility are as follows: Potential to emit ® VQG Four G3612 engines 96.00 109.68 96.00 Two G3616 engines 64.02 73.16 64.02 Fugitive 18.22 Cond Tanks 1.28 Loadout 0.71 Dehy1 11.95 Dehy2 5.06 Flare 0.47 2.57 Total 160.47 185.42 197.22 Emissions of hazardous pollutants are summarized on page 9 of this document. Applicable Requirements NESHAP Subpart ZZZZ Engines C235, C236, and C238 are considered existing engines under Subpart ZZZZ and are not subject to any requirements, in accordance with §63.6590(b)(3)(ii). Engine P018 and the two new Caterpillar G3616 engines permitted under this renewal issuance are considered new under the rule and are subject to requirements to reduce CO emissions or limit formaldehyde concentrations. NESHAP Subpart HH Since this facility is considered a production field facility, only HAP emission from glycol dehydration units and storage vessels with the potential for flash emissions are aggregated for major source determinations under Subpart HH. The HAP emissions from these units are below the major source threshold and therefore this facility is considered an area source under this rule. Pre-controlled emissions are, however, greater than major source level, therefore the dehydrators have synthetic minor HAP limitations. Previously, the original dehydrator was exempt from Subpart HH since actual benzene emissions were below the 1984 lb/year threshold. The increased capacity and additional dehydrator result in an exceedance of this exemption threshold and therefore the dehydrator are now required to operate the equipment within the optimum glycol circulation rate, as determined according to the provisions of Subpart HH. NSPS JJJJ Applicability of 40 CFR Part 60 Subpart JJJJ for spark-ignition engines is based on the construction date, date of manufacture, and power rating. For the purposes of 123/0277 Page 3 of 9 DCP Midstream, LP— Enterprise Compressor Station Operating Permit No. 95OPWE103 Technical Review Document— Renewal 2 determining applicability to the provisions of Subpart JJJJ, the date that construction commences is the date the engine is ordered. The rule specifies that for lean burn engines greater than 500 hp, requirements apply to units both ordered after June 12, 2006 and manufactured after July 1, 2007. Three existing engines at this facility, C235, C236, and C238 were ordered prior to June 12, 2006. Engine P018 was ordered after the June 12, 2006 applicability date but manufactured prior to July 1, 2007 and is therefore not subject to the requirements of Subpart JJJJ. The two new engines to be constructed at this facility, C-237 and C-239, will be subject to NSPS Subpart JJJJ, which requires the engines to abide by the standards for new nonroad SI engines in 40 CFR Part 1098. Regulation No. 7 All engines at the facility are subject to Section XVI.B.2, which requires the installation of an oxidation catalyst. Pursuant to Reg 7, Section XVII.B.4, engine P018 and the two new engines, C-237 and C-239, are exempt from Section XVII.E as they are subject to MACT control requirements. Three existing engines, C235, C236, and C238, are subject to the requirement in XVII.E.3.b.(i) to install an oxidation catalyst. However, this requirement is state-only enforceable and less stringent that the XVI requirement, therefore, the XVII.E requirement was streamlined from the permit. Section XVII.C includes state-only requirements to equip condensate tanks with control equipment and has been streamlined from the permit. Section XII.H and Section XVII.D require that the dehydrators be equipped with emission control equipment capable of reducing VOC emissions by 90%. These requirements are less stringent than the 95% control required by the underlying construction permit for the existing dehydrator and therefore have been streamlined from the permit. XVII.D.2 specifies that flares used to comply with Section XVII must be enclosed and have no visible emissions. Compliance Assurance Monitoring The first renewal issuance of the Enterprise operating permit included CAM requirements only for the dehydrator. Based on the information provided to the Division, uncontrolled emissions from each of the six compressor engines are above major source thresholds. Each of the engines is equipped with an oxidation catalyst to achieve compliance with the emissions limitations and therefore subject to the provisions of the CAM program. The second new dehydrator is also subject to the provisions of CAM. 123/0277 Page 4 of 9 DCP Midstream, LP— Enterprise Compressor Station Operating Permit No. 95OPWE103 Technical Review Document— Renewal 2 RACT Analysis The source submitted a RACT analysis with the construction permit modification application. All of the sources at the Enterprise station will utilize RACT to minimize the NOx and VOC emission per Regulation No. 7. The dehydration units, condensate tanks and loadout, and engines are equipped with emission control devices. Weekly audio, visual, and olfactory inspections will be conducted to monitor fugitive emissions from equipment leaks. Greenhouse Gases The potential to emit greenhouse gases at this facility is 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 Enterprise facility. DCP did not identify any pollutant emitting activities in the Enterprise vicinity that are dependent upon the Enterprise 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 construction permit modification received on November 21, 2011 and January 13, 2012, respectively, requested the following modifications: • Incorporate the requests of the April 5, 2010 minor modification. This modification requested that the wording in the dehydrator's CAM plan be modified to allow the use of temperature sensing instruments other than thermocouples to verify the presence of a flame. Also, in this modification the compliance emission factors for engine P018 were corrected to properly correspond with the annual emission limits. • Remove all references to engine C234 and the SVE unit as they have been removed from the facility and their permits cancelled. • Incorporate the modifications requested in a January 5, 2012 construction permit modification application. This requested the four existing engines to be permitted at the same horsepower and emissions limits. This modification also included the addition of two Caterpillar G3616 compressor engines. This increase in compression capacity is accompanied by a requested increase in dehydrator output for the existing dehydrator and the addition of a second dehydrator as well as a condensate throughput limit increase and the addition of four new stabilized condensate tanks. The fugitive and loadout emission were also updated in the construction permit application to account for these changes. An enclosed combustor will be added to the stabilized condensate tanks and the associated loadout. 123/0277 Page 5 of 9 DCP Midstream, LP— Enterprise Compressor Station Operating Permit No. 95OPWE103 Technical Review Document—Renewal 2 • Correct the serial number of engine P018. The source's requested modifications were addressed as follows: Page following cover page • Updated the responsible official and permit contact in accordance with the information submitted with the renewal application. Section I — General Activities and Summary • Revised the description of permitted activities to account for the new equipment. • The serial number for engine P018 was corrected in the summary of emission units in Condition 6. Section II — Specific Permit Terms • The compliance emission factors for engines C235, C236, C238, and P018 were corrected as requested in the renewal application. • The annual emissions and natural gas consumption/throughput limitations were adjusted in accordance with the APENs submitted with the construction permit modification application. • The SVE unit was removed entirely from the permit. Section 11.2 — New Caterpillar G3616 Engines • Provisions for the construction of the two new Caterpillar G3616 engines were added directly in the Title V permit. • Requirements identical to those for the existing engines were added for the new engines. The applicable provisions from NSPS JJJJ were also included in the permit. Section 11.3 — New TEG Dehydrator • Provisions for the construction a new TEG dehydrator were added directly in the Title V permit. • The requirements for the new dehydrator, D-3, were made identical to those for the existing dehydrator, with the exception of minor changes made to requirements applicable to both dehydrators. • The flare used to control VOC emission from the dehydrators was moved to its own condition. Section 11.4 — Condensate Loadout • Requirements for the combustion device added to control loadout emissions were added to the permit. Section 11.6 — Condensate Tanks 123/0277 Page 6 of 9 DCP Midstream, LP— Enterprise Compressor Station Operating Permit No. 95OPWE103 Technical Review Document— Renewal 2 • Provisions for the construction a four new condensate tanks were added directly in the Title V permit. • Requirements for the combustion device added to control tank emissions were added to the permit. Appendices • Revised the CAM plan requirements to allow for a heat sensing device other than a thermocouple as requested. 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 • Revised the language in Condition 1.4 include current conditions that are state- only enforceable. • Updated the AOS for engine replacement with the most current version (10/1/2011). The new compressor engines were also added to Table 1 of Condition 2. Section II — Specific Permit Terms • Language changes were made throughout the permit to make it more consistent with recently issued DCP permits. • The compliance testing condition for the existing engines was removed as initial compliance testing has already occurred. • The requirement to follow the most recent Division-approved operation and maintenance plan for both the engines and dehydrator was replaced with the applicable provisions from the plan. • The inlet gas composition limitations were adjusted in accordance with the GLYCaIc run submitted with the application. • The formaldehyde emission limitations have been removed from the operating permit as the source is already a major source of HAPs. • The calculations in Condition 12 were removed and included under the specific emission unit. The conversion equations for stack flow data and portable monitoring calculations were removed from the permit. This information can be found in the portable monitoring info on the Division's website. 123/0277 Page 7 of 9 DCP Midstream, LP— Enterprise Compressor Station Operating Permit No. 95OPWE103 Technical Review Document— Renewal 2 Section III — Permit Shield • Several requirements were streamlined from the permit as discussed above. Section IV— General Permit Conditions • Updated the general permit conditions to the current version (11/16/2010). Appendices • Added a contact name for the Division in Appendix D. • Added the engine replacement AOS applicability reports to Appendix H. • The CAM plan was revised to include requirements for the engines at this facility which are subject to CAM. 123/0277 Page 8 of 9 '� t 2 _ f) O- 1n If) I ,. 0) '` 1n 0) 0) ' M h : M M M Y V' M V K N M M (D a 0 0 m o a N IO0 V 00) (D 0 rq .:. (60) a) C) C as a 0 w a Q N 110 L. 0 n � M _ (p N- (WD -_-„,- N co co (gyp N O ( N CO O V C 00 '., 04) 0) 0) 0) 0) 0^) 0)) O - - 1- r n N N r (o rt, 0 W u) 1n v) 1n (N vvv aC0 (D . 0 1n 1n 1f) In N- N M o) N U) U) C C C 1c 0 m O 5 C O) W W W v O F W 4 ate_ i N N (No J -0 @ cv (` _ C7C7C7 yL c0 d d (o 0 (6 (6 (6 j N o) co .C AZ Z Z H _ g Z m m N In (7 N N 8 U VJ W W ≥. c N N N T N00(D .0 O _ n co O N M.O 0 0 N M M M O J J .- C y0 - 0 0 0 ›.., a) Q F t. to0 @ ..• .+ ..u 0 moo 72 4"" M in co N co W M O N CO V N- - ;� in in In co co (O (O N- N- N- N- N- N '! 000000000000 N O M N DCP Midstream O 370 17th Sheet,Suite 2500 _ Denver,CO 80202 Midstream. 303-595-3331 January 4,2012 oCEIV£p Colorado Department of Public Health and Environment Air Pollution Control Division JAN -5 2012 430 Cheny Creek Drive South,APCD-SS-B1 \ APCD Denver,CO 80246-1530 \` a 9 bo�ary D Re: Enterprise Compressor Station Kaizen Permit Modification Application Revision to October 25,2011 Submittal Dear Sir or Madam: DCP Midstream,LP(DCP)is submitting the attached construction permit modification application for the Enterprise Compressor Station located in Section 30,Township 3N, Range 63W,Weld County,Colorado. Please replace the October 25,2011 Kaizen Permit Application in its entirety with this revised application. There were significant changes between this version and the old version. DCP would,however, like to maintain the spot in the queue that the October application currently holds. This is a natural gas compressor station which is permitted under Title V Operating Permit 95OPWE 103. DCP has four Caterpillar G3612 SI engines operating at this facility. Engine P018 is rated at 3,550 HP. The other engincs(P005,P006, and P003)are rated at 3,300 HP. DCP would like to replace the turbo packages on the three older engines which will increase the engine efficiency. This change will also increase the horsepower of the engines to 3,550 HP. These engines are all equipped with oxidation catalysts.The emissions for P018 will be adjusted to match the other engines at the new horsepower.These will meet the requirements of Regulation Number 7, Section XVI.B.2. With this application,DCP is also going to add two Caterpillar 3616 compressor engines, and will increase the TEG dehydrator throughput for existing dehydration unit D2 to 110 MMSCFD and also add a new TEG dehydrator(D3) rated at 60 MMSCFD. The condensate throughput will be increased to approximately 6.5 MMgal/yr along with the addition of four new 300 bbl stabilized condensate tanks. The fugitive and loadout emissions have also been updated in this application to account for these changes. An enclosed combustor has been added to the stabilized condensate tanks and the associated loadout. Also,please note that Engine C234 and the SW unit have been removed from that facility. DCP previously submitted cancellation notices for these two sources and requests that these sources be removed from the permit during this permit modification. 1 /7R - '% APCD c S,.tea Z10,aC°% January 4,2012 Page 2 The project modification will provide a net decrease in NOx (-6.93 TPY)and an increase in CO (35.85 TPY). There will be an increase in VOC(37.82)and formaldehyde(8.26 TPY)(See attached table). The application includes the following attachments: A. APEN Filing Fees B. APENs C. Emission Calculations and Supporting Documentation D. Company Contact Information Sheet E. Ambient Air Impact Analysis F. Facility Emissions Inventory G. Process Description,Flow Diagram,and Plot Plan H. Operation and Maintenance Plans I. Regulatory Analysis J. CDPHE Construction Permit Completeness Checklist K. RACT Analysis If you have any questions or require any additional information about the project,please feel free to contact me at(303)605-1716 or WDHille,dcpmidstream.com. Sincerely, DCP Midstream,LP Wesley Hill Senior Environmental Specialist Enclosures www.dcpmidstream.com Emissions Comparison Enterprise Compressor Station DCP Midstream, LP Current Permit Limits Arik" . „, "I aim r '.. - r . §r§+ .9 C235 G3612 SI 47.80 47.80 31.87 2.55 C236 G3612 SI 47.80 47.80 31.87 2.55 C238 G3612 SI 47.80 47.80 31.87 2.55 P018 G3612 SI 24.00 6.17 34.28 2.74 P012 FUG - - 26.91 - P013 Cond Tanks - - 4.30 - CM. P016 LO - - 11.52 - 4MM•al r D2 Deh - - 5.00 - 85 MMSCF/ r 71SHIPAINEWII ti" • o,-. 1 :14 4:71- Total 215.20 197.37 214.58 12.94 Total* 167.40 149.57 177.62 10.39*Not including removed equipment New Confi•uration m a C a W4 r a C235 G3612 SI 24.00 27.42 24.00 2.74 C238 G3612 SI 24.00 27.42 24.00 2.74 C238 G3612 SI 24.00 27.42 24.00 2.74 P018 G3612 SI 24.00 27.42 24.00 2.74 TBD G3616 32.01 36.58 32.01 3.84 New TBD G3616 32.01 36.58 32.01 3.84 New P012 FUG - - 36.44 - P013 Cond Tanks - - 1.28 - 5.6 MM.aI r P016 LO - - 0.71 - 5.6 MM.al r D2 Deh - - 11.95 - 110 MMSCFD D3 Deh - - 5.06 60 MMSCFD Flare Flare 0.47 2.57 - -Total 160.47 185.42 215.44 18.65 -6.93 35.85 37.82 8.26 *Not including removed equipment DCP Midstream, LP do P Midstream. Enterprise Compressor Station Construction Permit Modification Application Submitted To: Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South APCD-SS-B I Denver,CO 80246-1530 January 2012 Revision Prepared By: Olsson Associates 4690 Table Mountain Drive,Suite 200 Golden,CO 80403 CVSLOLSSON Attachment A APEN Filing Fees($1,681.90) $1,223.20-Already submitted with October 25,2011 application 152.90-P018 APEN update submitted with November 30,2011 TV Renewal $305.80—With additional 2 checks submitted with this revision Total$1,681.90—11 APENs Enterprise Compressor Station DCP Midstream,LP PAYEE NUMBER CHECK NUMBER 370 17th 3Ireet.Burls 2500 0000052019 00315455 Denver,Colorado 80202 PAYEE NAME CHECK DATE APCustomerSerme@dcpmidsseam.com 303.605.2219 COLORADO DEPT.OF PUBLIC HEALTH& 12/20/11 INVOICE NUMBER INVOICE DATE NET AMOUNT DESCRIPTION 1211 CDPHE APEN 12/18/11 152.90 CDPHE APEN FEE ENTERPRISE TOTAL PAID $152.90 Pt EASE RETAIN FOR YOUR RECORDS THE FACE•FTHlS.•CUMCNTHASAC•L• E• :ACKG •UN• ■N WHITE A WITHV. =LEFT=E SAND 7 ESVATE-MA-K•NTHE-EVE SESI•E. DCP Midstream,LP JPue.p.n Chase 9ank,Nr. so-o»/ass 370 17th Suet,Suite 230O""Now York Denver,Colorado 80202 » < APCustornerService@dcpcid eamoom : ' : • 303.603.2219 TO THE ORDER OF r�{�r I�'yI��I1' �� A 0000052019 pp 12/20111 00315455 NOT NEGOTIABLE ATTER 120 DAYS 5152.96 COLORADO DEPT.OF PUBLIC HEALTH& ASD-AR-B1 4300 CHERRY CREEK DRIVE SOUTH DENVER,C0 80246-1530 Ch&"'# �� AUTHORIZED SIGNATURE One hundred J fifty two and 90/100 Dollars ■ H•L• :ETWEENTHUJN:AN•F.'EHNGE .0 EATHE.N C•L• ED-.X.C•L• WILL r5A PEA .THEN E.AP EA'. OOO115455o 1 54 5 54' ,:0213043791: 6018951.96e DCP Midstream,LP PAYEE NUMBER CHECK NUMBER 37017th Street,Suite 2500 0000074502 00315207 Denver,Colorado 80202 PAYEE NAME CHECK DATE APCustomerSente I&midstream.com 303.6052219 COLORADO 12/10/11 INVOICE NUMBER INVOICE DATE NET AMOUNT DESCRIPTION ENTERPRISECAT3616APE11/13111 152.90 return check for the APEN TOTAL PAID 5152.90 PLEASE RETAIN FOR YOUR RECORDS DCP Midstream,LP JPIbyn than Balk,NA SO-937/all 370 17th Strad,Suite 2500 bynnaa,Nw Yak Denver.Colorado 80202 ,rz Arawomersar t@dmeiewarao w `° PanENO, fl CJCBATE' t CND 303.605.2219 0000074502 12/19/11 00315207 TO THE ORDER OF 06QVE CII/C;AIVE"tiit'C' NOT NEGOTIABLE AFTER 120 DAYS $152.90 COLORADO DEPT OF PUBLIC HLTH 8 ENVRNMNT AIR POD CNTRL DN APCD SSB1 4300 CHERRY CREEK DR SOUTH Denv � ni®S Denver,CO 80246-1530 tl One hundred ffytwo and 90/100Dollars OOO3 i52O7O 70 I:0 21309379i:1 309 3 791: 601895196e 5 1960' DCP Mftktrwm,LP CHECK muanom vo 17th swat suer,isoo c t < 000007�Q NO.90d2mD , MYEE NAMEpEC1�)dll7rf COLORADO OW11 ' • WVOICE NUMBER WVOicE DATE NE'I1AMOUN T DESCRIPDON Erp U UD9r 03/2111 �59t70 'relum check to Wei H ' • l L , / /, 1 r .• r i 1 0 , , TOTAL.PAID $4511.70' r •tJ _ Arum rat tone+ _ _ r + • .V t.^4 1•Viill~ . gF' it. {.�,/• st .:4,..,.,..1‘. ;„ L, 3. 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PLEASE RETAJN POR YOUR RECORDS "• :; CII.FNJT HAS 1 Call ID riacgc,,OU'JD(3,1v.+1•( c. . ::a';;ifl �'-. `.�C F•»ERS AND ATRUE WM :.0.1APK O'JTtIF 1 F. -k f'?rt'.• so-13.1,213tftela k f/i]] �'. • � C901' `. I 'n0?t!d01lO - 0Q0007 l U151u 1 00303925 E. rasa �%'�� ; - NOT NZOOT ARZArrER130 DAY. .. **•si+ts6'�z;�p 'COLORADO ;. . . - DEPT OF PUBLIC;HLTH:8 ENVRNY$'T_. . • AIR POO CNTAC OI fAPCD SS8t.,.. Den CHERRY)248-153 DR 9(WiFi 1� Denvert�O 80248-153D One hundred f+fty two and 90/100 Dollars ED s3 CINkTURE I, ~ +4 LI ETYtLEHYHJt"_ �;gpFO FFIN E .6n: F. 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Y Y ; w f.' i s 9 Y.. 3 3'l'y ': 71. &• 3 O q a ift 1 in ti o eo y; H It,-, „ o Oias . a `Y' 2 a E I it 3 c eiCi .5 "y Attachment C Emission Calculations and Supporting Documentation Enterprise Compressor Station Compressor Engine Emissions Calculations DCP Mldstresm,LP Enterprise Compressor Station CaWplllar 63312 51-Commoner Engles(4 Simko Lars Ban%3,5506% Engine*P015,C236,C.23%end C-231 Urn 0.45 350505 El 0.700 153.04Ir in 06 um 6 bat 24000 mniblufiv Otv4m&Main W 140 FFlak 11I05.3 MIn 16[45.Faille. 15501 mm50E r 'Mmu4044a eh rate]term V rang. **WO hdlltl Ealubt Cak01 W Ia Umim044 Fusion Fan P.4.W Enactors cesspool Emission[fled 0001501141 Gkakln bNJii (bM'n 1bn}a NO5' 0.70 041404. 2444 0..70 yMp111 24.03 CO. SS0 SO O. 05.70 0.00 Wm-% 27.42 0000 015 Agnes 21052 0.70 oehow 2444 PM' 0.03645 Moth% Im 0 NEd9 klmeb 106 503' 102604 IbA05031.4 0.06 5.05E-04 Mmes, 006 'Engine 8Galata%dors 'Unc."1.4.WSo Som.fro.4Ni.4.5.0014500)i3Orns/rtm EPA'.AP420m0412,TW322.Mn PM.slits,Now 6,00,3..we.mtlnts atl 01Ye54. III Watts Wan tabirlatkent Ps4W E4Y.li Conn Etlog bliib[5n1Yii DA MSS'' bloats OW 6.545,Scar twosome Mel % IWM se moll 1122-TebaaniNaa <4.0'860660.1441 EPA <2 44144 15.41 20% 4.20 A m 112.1MIbiWc 43.13266 IMnmBo EPA 4733EM 0660 60% 3.34 A W 1.3.6404n 2570,041Nmr@b EPA 641EM 406.13 W% 76.05 A m I,3Ombwgsi <$M6m lbllwau EPA 0034E-04 105 50% 171 A W 334'Thn4N/4.5a. 2.60004 k'mas EPA (WEm i 152.50 50% 9.N C 1442 20A6m1 aW404 3326-05 MmeM 207644 •444 50% 340 A04n4MMa 1]6EL0Mw6M EPA 500605 409 000 013 Ailwlmµia 554.00 E1.0.. EPA 1.332644 11.10 W% 044 Aemaitinnie 006403 M4nel EPA 101641 .417@.61 50% 576.70 A 50 -}clown 5.14E-03E1mIBE EPA 1.21601 01W0M 50% 54027 • W 6..114 4100041Mmne% EPA 10069E 44.04 W% 0625 A 9 BeraVEWnwt. 100E-071Mrvr6E EPA 2W[p 1 0.03 50% 0.02 M¢� 0.55011EW,Bu EPA 0.90%00 .0 004 OaanlG,Rl 4.14EOIIMnR4 EPA 505546 0005 50% 04 O 1tl,nL1 3.1]64 MmBE EPA 6052695 0N.67 50% 34.9 0 1000 C4EiITMnnMtls 1]1fr95 M,r,BE EPA 4442604 a1.R 50% 344A 0541406,1 1705E-06MnBE EPA _ al.%E04 109 W% ]9 A W LMYdOm e$55E066soEth EPA 10342604 4sW 00% ]W A 50 Chow 01Y-C7MmsBE EPA 142606 40.15 60% 007 EtMnaia 5.4E-03MnneE EPA 053E4 0635 W% 4.17 0 %CC Ethylene 01Wn14Y 4...a.08 1666E EPA 05,0603 45.31 00% 444 A 50 P10 5M%4 01.11405 IE1mEE EPA 200E40 0073 50% 0.12 s 07113WfinBE EPA 1214.04 1.10 50% OW wmeEsnYY 0107Y•577570.,,(. 3..1]EKO 4W.W W% 544.05 A 00 1LN4 EHEC3MIn60, EPA 0ME01 1 57650 #A 93.06 C 1000 IY0,eis Q4M. 8, 46 MInS% EPA 4W4 E1421 50% 210 A 50 N4MWi,a 7N[05 WaNW EPA 1752603 4154 00% 74 C 1003 talon 1.11EM Wmns% EPA 200502 19339 501E 115.4 C 1033 PAM [[.0.41E1mes EPA 040604 0000 50% 253 A W nma,avii 1042605 Emcee% EPA 210%04 1110 a0% 100 _Frond 2.40E10%mope% EPA a 544 W% 952 0 Teo fAY4 I.YIFIe WmnBE EPA 2]0%91 070E44 0 09 Y% 0.04 �MYM 019E-0S Vm,1B4 EPA 001]2604 _ 149 Wm 2N 0 1000 - S.Otlbien Lads Pima% EPA 5.10000 40.52 50% 00, A W S OnM 450E-04 Wm*B5 EPA 0.75%03 15377 50% 4144 ae C 0 CHY6a 1 45.605645045, EPA ]60501 4 11 00% 161 A 50 Q Pe 1NE94161m,iE EPA 4422603 0$06 50% 114 L WOO 1 1K m - 300 3100147 7523.41 •05.4415d iamb,Mere torn 4.inb,4wimMIS)apnea Iran EPA'%AP-43 Cbin 3.2 Tab SM. 'Mi*e errs lot mMEWe nal5M P,E1n ,,bon IXbat M,4Fn Ito.3. DCP M4bean LP VYA'2 Compressor Engine Emissions Calculations DCP Midstream,LP Enterprise Compressor Station Cetorpiller G3616 SI-Compressor Engine(4 Stroke Lean Bum,4735 HP) Unt Rating e. 4,73570 BSFC: 7,481 beyfghr Maximum Heat 8Pa 35.42 mmbumr Ceraeg Schedule 8.760 Styr Frill; 1.138 bWsat knw Fuel Use 27308 mmedyr ▪MBnurnnnlm(e site rated horspowrnung. Ginn Pollutant Emission Calm/None Uncontrolled Emission Factors Mai Er iss Controlled Emission Facers Condoled Emissive Pollutant (tedyr) (tonfyr) NO,' 0.70 gMphr 32.01 0.70 glphp%r 3201 CO' 2759Nhp-hr 12574 0.80 oMphr 36.58 FOG' 0.70 plMpin 3201 0.70 e'Thp4r 32.01 PM° 991E-03IbdmmBL 1.55 9.99E-03IpM1nmBb 155 50,' 5.88E-0e INmmBb 0.09 5.88E-04Iphnm8N 009 'Engine manuteeue%embebn factors °Uncontrolled emission fadat from 4epoka,Manbum(ISIS)engines from EPA's AP-42 Chapter 3.2,Table 3.2-2.Nob PM emission Motor holes both condensable and Bnemde. Nar.Crlterle Reportable Pennant Calculations Potential Emission Control Efficiency Centralia Os MNlm%' Pollutant HAP Emission feelers' Data Source (M%r) EONS % (bf4 Sin ably) 1,1,2,2-Tebachlooe8gne <4.00E-0S lbMnmBL EPA <142E-03 <1291 50% 621 A 50 1,1,2-Tddi roemena <3.18E-05 NmmBL EPA <113E-03 <967 50% 4.93 A 50 — 1.3-utadlem 2.67E-04 MImmBb EPA 948E-03 '1205 50% 41.43 A 50 1.30itbmpmele <2640-05 tlmmSW EPA <9.35E-04 <8.19 50% 4.10 A 50 2,2,4-Tnlmetrylpenbro 2,50E-0ItlmmBb EPA 8.66E-03 <77.58 50% 38.79 C 1000 24leIiylregienM a 332E-O5INmmBN EPA 1.18E-03 <10.30 50% 5.15 Acortilens 1.25E-061NmmBN EPA 4.43E-05 <0.39 5094 0.19 Acenmhhyiene 553E-061NmmBN EPA 1.96E-04 <1.12 60% .. 0.88 - Acbedenyds 8.385431ymm6N EPA 2.96E-01 4253415 50% 1297.06 A 50 Aerobia 6.14E-031NmmBL EPA 182E-01 <1594.97 50% 797.49 A 50 Bewrle 141E-04tlmmBW EPA 1.56E-02 41311.53 50% 68.27 A 50 Beroo(b)MmnMee 1.66E-07 tlmm9W EPA _ 5.88E-06 <0.05 50% 0.03 Benmletmene 41547tlmm6L EPA 1.47E-05 <0.13 50% 008 BwmNWb.operybne 1.14E-07 tlmm6L EPA 107E-05 <0.13 50% 080 Biphenyl 212E-04tlmmBL EPA 7.51E-03 <6578 50% 3289 C 1000 Carbon Tetrachlb,e <3.67E-05INmmBtu EPA <1.30E-03 '11.39 50% 569 A 50 Chbmbennene 4301E-05jNmm9 -1u EPA <108E-03 <8.43 50% 4.72 A 50 Chloroform 42.66E-051-hpsmaN EPA <101E-03 <8.84 50% 4.42 A 50 Chrtsene 8.83E471tlmm8N EPA 2.45E-06 <0.22 50% 0.11 E6ntbelzeie 3.97E-051tlmmBN EPA 1.41E-03 <1232 - 50% 6.16 C 1p00 Elan*DIbromIch 44.43E-05 NmmBW EPA <157E-03 <13.75 50% 6.67 A 50 Flumailee 1.11E-06dmmBW EPA _ 393E-05 <0.34 50% 0.11 Fiuonne 6.67E-0BtlmmBW EPA 2.01E-04 <1.76 - 50% Formaldehyde 040,pdMpN Man( 4.18E400 436577,86 79% 7681.35 _ A 50 Methanol 2.50E-03 ltlmmBtu EPA 8.68E-02 <775.76 50% 387.86 C 1000 Methylene ChOMe 200E-05itlmmBN EPA 7013E-04 <6.21 50% 3.10 A 50 Naphymlere 7.44E-05N4nmBW EPA 264E-03 <2303 50% 11.54 C 1000 n-Hens 1.11043 ItlmmBW EPA 3.93E-02 <344.44 50% 172.22 C 1000 PAN 2.69E-05INmTBW EPA 953E-04 <535 50% 4.17 A 50 Pheamkene 1.04E-05 NmmBW EPA 3.68E-0/ <323 50% 1.61 Phenol 240E-06 tlmm8W EPA 8.50E-04 <745 50% _ 3.72 C 1000 Plum 1.36E-08tlmmBN EPA 482E-05 <0.42 50% 0.21 Styrene <2.36E-05tlmnBW EPA <8.360-04 <7.32 50% 388 C 1000 Tebxhlaoetxm 2.48E-06NmmBW EPA 6.78E-05 '0.77 50% 0.38 A 50 Toluene 4085.a I&mm81u EPA 1.45E-02 <128.60 50% 8330 C 1000 Vinyl Chime% 149E-0SN5nmeN EPA 5.28E-04 <4.62 50% 2.31 A 50 kkleiee(m,p.o) 184E-041NmmBW EPA 352E-03 <5710 50% 28.55 C 1000 TOTAL — 4.44 424433 10110.58 — — •01034,%850 emisaan iecias from 4-stoke.kamoum(4StM)engines from EPA%AP-02 Chiller 3.2,Table 323. d Deminimb bids ter rpannbb'ManbN pollutants.per Cdaedo Regulation N0.3 k !755922 ! | - 1 $®I!\■!! t !$`§=E «^m: ! J - i I i;■;9■■q k / a l253l535 i ! ' 'r'„ z z 1,F .11,- ■ | |! ihiPl§ § J! N [ ' ! | ! !! 5:;.::, � ' 'i !I) f | fI) . f! i � Ii |f! !!!i!, 2 := il itli/A\ig:§1k | | ! ! =,a� ! , . 4FBK«:k2 &! !' iii:ja ;I ■ ,■ |§■|l= :�zl; t;>§•§ ` || . ! _ 5 fi i 8| $1k;k . g : @PP@ | kii-t. �W Pi ij ! |�` !!!~121'.-i iit ! ! |-| ji& uIitIIiII1!IHH; ,!!e.t »wl , 5 i i § ) 01: ::: :__::::::::::::. ii|`.§':§„;' .. . ;_.., . ! Iz !. :. . <.. ,,._..,, / RbQRhBGRa lui W m §g2§g li li ||||||||||||||||||| | .1 ......|......|§!!o! ■ iie2RRRReRRe II\�©®©©a®©©g | I ! 1.......... .. .. .. . ! .......... ...,_,, .. | ! ||i,.,;; ;;; ;,;,;;I l; ! 111! ;;;;;;;; ;;;g;;; ui 5| | BQ§H".... III 1 #9Qg gQ2HH I i !!!! RRg!§! 1E| /1| | ` | , 1 II \\ ° h h/\/ / Illi ° hn II;,. J ! § | mace | g ■ I | |||§|||!|| 1 !1 @RRe | i !,!,!!,E ! z i_I 1i.; ! ||l|;|| !|| |I ! in 4E1229 OO iii .1� i!� . `i .114 !|!|;!|! |, 'Well � !!.| II , lig! IIIAIIIN IA5 I | . !` |||| ,, ! !,. 1 !;,!!!!;|| pgla x G , | |'`''! _ g| }I|ia �|| 280000 , | | ill i 'i'!! I III 1 i� � �ill � !|| . ■ t|!,|'� | iiit" if! 'f! '` 1|||!,a!!|.| ||!| `' ! .,|! ';,!!fi!!!!!! ||. <!|..ic. |Sf I . § § eexeaxewe» /,| RR4RaRRRR, S|i;-t§ |||!it|!§4(|0! ;I)i!||;|||;§;§l;;;!§|| | ,.,..,g, ,, ,,,,, , , ! .. . m§|||; |■|� ■|| ! RRwaahhR6|6| \ ea . - ....j ............. / w4qsweseeag ` I lwee99 © & a, . li. ......... . . .. _! 1 !| ,.,,.,,... .|m.-m? 1 | |||||■|■■■■|■|||■ ■ ! ||[||■ill"1!"!!|| |. . |............." oo !!i . . „ | i !! ! . | ! | RRRg8R5RR@ | /` � , , ae9eegRRg ! . „ | { . I , 1 \I IW11;1111111;4_1110 1 |i to ; \§ | ! || 1,| ! !i|| N. .,w , I A Dehydrator Flare Emissions Enterprise Compressor Station DCP Midstream,LP Supplimental Fuel for Flare 2009 MMBTU/hr Daya/mo MMBTU/mo Jan 0.355 31 264.3 Feb 0 250 28 168.0 Mar 0 344 31 256.1 Apr 0.261 30 188.0 May 0 125 31 92.9 Jun 0.117 30 84.5 Jul 0 146 3' 108.7 Aug 0.146 31 108.9 Sep 0.140 30 100.8 Oct 0.172 31 128.0 Nov 0.159 30 114.4 Dec 0 139 31 103.5 1718.0 MMBTU/yr from assist gaalplot(2009 throughput higest of last three years) 2000.0 MMBTU/yr Round up assist gas to be conservathre. 8,344 MMBTU/yr from D2 condenser overhead abeam from bec 15,2011 GtyCalc 3,528 MMBTU/yr from 03 condenser overhead stream from Dec 15,2011 GIyCalc 13,871.8 MMBTU/yr .Erntsslone • a �fryrn,, NOx 0.088 0.47 CO 0.37 2.57 AP-42 Table 13.5-1 Fugitive Emissions From Equipment Leaks Enterprise Compressor station DCP Midstream,LP LIZ:= "!+� i 0 '.; —MOTIIMI o IIIIIIIIMIMfl X0000• Orrr_- r'-n MIlli:S 0 X000®0® • 2.00E-04 nip®nil INIMEar .fist.nIll®' r]MIIMKED flE® Qv©MMDE '<' 2.00E-03 ail 0.00naE Irrilia 1.30E-02 2.40E-03®' MIIIIIIflCa :AC 250E-03 4.50E-03 Mir ni®i EiniF MENElaP MiiiMriaiam .r5 Gas Anal I. M41W10 16.0 73.610 11.78 5273 • 5581% Ethane 30.0 13444 4.03 15.06 19.11% Tat Me1NEt 87.053 155 70.9 74.92% Praaam 44 0 5.763 2.54 11.35 12.02% I-Butane 58.0 0.819 048 2.13 225% nBulrne 58.0 1.874 1.09 4.87 5.15% IPe Lane 72 0 0.501 0.36 1.61 1.71% n-Ps,Wa 72.0 0.538 0.39 1.74 1.84% Other Means. 86.0 0.359 0.31 1.38 1.46% nMewM 860 0.112 0.10 0.43 0.46% Benzene 76.1 0.025 0.02 009 0.09% Toluene 921 0.020 0.02 0.08 0.09% EMyeennne 106.2 0.000 0.00 0.00 0.00% Wynn 106.2 0.004 0.00 0.02 0.02% Tole VOC 10.018 5.3 23.70 25.08% Gabon Obxltle 44 0 2.590 1.14 5.10 Helium 4.0 0010 0.00 0.00 Oxypen 32.0 0.010 0.0D 0.01 N • en 28.0 0.320 0.09 040 Marta 19,2011 On OCP Midstream.LP 127302011 Gem Service spsdatlan Light Liquid Service Seedefon =7a iiiii=iii 0.0000an G ':I, 00,1 EIrri Sir IIMIEW alE =MMUS S=SE ow o.0000 am S ow EZIZINS2ISEI SIM I=SIIINIMI 0.00 0.00 CrA7IICSI 000%IIM!".O 0.00 SlE EaSEIM SZEI SEE EEEEfll SIE 000ISS Sir SO= IltIMES- 000 0.00 flI ?ti. E=SIIIM SE 000 0.00 ��' al 0.00 0.00 tra WISE)SMEGI .l-a in --aiinialnanE SISEI SIII 0.0079 0.0345 ®na]SEil irl!!! SID2I 0.0075 0.0330 BrIMI=IS SLID SE morn ornms 000% 0.(100E 00007 EG=ZEIMMII®' 0.00 0.02 0.02% 0.001.halm =Mina®ial al51 _ ... •Assume 100 e1%VOC to 0e ca16enebn.HM et%hen Liquid Mee Ma Tool HAP% 029 110 0.72 3.14 Taal VOC 3.33 14.58 6.32 111.44 aNeim 0.16 0.68 0.29 1.71 Seems 0.02 0.11 0.06 026 , Team 0.06 027 0.15 005 Egylnanzee 0.00 0.02 0.01 0.05 Xylem* 0.04 0.16 0.10 034 A)Capa.M—heed upon API Name.4M prate q and API Publication*MS(TS" B)EPA*melon an aeYW Rem'Retail 6b Equipment 006 Ent.Ma wins:EPA RIYtWn lb.Ii m4*417 • OCP MCWeam,LP imam 19 ! 2 I||!!|| |!!!!!! t 1„,„ j >....,. ! |,;,,,,; \see .§„ f 6 ' ! §\) | 1 � ||! - f § | , t`' | ! | ` .. & i al liii |1| I u` 9 p_ ii I I \ §f §2� q III | R p| | /| r! ■ ! , || ■ ! •l gt` || 2 ! " '! I I �� 1;1 hi Ja| | ■ ! f| § 0W I5 gr...- 'vs !2 a cn Z a! § A ) 2.o k ! JJ �§ o # ) � k \( ; U \ � - ( 3 /) ; E { \� ` . ) ; ! |-5203 < 0{ � !! @ # a 0_CC III / }E ) . .e'"2 il O 2 ( § k k �k Li- - , � 2 | � to a ; ! 2 2!| f$ ! 0 . |§a ) �0< !| i ,! 2320§ @ ! §' § r�f #`§!® - - § | � \!} % \ } | I 3 } / - . N | � > > | , ! « | 7 ! / » , ! | !| ��` ! ,| ; \ i\ \u) �22 � \ }j } / g> m > ) k 5 Enterprise Compressor Station Summary of GHG Emissions DCP Midstream, LP Combustion Sources 87,191.3 Blowdowns 85.1 Rod Packing Venting 55.75 TEG Dehydration System 102.32 Total CO2e PTE 87,332 DCP Midstream,LP 12/30/2011 ei ei = � attb la , ak \ ! 2a » n .O IN el JJ2 & $ § ; @ k 0 tea ( - $ ) / co - / ; s ° f ) ` \ { j / § CO LO CM § a f co r- E — 03 v: W N o 1 in k a O § \ S % s2 ) ! % tss mmmm m � ( � � \ � k � f ; I ; ; 2222 Bt ! . m2 0000flm § f N LO \ „ � , � , r « 5 / IT a i.' \ ) ) \ tot cti ( ( 4 Bk � l � = f ti (! � - � ##01 0, _ ; ° § ! k � ) ] \ \ ! § k § 0 k2i / � CO ; .2 U. E O 000 v woo ) ) w cn www00 § \ ) a. aa / 2 § \ { \ \ Enterprise Compressor Station Compressor Slowdown Emissions DCP Midstream,LP Carbon Dioxide 44.0 2.647 1.16 5.57 Helium 4.0 0.006 0.00 0.00 Oxygen 32.0 0.000 0.00 0.00 Nitrogen 28.0 0.294 0.08 0.39 Methane 16.0 77.493 12.40 59.33 Ethane 30.0 12.696 3.81 18.23 Propane 44.0 4.621 2.03 9.73 i-Butane 58.0 0.571 0.33 1.58 n-Butane 58.0 1.077 0.62 2.99 i-Pentane 72.0 0.217 0.16 0.75 n-Pentane 72.0 0.203 0.15 0.70 Other Hexanes+ 86.0 0.000 0.00 0.00 n-Hexane 86.0 0.175 0.15 0.72 VOC wt% 16.47 % Methane Wt% 59.33 % CO2 Wt% 5.57 % Volume @ 60 psi 3430.0 cubic feet/event Vent toNblowdown #/yr TPY VOC TPY Methane TPY CO2 TPY CO2e P018 0.094 12 0.19 0.67 0.06 14.2 C235 0.094 12 0.19 0.67 0.06 14.2 C236 0.094 12 0.19 0.67 0.06 14.2 C238 0.094 12 0.19 0.67 0.06 14.2 Cat 3616 0.094 12 0.19 0.67 0.06 14.2 Cat 3616 0.094 12 0.19 0.67 0.06 14.2 Tota1OO2e r' I.i 5.1 DCP Midstream,LP 1/4/2012 Enterprise Compressor Station Recriprocating Compressor Venting Emission Calculation CH4 CH4 CO2 CO2 Total Emissions Emissions Emissions Emissions Emissions Compressor (scfli') (MT CO>e)N) (scfli'l (MT CO,e)I°l (MT CO2e) Compressor 1 9,480.0 8.4 527.0 0.0 8.4 Compressor 2 9,480.0 8.4 527.0 0.0 8.4 Compressor 3 9,480.0 8.4 527.0 0.0 8.4 Compressor 4 9,480.0 8.4 527.0 0.0 8.4 Compressor 5 9,480.0 8.4 4 527.0 0.0 8.4 Compressor 6 9,480.0 8.4 527.0 0.0 8.4 Total 50.4 0.2 50.6 (a)40 CFR Part 98 Subpart W,Equation W-29 mi 40 CFR Part 98 Subpart W, Equation W-36 a a m n mI ' ry O O ry n" \ O U Y ea ~ ry C E A 3I „ g k a 0 o c .� o n rn n U ag fa: m al m W N m N O n a ry O C a ° L L a E L L pW a a as , 2 m m units u 15 m `B m o i a, c e o .y I W 15 m L pU 2 Q 2 T N N m d in In b • a ^+ r .rvi n m o▪ rtri m M .. - .1 ry ry E - 3 v 2 2- 0 a a a ! . ei PP a• a V• NC1 F p 2 O . in O V H " ry M C C c D a y a BM a e a a a a a in � C E Sen 01 k = • n m: al III - - d ESE `a Qry Qu a 1WE 00.. _ o f o f O N 00 00 x I Gas G3612 CATERPILLAR Petroleum 3195-3550 0383-2647 bhp kW Engine 900-1000 rpm ;;,r } -Plc/ • . .1`.: - - CATERPILLAR° ENGINE SPECIFICATIONS V-12. 4-Stroke-Cycle t:-ti Bore—in (mm) 11.8(300) k� '1 (I ii d e21i11'1 . Stroke—in (mm) 11.8 (300) Displacement—cu in(L) 15,528 1254.41 ;147.i i Aspiration Turbocharged and Aftercooled , ; ayg Capacity for Liquids—U.S. gal(L) t. a_ Jacket Water Circuit' 177 (669) '' l Aftercooler Circuit' 17 (64) Lube Oil System(refill) 272(1030) Shown with Package Shipping Weight Optional Equipment (Dry)—lb(kg) 55,300(25 084) 'Engine only FEATURES • FULL RANGE OF ATTACHMENTS • G3612 • Wide range of bolt-on system expansion • Low emissions attachments,factory designed and tested • Broad operating speed range and • UNMATCHED PRODUCT SUPPORT ability to burn a wide spectrum of OFFERED THROUGH WORLDWIDE gaseous fuels CATERPILLAR DEALER NETWORK • Caterpillar Advanced Digital Engine • More than 1,500 dealer outlets Management(ADEM Ill)control system • Caterpillar factory-trained dealer with detonation-sensitive timing control technicians service every aspect of your for individual cylinders petroleum engine • Robust diesel strength design provides • 99.7%of parts orders filled within 24 prolonged life and lower owning and hours—worldwide operating costs. • Caterpillar parts and labor warranty • TESTING • Preventive maintenance agreements • Prototype testing on every model: available for"repair before failure" - proves computer design options -verifies system torsional stability • Scheduled Oil Sampling (S•O•S°") -functionality tests every model program matches your oil sample • Every Caterpillar engine is dynamometer against Caterpillar set standards to tested under full load to ensure proper determine: engine performance. - internal engine component condition ■ WEB SITE - presence of unwanted fluids • For additional information on all your - presence of combustion by-products petroleum power requirements,visit • SINGLE-SOURCE SUPPLIER www.cat-oilandges.com. • Caterpillar: —casts engine blocks, heads, cylinder liners,and flywheel housings — machines critical components — assembles complete engine �e"ar„ Ownership of these manufacturing 4_____ CE processes enables Caterpillar to produce a ISO 900'1 high quality,dependable product. CERTIFIED • Factory-designed systems built at Caterpillar ISO certified facilities (EXWQS14-01 • WITERPILLAFI G3612 GAS PETROLEUM ENGINE FACTORY INSTALLED STANDARD & OPTIONAL EQUIPMENT SYSTEM STANDARD OPTIONAL Air Inlet Air cleaner—standard-duty Heavy-duty air cleaner with precleanors Inlet air adapter Heavy-duty air cleaner with rain protection Charging System Charging alternators Control System Caterpillar ADEM III control system Custom control system software is available provides electronic governing integrated for non-standard ratings.Software Is field with air/fuel ratio control and individual programmable using flash memory. cylinder ignition timing control Cooling System Jacket water pump Expansion tank Jacket water thermostats and housing Flexible connections Aftercooler pump Jacket water heater Aftercooler water thermostats and housing Single-stage aftercooler Exhaust System Dry wrapped exhaust manifolds Flexible bellows adapters Vertical outlet adapter Exhaust expender Weld flanges Flywheel/ ME No.00 flywheel Flywheel Houshp SAE No.00 flywheel housing SAE standard-rotation Fuel System Gas admission valves with electronically Fuel filter controlled fuel supply pressure Gas pressure regulator Flexible connection Low energy fuel system Corrosive gas fuel system Ignition System ADEM III control system senses individual CSA certification cylinder detonation and controls individual cylinder timing Instrumentation LCD display panel monitors engine Remote data monitoring and speed control parameters and displays diagnostic codes Compatible with Cat Electronic Technician IET) and Data View Customer Communication Module(CCM) Display panel deletion is optional Lube System Crankcase breathers(top mounted) Air or electric motor-driven prelube Oil cooler Duplex oil filter Oil filter LH or PH service Oil pan drain valve Lube oil makeup system Mounting System Engine mounting feet(six total) Mounting plates(set of six) Power Take-Offs Front stub shafts Protection Electronic shutoff system with purge cycle Crankcase explosion relief valves Gas shutoff valve Starting System Air starting system Air pressure reducing valve Natural gas starting system General Paint,Caterpillar yellow Engine barring device Vibration dampers Damper guard LEHWOB14-01 G3612 GAS PETROLEUM ENGINE CATERPILLAR' TECHNICAL DATA G3612 Gas Petroleum Engine—900-1000 rpm DM5312-00 DM5310-00 Engine Power @ 100%Load bhp(bkW) 3195(23831 355012647) @ 15%Load bhp(bkW) 2397(17B71 266211985) Engine Speed rpm 904 1000 SCAC Temperature °F(°C) 130(54) 130(541 Compression Ratio 9.0:1 9.0:1 Emissions* NO, g/bhp-hr 0.70 0.70 CO g/bhp-hr 2.50 2.50 Total Hydrocarbons g/bhp-hr 5.85 6.15 Fuel Consumption @ 100%Load Btwbhp-hr(MJ/bkW-hr) 6,570(9.30) 6,780 19.57) @ 76%Load Btwbhp-hr(MJ/blcW-hrl 8,805(9.53) 7,050(9.98) Fiat Balance Heat Rejection to Jacket Water @ 100%Load Btu/mn(bkW) 32,168(566) 36,195(635) @ 75%Load Btu/mn(bkW) 28,721(505) 31,271(550) Heat Rejection to Aftercooler @ 100%Load Btu/mn(bkW) 21,222 1373) 26,509 14661 @ 75%Load Btu/mn(bkW) 9,333(164) 14,525 12551 Heat Rejection to Exhaust @ 100%Load etWmn(bkW) 134,721(2369) 154,673(2720) @ 75%Load Btu/mn(bkW) 107,091(1883) 123,769(2175) Exhaust System Exhaust Gas Flow Rate @ 100%Load cfm(m'/min) 20,634(584) 23,461 (664) @75%Load cfm(m'/min) 16,100(456) 18,5541525) Exhaust Stack Temperature @ 100%Load °F(°C) 846(452) 858(459) @ 75%Load 'F 1°C) 807(464) 878(470) Intake System Air Inlet Flow Rats @ 100%Load cfm(m'/min) 8,627 1241) 9,5981272) @ 75%Load cfm(m'/min) 6,542(185) 7,477(212) Gas Pressure psi IkPal 43(295) 43(295) "at 100%load and speed LEHW0a74-01 CATERPILLAR' G3612 GAS PETROLEUM ENGINE GAS PETROLEUM ENGINE 186.42 93.88 (4735.1) f -'--(2379.5)_.._.____ • ri 126.77 ✓ �! Il :_ r!a (3219.9) l • • . O }'sl r �iCi . . I • � 1 AN ' t ` DIMENSIONS Note: General configuration not to be used Length in Imm) 188.42(4735.1) for installation.See general dimension drawings for detail. Width in(mm) 93.88(2379.5) Height in(mm) 126.77(3219.9) Shipping Weight lb(kg) 55,300(25 084) RATING DEFINITIONS AND CONDITIONS Engine performance is obtained in accordance Conditions: Power for gas engines is based on with SAE J1995, IS03046/1, BS5514/1, and fuel having an LHV of 905 Btu/cu ft 133.74 kJ/L) DIN6271/1 standards. at 29.91 in. Hg 1101 kPa)and 59°F(15°C). Fuel Transient response data is acquired from an rate is based on a cubic meter at 29.61 in.Hg engine/generator combination at normal (100 kPa) and 60.1°F(15.6°C).Air flow is operating temperature and in accordance with based on a cubic foot at 29.61 in. Hg(100 kPa) 1503046/1 standard ambient conditions.Also in and 77°F 125° C). Exhaust flow is based on a accordance with SAE J1995,855514/1, and cubic foot at 29.61 in. Hg(100 Pa)and stack DIN6271/1 standard reference conditions. temperature. TMI Reference No.:DM5312-00,DM5310-00 Materials and spedllcatione are subject to change without notice. The International System of Units ISII is used in this publication. LEHW0e14-01(0.011 Printed in U.SA O2001 Caterpillar Ni rights reserved. DCL DCL America Inc. 12620 FM 1940 tat A4 Sex 0 560,sonmo,7% 77065 *1:877.4974759 Far 2L16054L98 f.-ImSF iarog*la nericrean To Wes Hill Phone DCP Fax Date Dec 29th 2011 Email RE: Emissions Performance Estimate ENGINE DATA Engine model Cat 3612 LE Power 3002 hp Fuel PQNG Exhaust Flow Rate 35,525 lb/hr Exhaust Temp 882 F CATALYST SYSTEM DATA Catalyst Model 33.25"x24"x2" Catalyst Type Oxidation - A Number of Elements 4 per engine Cell Density 300 cpsi EMISSION PERFORMANCE ESTIMATE Exhaust Gas % Destruction Component CO 93 VOC 80 CHOH 80 Regards Brendan Filby General Manager DCL America 925-808-5223 Confidential Communication DCL DCL America Inc. 12620 EM 19611M,Ste A4 Box s 560,.aunton,72 77065 Td:S77-897.9799 Au,251405-5858 a-Mail ithedtLmrics.asa QUOTATION To Eric Edens Phone DCP Fax Date Dec 20th, 2011 Email Quote No.: 13-2032 RE: (2) Catalytic Silencers for CAT G3616 Estimate ENGINE DATA Engine model Cat 3616 Power 4735 hp Fuel Pipeline NG Exhaust Flow 32336 acfm Exhaust Temperature 876 F CATALYST SYSTEM DATA Catalyst Model RC5x4x1-30 !GS trunnion mount Catalyst Type Oxidation Number of Elements 10 Cell Density 300 cosi Approx. Dimensions Drawing to follow Connection Size Recommended 34" Approx Weight 12500 Lbs Approx. Pressure Drop 5.5"w.c. SILENCER SYSTEM DATA Silencer Grade Industrial Approx. Attenuation 15-20 dBA EMISSION REQUIREMENTS Exhaust Gas Engine Output (g/bhp-hr) % Reduction Component CO 2.50 93 HCHO 0.4 79 NMNEHC 0.5 65 This quotation is subject to DCL's standard terms and conditions of sale attached. Copies of limited warranty statement are available from DCL upon request (DCL doc. No. X0010- 0000-56). Confidential Communication nom• Da Inc, wry �.I*._�. ....,.....d._. Page: 2 of 4 MODEL DESCRIPTION; RC^' Model 5x4x1 industrial grade catalytic silencer equipped with (1) catalyst layer with room to expand up to 3 layers, side loading access door, 5516 steel construction and ports per customer requirements. Standard high heat black paint. • Element Dimensions: 600x300x94 mm (each full block) • Effective length of element: 89 mm • Cell density: 300 cpsi • Catalyst volume 14L (each) • 10 Elements per layer • Approx overall height 224" • Diameter 72" • Wind Load 125 MPH S516 steel catalyst centerbody construction, carbon steel silencer body construction Unit Price: $ 57,936.00 USD Quantity: 2 Lead Time: Ships 10-12 weeks after receipt of order/approval of drawing Delivery Terms: EXW (Incoterms 2000) • Entire order cannot be consolidated. Partial deliveries will be made. • 10% deposit with PO *Note* Pricing does not include cladding, special coatings, stack (final height requirement to be confirmed), Please note: Our prices are based on today's precious metal prices. DCL reserves the right to revise this quote should changes occur in the spot prices of the precious metals used in the above product(s). This Quotation is valid for a period of 90 days. Best Regards, DCL America Brendan Filby Cell 925-808-5223 bfilbv(adcl-inc.com Confidential Communication ISO 9001:2000 QMS n�� AweIca inc. neM,re.4Y•Wssan r.M nt•r4e9P Mr memos.Foe.foOlINSiowinae Page: 3 of 4 STANDARD TERMS AND CONDITIONS OF SALE - Revised April 2009 1. Application. These Standard Terms and Conditions apply to any sale of products, equipment, parts, materials and related services (the "Products") by DCL America Inc. (^DCL") to a DCL customer (the "Customer") and acceptance of these Standard Terms and Conditions Is an express condition of such a sale. 2. Entire Agreement These Standard Terms and Conditions, the quotation (the "DCL Quotation") and/or order confirmation (the "DCL Order Confirmation") issued by DCL in respect of each supply of Products and any other document expressly incorporated by reference by DCL in a DCL Order Confirmation (collectively, the "Agreement") constitute the entire agreement between DCL and the Customer regarding a sale of Products by DCL to the Customer and supersede all other discussions, proposals, negotiations, statements, representations, understandings and the like, whether written or oral. DCL rejects any differing or supplemental terms which may be printed or otherwise found in any purchase order or other document sent by the Customer, except as expressly accepted by DCL by the signature of an authorized representative. Unless otherwise specifically and expressly set forth in writing by a duly authorized representative of DCL, if there are inconsistencies in the documents constituting the Agreement,such documents shall take precedence in the following order: (I)these Standard Terms and Conditions, (II)the DCL Order Confirmation,and(iii)the DCL Quotation or other contract document incorporated by reference by DCL in the DCL Order Confirmation. 3. Terms of Payment. Unless otherwise agreed by DCL in writing, DCL Invoices for the Customer's purchase of Products are payable within thirty(30)days of the date of the Invoice. Should payment of any amount owing to DCL under the Agreement not be made to DCL when due,such payment shall bear interest at the rate of one and one-half percent(11/2%)per month or the maximum rate allowed by law, whichever is lower. The charging of such interest shall not be construed as obligating DCL to grant any extension of time in the terms of payment. No cash discount shall be available to the Customer. If prior to any delivery of Products, DCL has concern regarding timely payment of the purchase price because of a material adverse change in Customer's circumstances or otherwise, DCL may require payment of all or additional parts of the purchase price before shipment or delivery and/or DCL may require satisfactory security for the payment of the purchase price. 4. Delivery Terms. Each sale of Products shall be shipped in accordance with the IncoTerms 2000 spedfied in the DCL Quotation or DCL Order Confirmation. If shipping instructions are not so specified for any supply of Products, such supply shall be shipped ex works (IncoTerms 2000). Ex works deliveries of the Products are deemed complete upon release of the Products to the Customer's carrier at the applicable manufacturing facilities located in Concord, Ontario, Canada as specified by DCL in the DCL Quotation, the DO. Order Confirmation, or otherwise. If the Customer Is unable or unwilling to accept physical delivery at the time spedfied, DCL may store or arrange for storage of Products at Customer's cost and the delivery of such Products shall be deemed complete as of the first day of storage. 5. Taxes. Unless otherwise expressly provided by DCL in a DCL Quotation or DCL Order Confirmation, or otherwise implicit in the IncoTerms 2000 specified for a particular supply,the price of the Products shall not include sales, use, excise, value added or any similar taxes, duties and other export/Import charges, any inspection or testing fees or any other tax, fee, penalty or charge of any nature whatsoever imposed currently or in the future by any federal, state or other government authority, upon or with respect to the sale, purchase,delivery, storage, processing or use of any Product or upon payment to DCL,and all such taxes, fees and other charges shall be paid by Customer In addition to the price of the Products. In the event DCL is required to pay any such taxes, fees or other charge, Customer shall reimburse DCL therefor. 6. Delivery Schedule. Time for delivery of Products is approximate and starts to run on the latest of the date specified or confirmed In the DCL Order Confirmation,or the receipt by DCL of any advance payment,credit approval or any security for the balance of the purchase price,as applicable,each as may be requested by DCL. Unless otherwise specified or confirmed in a DCL Order Confirmation,DCL shall not be liable for losses of any kind incurred by the Customer for delays in or failure to deliver all or any part of the Products. Changes In the delivery schedules requested by the Customer must be In writing and received by DCL at least two(2)business days prior to the previously scheduled shipping date. DCL is under no obligation to accept any changes in delivery dates requested by the Customer. 7. Ode Retention. Title or ownership of the Products shall not pass to the Customer,notwithstanding delivery thereof,but shall remain vested in DCL until the purchase price of the Products is paid in full. As security for the full payment of the purchase price of the Products, the Customer hereby grants to DCL, and DCL hereby reserves, a purchase money security interest and charge in the Products and in all substitutions, replacements and additions thereto and the proceeds thereof. Until such time of full payment,the Customer shall: (a)Insure the Products against loss,damage or destruction for full replacement value;and(b)execute such additional documents as DCL requests for the confirmation or perfection of DCL's ownership or security interest and charge. Upon default by the Customer,and subject to applicable law, DCL may repossess and deal with the Products as it sees fit and retain all payments which have been made by the Customer on account of the purchase price as partial damages. Upon any such realization of security,the Customer shall remain liable for any deficiency in the purchase price and shall reimburse DCL for all costs and expenses,including reasonable legal fees, incurred in enforcing Its rights. All rights and remedies of DCL are cumulative and in addition to those available at law or in equity. e. DCL Property. All supplies, materials, tools,jigs, dyes, gauges, fixtures, molds, patterns, equipment and other items procured by DCL to perform the supply of Products under any Agreement shall be and shall remain the property of DCL under ail drcumstances, including,without limitation,reimbursement of DCL by the Customer for all or any portion of the cost of such items. 9. Risk of Loss. Unless otherwise spedfied or confirmed in the DCL Order Confirmation, the risk of loss or damage to the Products including any repaired or replaced items,and the responsibility for the payment of Insurance premiums and freight passes to the Customer upon DCL's delivery of such Products to the Customer's carrier as provided In Section 4. No loss or damage to the Products or any portion thereof shall relieve the Customer from its obligations hereunder. 10. Suitability. Before using any Product, Customer shall determine the suitability of such Product for Customer's intended use. Customer shall assume all risk and liability whatsoever resulting from the use of the Products. 11. Limited Warranties. DCL warrants that each Product is free of defects in material and workmanship strictly in accordance with the terms and conditions of the limited warranty statement specified or confirmed In the applicable DCL Quotation or DCL Order Confirmation at the time of purchase(the"Product Warranties"). Additional copies of Product Warranties are available from DCL upon request. 12. No Other Warranties.THE LIMITED PRODUCT WARRANTIES REFERRED TO IN SECTION 11 ABOVE ARE EXCLUSIVE AND IN LIEU OF ALL OTHER EXPRESS OR IMPLIED WARRANTIES OR CONDITIONS IN RESPECT OF THE PRODUCTS,INCLUDING,WITHOUT LIMITATION,ALL IMPLIED WARRANTIES OF MERCHANTABILITY, FITNESS FOR A PARTICULAR PURPOSE, TITLE OR INFRINGEMENT OF INTELLECTUAL PROPERTY RIGHTS OR ANY OTHER WARRANTIES ARISING BY OPERATION OF LAW, COURSE OF DEALING, TRADE USAGE, REPRESENTATION, STATEMENT OR OTHERWISE. THE REMEDIES PROVIDED IN THE APPLICABLE PRODUCT WARRANTY ARE THE oe� Dar . -rr.,H b IMiI44I FS ..Ye,Mc's Page: 4 of 4 CUSTOMER'S SOLE REMEDIES FOR ANY FAILURE OF DCL TO COMPLY WITH ITS WARRANTY OBLIGATIONS. Applicable law may not allow exclusions of Implied warranties,so the above exclusions may not apply. 13. Limitation of Liability. DCL SHALL NOT UNDER ANY CIRCUMSTANCE BE LIABLE TO ANYONE FOR DIRECT, INDIRECT,INCIDENTAL, SPECIAL, CONSEQUENTIAL OR EXEMPLARY DAMAGES OF ANY KIND, INCLUDING, BUT NOT LIMITED TO, ANY LOST PROFITS AND LOST SAVINGS, HOWEVER CAUSED,WHETHER FOR BREACH OR REPUDIATION OF CONTRACT,TORT, BREACH OF WARRANTY, NEGLIGENCE,OR OTHERWISE, WHETHER OR NOT DCL WAS ADVISED OF THE POSSIBILITY OF SUCH LOSSES OR DAMAGES. IN NO EVENT SHALL DCL BE LIABLE FOR THE COST OF PROCUREMENT OF SUBSTITUTE PRODUCTS. DCL'S MAXIMUM TOTAL CUMULATIVE LIABILITY FOR ANY REASON SHALL NOT EXCEED THE AGGREGATE PURCHASE PRICE FOR THE APPLICABLE PRODUCTS SUPPLIED UNDER THE AGREEMENT. THE FOREGOING LIMITATION OF LIABILITY SHALL APPLY TO THE FULLEST EXTENT PERMITTED BY LAW IN THE APPLICABLE JURISDICTION. CUSTOMER HAS ACCEPTED THE DISCLAIMER OF WARRANTIES IN SECTION 12 AND LIMITATION OF LIABILITY IN THIS SECTION 13 AS PART OF A BARGAIN WITH RESPECT TO THE PRICING OF THE PRODUCTS AND UNDERSTANDS THAT THE PRICING WOULD BE HIGHER IF DCL WERE REQUIRED TO BEAR LIABILITY IN EXCESS OF THAT STATED HEREIN. DCL neither assumes nor authorizes any person,firm or entity to assume for DCL any other additional liability or responsibility in connection with the Products, Including any affirmation, representation,or warranty concerning the Products made by an agent,employee,or representative of DCL. 14. Indemnification. Customer shall defend, Indemnify and hold harmless DCL, its officers, directors, agents, employees, successors, assigns and other customers against any and all losses, liabilities and expenses (including all legal fees) or judgments arising from or in connection with any claim made or action brought as a result of(a)the use,storage,sale, processing,or other disposition of the Products sold to such Customer under the Agreement, or the action or inaction of Customer or, If applicable, its employees, customers, or agents, which may cause Injuries or damage giving rise to claims against DCL, or(b)an alleged infringement arises out of Customer's use of the Products or incorporation of the Product(s)as components into any other product. 15. Intellectual Property. Neither Customer, nor its affiliates(nor their respective successors,assigns,licensees or other transferees) shall enforce(or attempt or purport to enforce)against DCL or its affiliates,(sub)licensees,manufacturers,and distributors any existing or future patent that claims(or purports to claim)any or part of the Products or the use,design,manufacturing,layout and packaging thereof. This nonassertlon covenant shall be a covenant that transfers with any sale, license or other disposition or grant of rights under the applicable patent rights. 16. Re-sale of Products. Without limiting the generality of anything set forth In the Agreement,in respect of any re-sale of the Products or sale of any product which Incorporates a Product as a component, the Customer shall indemnify, defend and hold harmless DCL, its officers, directors, agents, employees, successors, assigns and other customers against any and all claims, actions, losses, liabilities and expenses(including all legal fees)or judgments arising from or In connection with a representation or warranty for the Products, including In their capacity or use as a component part of other products, made by the Customer, other than as limited by the applicable Product Warranties, or arising from an allegation of patent infringement relating to Customer's product(s) In which the Products are used as a component part. 17. Survival. All payment obligations, provisions for the limitation of or protection against liability of DCL and any other provision of an Agreement which by its nature are continuing shall survive the termination,cancellation or expiration of such Agreement. 18. Permits. The Customer shall obtain at its expense all licences, permits and approvals for the purchase, delivery, shipment, Installation and use of any Products. 19. Force Majeure. DCL is excused from the timely performance of its obligations in the sale or other supply of Products if its performance is impeded or prevented by circumstances beyond its control (a"Force Majeure Event") and DCL is taking all reasonable steps to mitigate the effect of the delay. Following the occurrence and the termination of a Force Majeure Event, DCL shall provide the Customer with written notice and reasonable particulars of the Force Majeure Event. Either party may terminate any Agreement affected by a Force Majeure Event if such circumstances continue for more than six(6) months. Upon and notwithstanding any such termination,the Customer shall pay DCL for that portion of the Products manufactured or delivered prior to the date of the abovemenboned initial notice of the Force Majeure Event. Notwithstanding anything In this Section 19,the Customer shall extend any security granted for the payment of the purchase price of Products for a period equal to the delay caused by the Force Majeure Event. 20. Governing Law. The sale of the Products and this Agreement are governed by the laws of Delaware and the laws of United States applicable therein. Each of the parties irrevocably attorns to the exclusive jurisdiction of the courts of Delaware, provided that DCL shall not be prevented from seeking injunctions or other temporary relief or enforcing judgments of the courts of Delaware in another jurisdiction. The United Nations Convention on the International Sale of Goods is explicitly excluded from this Agreement. 21. Confidential Information. Customer shall not disclose proprietary or confidential business or technical information disclosed by DCL or related to any Products to any third parties and shall not use such information for Its own benefit or for any purpose other than for the express purpose for which It was disclosed as set forth in writing by DCL at the time of disclosure. 22. Assignment. Customer may not assign all or any part of the Agreement for sale of Products without the prior consent of DCL. Any attempt at assignment shall be null and void unless made in conformity with this Section 22. 23. Waiver, Amendment. Any waiver, modification or amendment of the Agreement shall only be effective as against DCL if such waiver, modification or amendment Is contained in a written instrument prepared or otherwise accepted in writing by DCL. A waiver or modification by DCL of any condition or obligation of Customer hereunder shall not be construed as a waiver or modification of any other condition or obligation and no waiver or modification by DCL granted on any one occasion shall be construed as applying to any other occasion. 24. Suspension or Cancellation. Subject to Section 19 hereof,no Agreement may be cancelled or suspended by the Customer without the express written consent of DCL such consent to be granted in DCL's sole and unrestricted discretion and upon such terms,including the payment of all costs incurred and profits foregone,as DCL may require. 25. Severability. If a binding court determination is made that a provision of these Standard Terms and Conditions or any other document which forms the Agreement is unenforceable(in whole or in part),then such provision shall be void only to the extent that such determination requires,and the parties shall replace such void provision with one that is enforceable and valid and,to the greatest extent permitted by law, serves the intent and purpose of the void provision. No other provision shall be affected as a result thereof, and, accordingly, the remaining provisions shall remain in hill force and effect as though such void, voidable or inoperative provision had not been contained herein. G3616 GAS ENGINE SITE SPECIFIC TECHNICAL DATA CAITERPIWIRa DCP Midstream GAS COMPRESSION APPLICATION Enterprise ENGINE SPEED(rpm): 1000 FUEL SYSTEM: GAV COMPRESSION RATIO: 9'.1 WITH AIR FUEL RATIO CONTROL AFTERCOOLER WATER INLET(•F): 130 S(TE CONDmONS' JACKET WATER OUTLET(•F): 190 FUEL: Enterprise Fuel Gas ASPIRATION: TA FUEL PRESSURE RANGE(pslg): 42.87.0 COOLING SYSTEM: JW,OC+AC FUEL METHANE NUMBER: 69.1 IGNITION SYSTEM: CIS/ADEM3 FUEL LHV(Wady 1031 EXHAUST MANIFOLD: DRY ALTITUDE(ft): 4788 COMBUSTOR: Low Emission MAXIMUM INLET AIR TEMPERATURE(•F): 110 NOx EMISSION LEVEL(gbhphr NOs): 0.5 STANDARD RATED POWER: 4735 bhp®1000ipm 1�„ T'gyp@ �g "m§w - -r.V. 'g'"_n �P!M �R `"' _ #`U'$ �t '3�,� * ....:La..:�i t'V..a... £ .., I,e .1' ENGINE a _R w .; '.e.. - n .0 - ENGINE POWER (WI7HOUTF (1)� bhp 1736 3970 2977 2368 INLET MR TEMPERATURE •F 69 110 110 110 71:-.4.;444,-..-' ,:b„ ifTa i '1 if'll Ste i ' '5' :g° ° FUEL CONSUMPTION (LHV) (2) Btu.tphr 6768 6957 7384 7728 FUEL CONSUMPTION (HHV) (2) BtulMphr 7481 7892 8165 5545 AIR FLOW(77•F,14.7 pals) (WET/ (3)(4) adm 12293 10490 8061 6528 AIR FLOW (NET (3)(4) Whr 54510 46515 35743 28946 INLET MANIFOLD PRESSURE (5) in Hg(abs) 73.7 62.7 48.8 40.5 EXHAUST TEMPERATURE-ENGINE OUTLET (6) •F 856 883 935 874 EXHAUST GAS FLOW(I®erpine outlet temp.14.5 psia) (WET (7)(4) 83/min 31994 27888 22274 18571 EXHAUST GAS MASS FLOW (WET' (7)(4) b/hr 56023 47819 38782 29810 140x(as NO2) (8)(9) gfbhphr 0.50 0.50 0.50 0.50 CO (8)(9) glbhp-hr 2.75 2.74 2.74 2.75 THC(nld.wt.0(15.84) (8)(D) g/hp-hr 5.30 6.48 666 6.81 NMHC(md.Wt.of 15.84) (8)(9) g/bhp-hr 1.71 1.78 1.81 1.85 NMNEHC(VOCs)(md.WI.0115.84) (8)(9)(10) grbhphr 0.63 0.65 0.87 0.68 FICHO(Formaldehyde) (8)(9) glbhphr 028 0.27 0.29 0.31 C02 (8)(9) g/bhphr 439 450 478 502 EXHAUST OXYGEN (8X11) %DRY 12.0 118 11.6 11.4 H��ryry �t�st,� 6II9P6T w . ;xas...'_e a`A'1Es L 'a" F �: EAT REJ.TO JACKET WATER(JW) (12) Btuhnin 48334 45214 39967 34168 HEAT REJ.TO ATMOSPHERE (12) Bluhnln 18888 18192 17699 16771 HEAT REJ.TO LUKE OIL(00) (12) 8lulmin 24028 23687 23706 22870 HEAT REJ.TO AFTERCOOLER(AC) (12)(13) Bluimin 53488 53488 13584 4998 TOTAL JACKET WATER CIRCUIT(JW) (14) Btuhnin 53168 TOTAL AFTERCOOLER CIRCUIT(OC•AC) (13)(14) BtWmin 84974 A cooling system safely factor of 0%has been added to the cooling system sizing altena. rdlNMtloNs AND DaFNITON9 Engine rating obtained and presented in accordance mai ISO 3048/1.adjusted for Net,ate NNW*and site inlet air temperahae. 100%raang at mesimum inlet air temperate is the mamnum*Nana capability for the specified fuel at sib atitude and madmum ate inlet air temperature. Max hating Is the ina,mum cepabily for the speafied fuel al Nts altibde and reduced Inlet air IampenaWn. Lowest load poem Is the lowest continuous duty panting bad albxed.No overload permitted at rating teen. Far notes information mmuh page t r e. PREPARED BY:HAP SCHADLER,clop midstream Dale generated by Gas Engine Rating Pro Version 4.00.00 Ref.Data Set DM8608-03-001,Printed 130ec2011 Page 1 of 4 G3616 GAS ENGINE SITE SPECIFIC TECHNICAL DATA CATERNUAR' DCP Midstream GAS COMPRESSION APPLICATION Enterprise Engine Power vs. Inlet Air Temperature Data represents temperature sweep at 4788 Rand 1000 rpm 5000 5000 4500 4500 a4000 4000 Max Continuous Power vs. a 3500 Speed Capabity 3500 for Site Conditions 3000 ` 3000 . No Rating Available a 2500 Range for Site Conditions E 2000 2000 1500 1500 gi CoMiwous Range for Site Conditions ID 1000 1000 500 500 Low Load Intermittent 0 0 . Operating Range 30 40 50 60 70 80 90 100 110 120 130 Air Temperatu re,'F Engine Power vs. Engine Speed Data represents speed sweep at 4788 ft and 110°F 5000 5000 4500 — 4600 x4000 ��__. — .x. 4000 Mee Capabus Power va Speedd peity 8 3500 3500 for Site Conditions p 3000 3000 b No Rating Available a 2500 .. or' 2500 . Range for Ste Conditions 12000 2000 81500 7500 Eil Continuous Operating MI 1000 1000 Range for Ste Conditions 500 500 Low Load Intermittent 0 0 . Operating Range 750 800 850 900 950 1000 Engine Speed(rpm) Engine Torque vs. Engine Speed Data represents speed sweep at 4788 6 and 110°F 25000 25000 a 20000 20000 Max Continuous Torque va _ —Speed Capabity for Site Condiions 15000 16000 Na Rating Available 10000 . Range for Site Conditions 10000 a i Comnuous Operating W 5000 5000 Range for Ste Conditions 0 Low Load Intermittent 0 Operating Range 750 800 850 900 950 1000 Engine Speed(rpm) Note:At site conditions of 4788 ft and 110°F inlet air temp.,constant torque can be maintained down to 750 rpm. The minimum speed for loading at these conditions is 750 rpm. PREPARED BY:HAP SCHADLER.dcp midstream Data generated by Gas Engine Rating Pro Version 4.00.00 Ref.Data Set DM8808-03-Cal,PrIMed 130ec2011 Page 2 of 4 G3616 GAS ENGINE SITE SPECIFIC TECHNICAL.DATA CATERPILLAR' DCP Midstream GAS COMPRESSION APPLICATION Enterprise NOTES 1.Engine rating is with two engine driven water pumps. Tolerance is±3%of NI load. 2.Fuel consumpton tolerance Is t 2.5%of NI load data. 3.Air flow value Is on a Wal basis. Flaw is a nominal value with a tolerance oft5%. 4.Inlet and Exhaust Restrictions must not exceed MI limits based on(unload flow rates from the standard technical data sheet. 5.Inlet manifold pressure is a nominal value with a tolerance of t 5%. 6.Exhaust temperature is a nominal value with a tolerance of(t)63'F,(-)54'F. 7.Exhaust flow value is on ewer'basis. Flow Is a nominal value for total flow rate with a tolerance of±6%. Exhaust gas vented through the wastegete flows only to the right exhaust outlet The total flow through the wastegale may bees great as 15%of the total value for conditions under which the wwastegate is open. For installations that use dual exhaust runs this difference must be taken into account Mien specifying any items to be connected to the exhaust outlets. The flow In the right exhaust outlet must be sized for al least 65%of the loth flow to allow for the westegate ful open condition,while the left outlet must be sized for 50%of the total flaMfor the wastegale closed condition. Both runs must meet the allowable backpressure requirement as described in the Exhaust Systems AEI Guide. 8.Emissions data is at engine exhaust flange prior to any after treatment. 9.Emission values are based on engine operating al steady state conditions. Fuel methane number cannot vary more than±3.Values listed are higher than nominal levels to allow for Instrumentation,measurement,and englne4oangine variations.They indicate"Not to Exceed"values.THC,NMHC,and NMNEHC do not include abehydea An oxidation catalyst may be required to meal Federal,State or local CO or HO requirements. 10.VOCs-Volatile organic compounds as defined in US EPA 40 CFR e0,subpart JJJJ 11.Exhaust Oxygen level is the result of adjusting the engine to operate at the specified NOx level. Tolerance Is t 0.5. 12.Heat rejection values are nominal.Tolerances,based on treated water,are t 10%for jacket water circuit,t 50%for radiation,s 20%for tube oil draft and±5%for aftercoolar circuit. 13.Mercoobr heat rejection includes an aftercooler heat rejection lector for the site elevation and Intel air temperature specified. Macooler heat rejection values at pad bad we for reference only. Do not use part load data for heat exchanger sizing. 14.Cooing system siting criteria are maximum circuit heat rejection for the site,with applied tolerances. PREPARED BY:HAP SCHACLER,Pop midstream Data generated by Gas Engine Rating Pro Version 4.00.00 Ref.Data Set DM8606-03-00I,Printed 130ec2011 Page 3 of 4 Constituent Abbrev Mole W Norm Water Vapor H2O 0.0000 0.0000 Methane CH4 85.1000 85.1000 Fuel Makeup: Enterprise Fuel Gas Ethane C2H6 11.9300 11.9300 Unit of Measure: English Propane C3H8 2.3000 2.3000 Isobutane iso-C4H1O 0.1000 0.1000 Calculated Fuel Properties Norbutane nor-C4H1O 0.1400 0.1400 Caterpillar Methane Number: 69.1 Isopenlane iso-05H12 0.0100 0.0100 Norpentane nor-05H12 0.0000 0.0000 Hexane C6H14 0.0000 0.0000 Lower Heating Value(Btu/scf): 1031 Heptane C7H16 0.0000 0.0000 Higher Heating Value(Btu/scf): 1140 Nitrogen N2 0.4000 0.4000 WOBBE Index(Btu/scf): 1289 Carbon Dioxide CO2 0.0000 0.0000 Hydrogen Sulfide H2S 0.0000 0.0000 THC:Free Inert Ratio: 267.43 Carbon Monoxide CO 0.0000 0.0000 Total%Inerts(%N2,CO2,He): 0.41% Hydrogen H2 0.0000 0.0000 Oxygen O2 0.0100 0.0100 RPC(%)(To 905 Btu/scfFuel): 100% Helium HE 0.0100 0.0100 Neopentane neo-05H12 0.0000 0.0000 Compressibility Factor . 0.997 Octane C8H18 0.0000 0.0000 Stoich A/F Ratio(VoWGl): 10.72 Nonane C9H20 0.0000 0.0000 Stoich NF Ratio(Mass/Mass): 16.77 Ethylene C2H4 0.0000 0.0000 Specific Gravity(Relative to Air): 0.639 Propylene C3H6 0.0000 0.0000 TOTAL(Volume%) 100.0000 100.0000 Specific Heat Constant(K): 1.295 CON0ITIC SAND QFFINIUrINS Caterpiler Methane Number represents the Mork resistance of a gaseous fuel. Itaho&be used with thecaterpiller Fuel Usage Guide for tie engine and raring to detennne the rating for the fuel specified.A Fuel Usage Guide for each rating is included on page 2 of its standard technical data sheet RPC always applies to naturally aspirated(NA)engines.and tuddoharged(TA or LE)engines only when they are deradd for altitude end ambient site conditions. Project specific technical data sheets generated by the Ceterpilar Gas Engine Rating Pro program lake the Caterpi[ar Methane Number end RPC into account when generetieg a site rating. Fuel properties for BtWsd cekuladons are a 60F and 14.696 psis. Caterpillar shall have no lability in law or equity,for damages,consequently or otherwise,arising front use of progam and related material or any pert thereof. 61fMS Field gases,weN heed gems,end ethe engine gases typically certain liquid water and heavy hydrocarbons entrained in the gas. To prevent detonation and severe damage to the engine,hydrocarbon liquids must not be allowed to enter the engine fuel system.To remove Notre,a Squid separator and coalescing filter are recommended,with an automatic drain end cal m ecti tank to patters conamMabin Of the ground in accordance with local codes and standards To avoid water condensation in the engine or fuel linen snit the talative humidly of water in the fuel to 80%at the minimum fuel operating temperature. TANKS 4.0 Report Page 1 of 5 TANKS 0.0.9d Emissions Report-Detail Format Tank Indentiflcation and Physical Characteristics IdesDnaetlon User Identification: Entoeprlce eigM300-lobl tanks 6.46 MMGALlyr RVP 10 City Stab: Colors*, Type sly Typo I on: Vmlkal eeig Roof Tank Desortion: Erlbrydsaeiphtr 306hM condensate Tanks 1/8 volute o16.463.145 gaVyrw80T,690gal per lank,dutete* Tank Dknensions Shell Helgtl(ft): 15.00 Diameter(ft) 12.00 Liquid Might(R): 15.00 Avg.Liquid Height 7.50 Volume(gallop): (R) 12,600.44 TumwerS: 63.66 9TH Herded(yin): 807,893.00],6g3.00 H Paint Characteristics Shea Color/Shade: GrryNght Shell Conition Good Roof ColodShale: Gray/Lignt Rai COMAcn: Good Roof Chracterlstka Type: Cone Height(ft) 0.03 Slops(NR)(Cone Roof) 0.06 ereathr Vent Settings Vacuum Selena(pslg): -0.03 Pressure Settngs(pslg) 0.03 Metarological Data used In Emissions Calculations:Denver.Cdorade(Avg Atmospheric Pressures.12.12 psis) file://C:\Program Files\Tanks409d\summarydisplay.htm 12/15/2011 TANKS 4.0 Report Page 2 of 5 TANKS 4.0.9d Emissions Report-Detail Format Liquid Contents of Storage Tank Enterprise elyhl300-bb1 tanks 6.46 MMGAUyr RVP 10-Vertical Fixed Roof Tank Uw.M T..wsMpl0ep F0 T" Vim Prem.IOU) vMa Mau yaps M.1. SW 08,V949.179,07,4 MYAACYnp4.Anl Malt A. MU Mau 1a.0 t) Aq Mn Mw WOO twat twat Wig* 0.w.ew. G.MMR1RVP 101 Al 50.1e 4.20 0e.12 3145 000]0 I.02e II%I S000e 9200 Colon RVP•10,MOW 0A%-1 file://C:\Prograrn Filcs\Tanks409d\summarydisplay.htm 12/15/2011 I. TANKS 4.0 Report Page 3 of 5 TANKS 4.0.9d Emissions Report-Detail Format Detail Calculations(AP-42) Enterpdaa elght300.bbl tanks 8.46 MMGAUyr RVP 10•Vertical Fixed Roof Tank 491.6 Em.ar 0Mesupes. SVMpLUFIek 2]40.1140 Vwga.Volume 44001 842.3372 Yarn 20210 0.05114 Vera Spat.170.014 Foam 03151 V.rl66Siihnben Fib 3547 Tot War S"aVObm. TS**�Pk Iwu X11.502 Vow-Epsom Dap Tank 10H91071710:l.i l0. a405wd.�{.Wy5 10.00 A1k 2.5000 r M.92.0Y: 21250 M OVua.Ica*66545 pnel5Ym.11k 05250 454440+466 00000 Fee1S.p17417 00525 45.0>N.1fU O.Kd -- VMoICUal 590514 01415770147 V.pxMmmlb'.lN 00.0914 rno Wild yam Telect I0..l 5.0035 OBI A%1.10.10 14.thes• Anna I Ter9.(So. 1 T $6621x» ISO U.Car.1 OacM MO: 16151 L uquid Bulk Toth Paint NS.p l 512.1215 l F .i Point Solar MoWul6C 0.500 Oslo 1066m 5 M.bbr Far 55400 d n 11®.x22 VVip Saab E 1Ma Rider 066yV a.aa.a F.Yi. ti.'51 20 O 0y V1 W PS..1449"191..y 2.1494 VolEinalut Pa..5.e\R•75•15Y0.1.ol.5. 2.0320 34,2,3 3304,43 M I"6l L6 Y1 • T.5P nen Vav Pte.6001 MMFun L1W 50.2166 T.a.654 WO.. 00205 • Pre4•01.0447 MNmun LWk 0.1523 pM5M,W6• 091a""I TT npl.1pe 19: 51 05 Ply 501%044204&.50 Imp.512147 'R.2007 Day M¢Liquid SAW,In 16211: 52021662 I M1m c..T66e.Mp.f61.1C21.0417 v., 10a Faces V..tl Vgfs.b.bl 745105 0.1309 55..v Pm..01 Day/.rq.Lqx. 50.54"T5rMu.4214 40052 yew,Spew Wove 077 773240 �Mdd•csw*011b.5nwl 1201.0000 Vap07 PrIPIP.I0 all Day AVOW. 065 Budges T.r.v5 0..120 5.00E ♦r Not 11Cutls5+law1: 907.00 0m5 Irw T0.ru.arar 15x15 u5Ywmign V dun.WI: 12,100.441 00000 ors MM.1.MR 15560 Tot 01 0050 Dakar rm: 11400 M 5 flail 4caa p1 5.6621507 file://C:\Program Files\Tanks409d\summarydisplay.htm 12/15/2011 TANKS 4.0 Report Page 4 of 5 TANKS 4.0.9d Emissions Report-Detail Format Individual Tank Emission Totals Emissions Report for:Annual Enterprise elpht300-bbl tanks 6.46 MMGAL/yr RVP 10-Vertical Fixed Roof Tank I I bt) IConnonrns II Working Lasell Breathing Loss Tool Fs+woral (Gasoline(RVP 10) t 4,051.8111 2.390.6111 6,392.161 file://C:\Program Files\Tanks409d\summarydisplay.htm 12/15/2011 Page: 1 GRI-GLYCalc VERSION 4.0 - SUMMARY OF INPUT VALUES Case Name: Enterprisell0 MMSCFD File Name: \\dennas00\Data\Environmental\Air\Colorado\Enterprise\CAT 3612-Combustor-Turbine Permit Mod\Proposed CAT 3616\110 MMSCFD Glycalc 95% Control.ddf Date: December 15, 2011 DESCRIPTION: Description: Enterprise 110 MMSCFD 35 gpm Glycol Recirc Rate Annual Hours of Operation: 8760.0 hours/yr WET GAS: Temperature: 120.00 deg. F Pressure: 1000.00 psig Wet Gas Water Content: Saturated Component Conc. (vol %) Carbon Dioxide 2.6600 Nitrogen 0.3200 Methane 73.6091 Ethane 13.4435 Propane 5.7633 Isobutane 0.8119 n-Butane 1.8738 Isopentane 0.5005 n-Pentane 0.5144 Cyclopentane 0.0240 n-Hexane 0.1123 Cyclohexane 0.0286 Other Hexanes 0.2068 Heptanes 0.0782 Benzene 0.0251 Toluene 0.0204 Ethylbenzene 0.0004 Xylenes 0.0038 C8+ Heavies 0.0227 DRY GAS: Flow Rate: 110.0 MMSCF/day Water Content: 7.0 lbs. H2O/MMSCF LEAN GLYCOL: Glycol Type: TEG Water Content: 1.5 wt% H2O Flow Rate: 35.0 gpm PUMP: Page: 2 Glycol Pump Type: Electric/Pneumatic FLASH TANK: Flash Control: Recycle/recompression Temperature: 160.0 deg. F Pressure: 30.0 psig REGENERATOR OVERHEADS CONTROL DEVICE: Control Device: Condenser Temperature: 120.0 deg. F Pressure: 12.5 psia Control Device: Combustion Device Destruction Efficiency: 95.0 % Excess Oxygen: 0.0 % Ambient Air Temperature: 0.0 deg. F Page: 1 GRI-GLYCalc VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name: Enterprisell0 MMSCFD File Name: \\dennas00\Data\Environmental\Air\Colorado\Enterprise\CAT 3612-Combustor-Turbine Permit Mod\Proposed CAT 3616\110 MMSCFD Glycalc 95% Control.ddf Date: December 15, 2011 DESCRIPTION: Description: Enterprise 110 MMSCFD 35 gpm Glycol Recirc Rate Annual Hours of Operation: 8760.0 hours/yr EMISSIONS REPORTS: CONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.0693 1.664 0.3036 Ethane 0.1884 4.522 0.8253 Propane 0.3060 7.345 1.3404 Isobutane 0.0892 2.140 0.3906 n-Butane 0.3056 7.335 1.3387 Isopentane 0.0856 2.054 0.3749 n-Pentane 0.1213 2.911 0.5312 Cyclopentane 0.0455 1.093 0.1994 n-Hexane 0.0477 1.144 0.2099 Cyclohexane 0.0788 1.890 0.3450 Other Hexanes 0.0677 1.625 0.2965 Heptanes 0.0482 1.156 0.2109 Benzene 0.5471 13.131 2.3964 Toluene 0.3205 7.693 1.4039 Ethylbenzene 0.0031 0.075 0.0137 Xylenes 0.0323 0.775 0.1414 C8+ Heavies 0.0004 0.009 0.0017 Total Emissions 2.3568 56.562 10.3226 Total Hydrocarbon Emissions 2.3568 56.562 10.3226 Total VOC Emissions 2.0990 50.376 9.1937 Total HAP Emissions 0.9508 22.818 4.1643 Total BTEX Emissions 0.9031 21.674 3.9555 UNCONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 1.3882 33.316 6.0802 Ethane 3.7935 91.045 16.6157 Propane 6.3164 151.594 27.6658 Isobutane 1.8981 45.553 8.3135 n-Butane 6.6834 160.401 29.2732 Isopentane 2.1352 51.245 9.3522 n-Pentane 3.1311 75.147 13.7144 Cyclopentane 1.2789 30.693 5.6015 n-Hexane 1.5966 39.318 6.9931 Page: 2 Cyclohexane 3.1588 75.812 13.8357 Other Hexanes 2.0003 48.007 8.7613 Heptanes 2.8458 68.300 12.4648 Benzene 25.1880 604.511 110.3233 Toluene 30.3327 727.984 132.8571 Ethylbenzene 0.8039 19.294 3.5212 Xylenes 10.2209 245.302 44.7677 C8+ Heavies 5.6288 135.090 24.6540 Total Emissions 108.4006 2601.614 474.7945 Total Hydrocarbon Emissions 108.4006 2601.614 474.7945 Total VOC Emissions 103.2189 2477.253 452.0986 Total HAP Emissions 68.1421 1635.410 298.4623 Total BTEX Emissions 66.5455 1597.092 291.4693 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 50.6606 1215.853 221.8932 Ethane 43.4993 1043.984 190.5270 Propane 34.9533 838.880 153.0956 Isobutane 7.4493 178.784 32.6280 n-Butane 20.6585 495.803 90.4840 Isopentane 6.0793 145.904 26.6275 n-Pentane 7.3441 176.258 32.1670 Cyclopentane 0.7711 18.507 3.3776 n-Hexane 2.2257 53.418 9.7487 Cyclohexane 1.1338 27.212 4.9662 Other Hexanes 3.6088 86.612 15.8068 Heptanes 2.0873 50.096 9.1425 Benzene 1.4595 35.028 6.3925 Toluene 1.2144 29.145 5.3190 Ethylbenzene 0.0198 0.476 0.0868 Xylenes 0.1787 4.289 0.7827 C8+ Heavies 0.9066 21.757 3.9707 Total Emissions 184.2502 4422.004 807.0158 Total Hydrocarbon Emissions 184.2502 4422.004 807.0158 Total VOC Emissions 90.0903 2162.167 394.5955 Total HAP Emissions 5.0981 122.355 22.3297 Total BTEX Emissions 2.8724 68.937 12.5810 COMBINED REGENERATOR VENT/FLASH GAS EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.0693 1.664 0.3036 Ethane 0.1884 4.522 0.8253 Propane 0.3060 7.345 1.3404 Isobutane 0.0892 2.140 0.3906 ll Page: 3 n-Butane 0.3056 7.335 1.3387 Isopentane 0.0856 2.054 0.3749 n-Pentane 0.1213 2.911 0.5312 Cyclopentane 0.0455 1.093 0.1994 n-Hexane 0.0477 1.144 0.2089 Cyclohexane 0.0788 1.890 0.3450 Other Hexanes 0.0677 1.625 0.2965 Heptanes 0.0482 1.156 0.2109 Benzene 0.5471 13.131 2.3964 Toluene 0.3205 7.693 1.4039 Ethylbenzene 0.0031 0.075 0.0137 Xylenes 0.0323 0.775 0.1414 C8+ Heavies 0.0004 0.009 0.0017 Total Emissions 2.3568 56.562 10.3226 Total Hydrocarbon Emissions 2.3568 56.562 10.3226 Total VOC Emissions 2.0990 50.376 9.1937 Total HAP Emissions 0.9508 22.818 4.1643 Total BTEX Emissions 0.9031 21.674 3.9555 COMBINED REGENERATOR VENT/PLASH GAS EMISSION CONTROL REPORT: Component Uncontrolled Controlled % Reduction tons/yr tons/yr Methane 227.9735 0.3036 99.87 Ethane 207.1427 0.8253 99.60 Propane 180.7614 1.3404 99.26 Isobutane 40.9415 0.3906 99.05 n-Butane 119.7572 1.3387 98.88 Isopentane 35.9797 0.3749 98.96 n-Pentane 45.8814 0.5312 98.84 Cyclopentane 8.9791 0.1994 97.78 n-Hexane 16.7418 0.2089 98.75 Cyclohexane 18.8018 0.3450 98.17 Other Hexanes 24.5680 0.2965 98.79 Heptanes 21.6073 0.2109 99.02 Benzene 116.7159 2.3964 97.95 Toluene 138.1761 1.4039 98.98 Ethylbenzene 3.6080 0.0137 99.62 Xylenes 45.5504 0.1414 99.69 C8+ Heavies 28.6247 0.0017 99.99 Total Emissions 1281.8103 10.3226 99.19 Total Hydrocarbon Emissions 1281.8103 10.3226 99.19 Total VOC Emissions 846.6942 9.1937 98.91 Total HAP Emissions 320.7920 4.1643 98.70 Total BTEX Emissions 304.0503 3.9555 98.70 EQUIPMENT REPORTS: CONDENSER AND COMBUSTION DEVICE Page: 4 Condenser Outlet Temperature: 120.00 deg. F Condenser Pressure: 12.50 psia Condenser Duty: 1.91e-001 MM BTU/hr Hydrocarbon Recovery: 4.91 bbls/day Produced Water: 30.10 bbls/day Ambient Temperature: 0.00 deg. F Excess Oxygen: 0.00 % Combustion Efficiency: 95.00 % Supplemental Fuel Requirement: 1.91e-001 MM BTU/hr Component Emitted Destroyed Methane 4.99% 95.01% Ethane 4.97% 95.03% Propane 4.85% 95.15% Isobutane 4.703 95.30% n-Butane 4.57% 95.43% Isopentane 4.01% 95.99% n-Pentane 3.87% 96.13% Cyclopentane 3.563 96.44% n-Hexane 2.993 97.01% Cyclohexane 2.49% 97.51% Other Hexanes 3.38% 96.62% Heptanes 1.69% 98.31% Benzene 2.17% 97.83% Toluene 1.06% 98.94% Ethylbenzene 0.39% 99.61% Xylenes 0.32% 99.68% C8+ Heavies 0.01$ 99.99% 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: 6.01 lbs. H2O/MMSCF Temperature: 120.0 deg. F Pressure: 1000.0 psig Dry Gas Flow Rate: 110.0000 MMSCF/day Glycol Losses with Dry Gas: 6.9564 lb/hr Wet Gas Water Content: Saturated Calculated Wet Gas Water Content: 102.41 lbs. H2O/MMSCF Calculated Lean Glycol Recirc. Ratio: 4.75 gal/lb H2O Remaining Absorbed Component in Dry Gas in Glycol Water 5.85% 94.15% Carbon Dioxide 99.61% 0.39% Nitrogen 99.963 0.04% Methane 99.96% 0.04% Ethane 99.90% 0.10% Propane 99.87% 0.13% Isobutane 99.84% 0.163 n-Butane 99.79% 0.21% Isopentane 99.81% 0.19% n-Pentane 99.773 0.23% Page: 5 Cyclopentane 98.99% 1.01% n-Hexane 99.67% 0.33% Cyclohexane 98.52% 1.48% Other Hexanes 99.74% 0.26% Heptanes 99.48% 0.52% Benzene 88.75% 11.25% Toluene 86.11% 13.89% Ethylbenzene 83.95% 16.05% Xylenes 78.67% 21.33% C8+ Heavies 98.60% 1.40% FLASH TANK Flash Control: Recycle/recompression Flash Temperature: 160.0 deg. F Flash Pressure: 30.0 psig Left in Removed in Component Glycol Flash Gas Water 99.83% 0.17% Carbon Dioxide 20.681 79.32% Nitrogen 2.59% 97.41% Methane 2.67% 97.33% Ethane 8.02% 91.981 Propane 15.31% 84.69% Isobutane 20.31% 79.69% n-Butane 24.44% 75.56% Isopentane 26.36% 73.64% n-Pentane 30.24% 69.76% Cyclopentane 62.57% 37.43% n-Hexane 42.06% 57.94% Cyclohexane 74.43% 25.57% Other Hexanes 36.30% 63.70% Heptanes 57.90% 42.10% Benzene 94.80% 5.20% Toluene 96.45% 3.55% Ethylbenzene 97.85% 2.151 Xylenes 98.50% 1.50% C8+ Heavies 87.80% 12.20% REGENERATOR No Stripping Gas used in regenerator. Remaining Distilled Component in Glycol Overhead Water 40.07% 59.93% Carbon Dioxide 0.00% 100.00% Nitrogen 0.00% 100.00% Methane 0.00% 100.00% Ethane 0.00% 100.00% Propane 0.00% 100.00% Isobutane 0.00% 100.00% n-Butane 0.00% 100.00% Isopentane 1.90% 98.10% n-Pentane 1.65% 98.35% Page: 6 Cyclopentane 0.80% 99.20% n-Hexane 1.19% 98.81% Cyclohexane 4.30% 95.70% Other Hexanes 2.75% 97.25% Heptanes 0.86% 99.14% Benzene 5.27% 94.73% Toluene 8.19% 91.81% Ethylbenzene 10.64% 89.36% Xylenes 13.12% 86.88% C8+ Heavies 13.70% 86.30% STREAM REPORTS: WET GAS STREAM Temperature: 120.00 deg. F Pressure: 1014.70 psia Flow Rate: 4.60e+006 scfh Component Conc. Loading (vol%) (lb/hr) Water 2.16e-001 4.71e+002 Carbon Dioxide 2.65e+000 1.41e+004 Nitrogen 3.19e-001 1.08e+003 Methane 7.34e+001 1.43e+005 Ethane 1.34e+001 4.89e+004 Propane 5.75e+000 3.07e+004 Isobutane 8.10e-001 5.70e+003 n-Butane 1.87e+000 1.32e+004 Isopentane 4.99e-001 4.36e+003 n-Pentane 5.13e-001 4.49e+003 Cyclopentane 2.39e-002 2.03e+002 n-Hexane 1.12e-001 1.17e+003 Cyclohexane 2.85e-002 2.91e+002 Other Hexanes 2.06e-001 2.15e+003 Heptanes 7.80e-002 9.47e+002 Benzene 2.50e-002 2.37e+002 Toluene 2.04e-002 2.27e+002 Ethylbenzene 3.99e-004 5.13e+000 Xylenes 3.79e-003 4.88e+001 C8+ Heavies 2.26e-002 4.67e+002 Total Components 100.00 2.71e+005 DRY GAS STREAM Temperature: 120.00 deg. F Pressure: 1014.70 psia Flow Rate: 4.58e+006 scfh Component Conc. Loading (volt) (lb/hr) Water 1.27e-002 2.75e+001 Carbon Dioxide 2.65e+000 1.41e+004 Nitrogen 3.20e-001 1.08e+003 Page: 7 Methane 7.36e+001 1.43e+005 Ethane 1.34e+001 4.88e+004 Propane 5.76e+000 3.07e+004 Isobutane 8.11e-001 5.69e+003 n-Butane 1.87e+000 1.31e+004 Isopentane 5.OOe-001 4.36e+003 n-Pentane 5.13e-001 4.48e+003 Cyclopentane 2.38e-002 2.01e+002 n-Hexane 1.12e-001 1.17e+003 Cyclohexane 2.82e-002 2.87e+002 Other Hexanes 2.06e-001 2.15e+003 Heptanes 7.78e-002 9.42e+002 Benzene 2.23e-002 2.10e+002 Toluene 1.76e-002 1.96e+002 Ethylbenzene 3.36e-004 4.31e+000 Xylenes 2.99e-003 3.84e+001 C8+ Heavies 2.24e-002 4.61e+002 Total Components 100.00 2.71e+005 LEAN GLYCOL STREAM Temperature: 120.00 deg. F Flow Rate: 3.50e+001 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9.85e+001 1.94e+004 Water 1.50e+000 2.95e+002 Carbon Dioxide 2.81e-011 5.53e-009 Nitrogen 2.34e-013 4.62e-011 Methane 8.88e-018 1.75e-015 Ethane 1.13e-007 2.23e-005 Propane 8.53e-009 1.68e-006 Isobutane 1.42e-009 2.80e-007 n-Butane 3.44e-009 6.78e-007 Isopentane 2.10e-004 4.13e-002 n-Pentane 2.67e-004 5.26e-002 Cyclopentane 5.23e-005 1.03e-002 n-Hexane 9.75e-005 1.92e-002 Cyclohexane 7.20e-004 1.42e-001 Other Hexanes 2.88e-004 5.67e-002 Heptanes 1.26e-004 2.48e-002 Benzene 7.12e-003 1.40e+000 Toluene 1.37e-002 2.71e+000 Ethylbenzene 4.86e-004 9.57e-002 Xylenes 7.84e-003 1.54e+000 C8+ Heavies 4.54e-003 8.94e-001 Total Components 100.00 1.97e+004 RICH GLYCOL STREAM Temperature: 120.00 deg. F Pressure: 1014.70 psia Flow Rate: 3.66e+001 gpm NOTE: Stream has more than one phase. Page: 8 Component Conc. Loading (wt%) (lb/hr) TEG 9.470+001 1.940+004 Water 3.610+000 7.390+002 Carbon Dioxide 2.70e-001 5.530+001 Nitrogen 2.26e-003 4.62e-001 Methane 2.54e-001 5.20e+001 Ethane 2.31e-001 4.73e+001 Propane 2.02e-001 4.130+001 Isobutane 4.56e-002 9.350+000 n-Butane 1.34e-001 2.73e+001 Isopentane 4.03e-002 8.26e+000 n-Pentane 5.14e-002 1.050+001 Cyclopentane 1.01e-002 2.06e+000 n-Hexane 1.88e-002 3.84e+000 Cyclohexane 2.17e-002 4.43e+000 Other Hexanes 2.77e-002 5.67e+000 Heptanes 2.42e-002 4.96e+000 Benzene 1.37e-001 2.80e+001 Toluene 1.67e-001 3.43e+001 Ethylbenzene 4.49e-003 9.19e-001 Xylenes 5.83e-002 1.190+001 CB+ Heavies 3.63e-002 7.43e+000 Total Components 100.00 2.05e+004 FT.MH TANK OFF GAS STREAM Temperature: 160.00 deg. F Pressure: 44.70 psia Flow Rate: 2.77e+003 scfh Component Conc. Loading (vol%) (lb/hr) Water 9.76e-001 1.280+000 Carbon Dioxide 1.37e+001 4.390+001 Nitrogen 2.20e-001 4.50e-001 Methane 4.32e+001 5.07e+001 Ethane 1.98e+001 4.35e+001 Propane 1.09e+001 3.50e+001 Isobutane 1.750+000 7.45e+000 n-Butane 4.87e+000 2.07e+001 Isopentane 1.150+000 6.080+000 n-Pentane 1.390+000 7.340+000 Cyclopentane 1.51e-001 7.71e-001 n-Hexane 3.54e-001 2.23e+000 Cyclohexane 1.84e-001 1.130+000 Other Hexanes 5.73e-001 3.61e+000 Heptanes 2.85e-001 2.09e+000 Benzene 2.56e-001 1.46e+000 Toluene 1.80e-001 1.21e+000 Ethylbenzene 2.56e-003 1.98e-002 Xylenes 2.30e-002 1.79e-001 C8+ Heavies 7.29e-002 9.07e-001 Total Components 100.00 2.30e+002 Page: 9 FLASH TANK GLYCOL STREAM Temperature: 160.00 deg. F Flow Rate: 3.61e+001 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9.57e+001 1.94e+004 Water 3.64e+000 7.37e+002 Carbon Dioxide 5.65e-002 1.14e+001 Nitrogen 5.91e-005 1.20e-002 Methane 6.86e-003 1.39e+000 Ethane 1.87e-002 3.79e+000 Propane 3.12e-002 6.32e+000 Isobutane 9.37e-003 1.90e+000 n-Butane 3.30e-002 6.68e+000 Isopentane 1.07e-002 2.18e+000 n-Pentane 1.57e-002 3.18e+000 Cyclopentane 6.37e-003 1.29e+000 n-Hexane 7.98e-003 1.62e+000 Cyclohexane 1.63e-002 3.30e+000 Other Hexanes 1.02e-002 2.06e+000 Heptanes 1.42e-002 2.87e+000 Benzene 1.31e-001 2.66e+001 Toluene 1.63e-001 3.30e+001 Ethylbenzene 4.44e-003 9.00e-001 Xylenes 5.81e-002 1.18e+001 C8+ Heavies 3.22e-002 6.52e+000 Total Components 100.00 2.02e+004 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 Pressure: 14.70 psia Flow Rate: 9.97e+003 scfh Component Conc. . Loading (vol%) (lb/hr) Water 9.33e+001 4.42e+002 Carbon Dioxide 9.89e-001 1.14e+001 Nitrogen 1.62e-003 1.20e-002 Methane 3.29e-001 1.39e+000 Ethane 4.80e-001 3.79e+000 Propane 5.45e-001 6.32e+000 Isobutane 1.24e-001 1.90e+000 n-Butane 4.37e-001 6.68e+000 Isopentane 1.13e-001 2.14e+000 n-Pentane 1.65e-001 3.13e+000 Cyclopentane 6.94e-002 1.28e+000 Page: 10 n-Hexane 7.05e-002 1.60e+000 Cyclohexane 1.43e-001 3.16e+000 Other Hexanes 8.83e-002 2.00e+000 Heptanes 1.08e-001 2.85e+000 Benzene 1.23e+000 2.52e+001 Toluene 1.25e+000 3.03e+001 Ethylbenzene 2.88e-002 8.04e-001 Xylenes 3.66e-001 1.02e+001 C8+ Heavies 1.26e-001 5.63e+000 Total Components 100.00 5.62e+002 CONDENSER PRODUCED WATER STREAM Temperature: 120.00 deg. F Flow Rate: 8.78e-001 gpm Component Conc. Loading (wt%) (lb/hr) (ppm) Water 9.99e+001 4.39e+002 998857. Carbon Dioxide 1.53e-002 6.72e-002 153. Nitrogen 4.21e-007 1.85e-006 0. Methane 9.42e-005 4.14e-004 1. Ethane 2.92e-004 1.28e-003 3. Propane 4.89e-004 2.15e-003 5. Isobutane 7.77e-005 3.41e-004 1. n-Butane 3.54e-004 1.55e-003 4. Isopentane 6.98e-005 3.07e-004 1. n-Pentane 1.06e-004 4.66e-004 1. Cyclopentane 2.80e-004 1.23e-003 3. n-Hexane 3.46e-005 1.52e-004 0. Cyclohexane 3.22e-004 1.42e-003 3. Other Hexanes 3.96e-005 1.74e-004 0. Heptanes 1.94e-005 8.52e-005 0. Benzene 6.30e-002 2.77e-001 630. Toluene 3.04e-002 1.33e-001 304. Ethylbenzene 2.24e-004 9.84e-004 2. Xylenes 3.20e-003 1.41e-002 32. C8+ Heavies 9.68e-008 4.25e-007 0. Total Components 100.00 4.39e+002 1000000. CONDENSER RECOVERED OIL STREAM Temperature: 120.00 deg. F Flow Rate: 1.43e-001 gpm Component Conc. Loading (wt%) (lb/hr) Water 5.74e-002 3.50e-002 Carbon Dioxide 7.06e-002 4.30e-002 Nitrogen 4.78e-005 2.91e-005 Methane 2.36e-003 1.44e-003 Ethane 3.91e-002 2.38e-002 Propane 3.18e-001 1.93e-001 Isobutane 1.87e-001 1.14e-001 n-Butane 9.34e-001 5.69e-001 Isopentane 6.95e-001 4.23e-001 n-Pentane 1.16e+000 7.05e-001 Page: 11 Cyclopentane 6.03e-001 3.67e-001 n-Hexane 1.06e+000 6.43e-001 Cyclohexane 2.60e+000 1.58e+000 Other Hexanes 1.06e+000 6.46e-001 Heptanes 3.09e+000 1.88e+000 Benzene 2.29e+001 1.40e+001 Toluene 3.91e+001 2.38e+001 Ethylbenzene 1.22e+000 7.40e-001 Xylenes 1.57e+001 9.56e+000 C8+ Heavies 9.23e+000 5.62e+000 Total Components 100.00 6.09e+001 CONDENSER VENT STREAM Temperature: 120.00 deg. F Pressure: 12.50 psia Flow Rate: 4.77e+002 scfh Component Conc. Loading (volt) (lb/hr) Water 1.36e+001 3.09e+000 Carbon Dioxide 2.05e+001 1.13e+001 Nitrogen 3.39e-002 1.19e-002 Methane 6.87e+000 1.39e+000 Ethane 9.97e+000 3.77e+000 Propane 1.10e+001 6.12e+000 Isobutane 2.44e+000 1.78e+000 n-Butane 8.36e+000 6.11e+000 Isopentane 1.89e+000 1.71e+000 n-Pentane 2.67e+000 2.43e+000 Cyclopentane 1.03e+000 9.11e-001 n-Hexane 8.80e-001 9.54e-001 Cyclohexane 1.49e+000 1.58e+000 Other Hexanes 1.25e+000 1.35e+000 Heptanes 7.64e-001 9.63e-001 Benzene 1.11e+001 1.09e+001 Toluene 5.53e+000 6.41e+000 Ethylbenzene 4.69e-002 6.27e-002 Xylenes 4.84e-001 6.46e-001 C8+ Heavies 3.55e-003 7.60e-003 Total Components 100.00 6.16e+001 COMBUSTION DEVICE OFF GAS STREAM Temperature: 1000.00 deg. F Pressure: 14.70 psia Flow Rate: 1.57e+001 scfh Component Conc. Loading (volt) (lb/hr) Methane 1.04e+001 6.93e-002 Ethane 1.51e+001 1.88e-001 Propane 1.68e+001 3.06e-001 Isobutane 3.71e+000 8.92e-002 n-Butane 1.27e+001 3.06e-001 Isopentane 2.86e+000 8.56e-002 Page: 12 n-Pentane 4.06e+000 1.21e-001 Cyclopentane 1.57e+000 4.55e-002 n-Hexane 1.34e+000 4.77e-002 Cyclohexane 2.26e+000 7.88e-002 Other Hexanes 1.90e+000 6.77e-002 Heptanes 1.16e+000 4.82e-002 Benzene 1.69e+001 5.47e-001 Toluene 8.40e+000 3.21e-001 Ethylbenzene 7.13e-002 3.13e-003 Xylenes 7.34e-001 3.23e-002 C8+ Heavies 5.38e-003 3.80e-004 Total Components 100.00 2.36e+000 Page: 1 GRI-GLYCalc VERSION 4.0 - SUMMARY OF INPUT VALUES Case Name: Enterprise 60 MMSCFD File Name: \\dennas00\Data\Environmental\Air\Colorado\Enterprise\CAT 3612-Combustor-Turbine Permit Mod\Proposed CAT 3616\60 MMSCFD Glycalc 95% Control.ddf Date: December 15, 2011 DESCRIPTION: Description: Enterprise 60 MMSCFD 15 gpm Glycol Recirc Rate Annual Hours of Operation: 8760.0 hours/yr WET GAS: Temperature: 120.00 deg. F Pressure: 1000.00 psis Wet Gas Water Content: Saturated Component Conc. (vol %) Carbon Dioxide 2.6600 Nitrogen 0.3200 Methane 73.6091 Ethane 13.4435 Propane 5.7633 Isobutane 0.8119 n-Butane 1.8738 Isopentane 0.5005 n-Pentane 0.5144 Cyclopentane 0.0240 n-Hexane 0.1123 Cyclohexane 0.0286 Other Hexanes 0.2068 Heptanes 0.0782 Benzene 0.0251 Toluene 0.0204 Ethylbenzene 0.0004 Xylenes 0.0038 C8+ Heavies 0.0227 DRY GAS: Flow Rate: 60.0 MMSCF/day Water Content: 7.0 lbs. H2O/MMSCF LEAN GLYCOL: Glycol Type: TEG Water Content: 1.5 wt% H2O Flow Rate: 15.0 gpm PUMP: Page: 2 Glycol Pump Type: Electric/Pneumatic FLASH TANK: Flash Control: Recycle/recompression Temperature: 160.0 deg. F Pressure: 30.0 psig REGENERATOR OVERHEADS CONTROL DEVICE: Control Device: Condenser Temperature: 120.0 deg. F Pressure: 12.5 psis Control Device: Combustion Device Destruction Efficiency: 95.0 % Excess Oxygen: 0.0 % Ambient Air Temperature: 0.0 deg. F Page: 1 GRI-GLYCalc VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name: Enterprise 60 MMSCFD File Name: \\dennas00\Data\Environmental\Air\Colorado\Enterprise\CAT 3612-Combustor-Turbine Permit Mod\Proposed CAT 3616\60 MMSCFD Glycalc 958 Control.ddf Date: December 15, 2011 DESCRIPTION: Description: Enterprise 60 MMSCFD 15 gpm Glycol Recirc Rate Annual Hours of Operation: 8760.0 hours/yr EMISSIONS REPORTS: CONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.0292 0.701 0.1279 Ethane 0.0782 1.877 0.3426 Propane 0.1308 3.138 0.5728 Isobutane 0.0379 0.909 0.1658 n-Butane 0.1297 3.113 0.5682 Isopentane 0.0361 0.866 0.1580 n-Pentane 0.0510 1.225 0.2235 Cyclopentane 0.0189 0.454 0.0828 n-Hexane 0.0199 0.477 0.0871 Cyclohexane 0.0326 0.782 0.1426 Other Hexanes 0.0283 0.679 0.1239 Heptanes 0.0198 0.476 0.0869 Benzene 0.2324 5.577 1.0178 Toluene 0.1360 3.264 0.5956 Ethylbenzene 0.0013 0.032 0.0058 Xylenes 0.0139 0.333 0.0608 C8+ Heavies 0.0002 0.004 0.0007 Total Emissions 0.9961 23.906 4.3628 Total Hydrocarbon Emissions 0.9961 23.906 4.3628 Total VOC Emissions 0.8887 21.328 3.8924 Total HAP Emissions 0.4035 9.683 1.7672 Total BTEX Emissions 0.3836 9.206 1.6801 UNCONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.5846 14.031 2.5607 Ethane 1.5751 37.802 6.8990 Propane 2.7012 64.828 11.8311 Isobutane 0.8069 19.365 3.5342 n-Butane 2.8424 68.217 12.4496 Isopentane 0.9039 21.694 3.9591 n-Pentane 1.3253 31.808 5.8050 Cyclopentane 0.5345 12.828 2.3411 n-Hexane 0.6724 16.138 2.9452 Page: 2 Cyclohexane 1.3219 31.727 5.7901 Other Hexanes 0.8418 20.202 3.6869 Heptanes 1.1923 28.615 5.2222 Benzene 10.8956 261.495 47.7228 Toluene 13.1552 315.724 57.6196 Ethylbenzene 0.3495 8.389 1.5310 Xylenes 4.5048 108.116 19.7311 C8+ Heavies 2.3508 56.420 10.2966 Total Emissions 46.5583 1117.399 203.9253 Total Hydrocarbon Emissions 46.5583 1117.399 203.9253 Total VOC Emissions 44.3986 1065.565 194.4657 Total HAP Emissions 29.5776 709.861 129.5497 Total BTEX Emissions 28.9051 693.723 126.6045 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 21.4350 514.440 93.8853 Ethane 18.3766 441.038 80.4894 Propane 14.8905 357.373 65.2205 Isobutane 3.1692 76.060 13.8810 n-Butane 8.7921 211.011 38.5095 Isopentane 2.5847 62.033 11.3210 n-Pentane 3.1234 74.962 13.6806 Cyclopentane 0.3296 7.909 1.4435 n-Hexane 0.9470 22.729 4.1480 Cyclohexane 0.4869 11.686 2.1327 Other Hexanes 1.5344 36.826 6.7208 Heptanes 0.8904 21.370 3.9000 Benzene 0.6334 15.201 2.7743 Toluene 0.5313 12.750 2.3269 Ethylbenzene 0.0087 0.209 0.0382 Xylenes 0.0793 1.904 0.3475 C8+ Heavies 0.3929 9.430 1.7209 Total Emissions 78.2055 1876.931 342.5399 Total Hydrocarbon Emissions 78.2055 1876.931 342.5399 Total VOC Emissions 38.3939 921.453 168.1652 Total HAP Emissions 2.1997 52.794 9.6348 Total BTEX Emissions 1.2527 30.065 5.4869 COMBINED REGENERATOR VENT/FLASH GAS EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.0292 0.701 0.1279 Ethane 0.0782 1.877 0.3426 Propane 0.1308 3.138 0.5728 Isobutane 0.0379 0.909 0.1658 Page: 3 n-Butane 0.1297 3.113 0.5682 Isopentane 0.0361 0.866 0.1580 n-Pentane 0.0510 1.225 0.2235 Cyclopentane 0.0189 0.454 0.0828 n-Hexane 0.0199 0.477 0.0871 Cyclohexane 0.0326 0.782 0.1426 Other Hexanes 0.0283 0.679 0.1239 Heptanes 0.0198 0.476 0.0869 Benzene 0.2324 5.577 1.0178 Toluene 0.1360 3.264 0.5956 Ethylbenzene 0.0013 0.032 0.0058 Xylenes 0.0139 0.333 0.0608 O8+ Heavies 0.0002 0.004 0.0007 Total Emissions 0.9961 23.906 4.3628 Total Hydrocarbon Emissions 0.9961 23.906 4.3628 Total VOC Emissions 0.8887 21.328 3.8924 Total HAP Emissions 0.4035 9.683 1.7672 Total BTEX Emissions 0.3836 9.206 1.6801 COMBINED REGENERATOR VENT/FL➢SH GAS EMISSION CONTROL REPORT: Component Uncontrolled Controlled % Reduction tons/yr tons/yr Methane 96.4460 0.1279 99.87 Ethane 87.3884 0.3426 99.61 Propane 77.0516 0.5728 99.26 Isobutane 17.4152 0.1658 99.05 n-Butane 50.9590 0.5682 98.88 Isopentane 15.2801 0.1580 98.97 n-Pentane 19.4855 0.2235 98.85 Cyclopentane 3.7846 0.0828 97.81 n-Hexane 7.0932 0.0871 98.77 Cyclohexane 7.9228 0.1426 98.20 Other Hexanes 10.4077 0.1239 98.81 Heptanes 9.1222 0.0869 99.05 Benzene 50.4970 1.0178 97.98 Toluene 59.9465 0.5956 99.01 Ethylbenzene 1.5692 0.0058 99.63 Xylenes 20.0786 0.0608 99.70 C8+ Heavies 12.0175 0.0007 99.99 Total Emissions 546.4652 4.3628 99.20 Total Hydrocarbon Emissions 546.4652 4.3628 99.20 Total VOC Emissions 362.6309 3.8924 98.93 Total HAP Emissions 139.1845 1.7672 98.73 Total BTEX Emissions 132.0913 1.6801 98.73 EQUIPMENT REPORTS: CONDENSER AND COMBUSTION DEVICE Page: 4 Condenser Outlet Temperature: 120.00 deg. F Condenser Pressure: 12.50 psia Condenser Duty: 8.08e-002 MM BTU/hr Hydrocarbon Recovery: 2.13 bbls/day Produced Water: 16.31 bbls/day Ambient Temperature: 0.00 deg. F Excess Oxygen: 0.00 % Combustion Efficiency: 95.00 3 Supplemental Fuel Requirement: 8.08e-002 MM BTU/hr Component Emitted Destroyed Methane 4.99% 95.01% Ethane 4.97% 95.03% Propane 4.84% 95.16% Isobutane 4.69% 95.31% n-Butane 4.56% 95.44% Isopentane 3.99% 96.013 n-Pentane 3.85% 96.15% Cyclopentane 3.54% 96.46% n-Hexane 2.96% 97.04% Cyclohexane 2.46% 97.54% Other Hexanes 3.36% 96.64% Heptanes 1.66% 98.34% Benzene 2.13% 97.873 Toluene 1.03% 98.97% Ethylbenzene 0.383 99.62% Xylenes 0.31% 99.69% C8+ Heavies 0.01% 99.99% 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: 6.84 lbs. H2O/MMSCF Temperature: 120.0 deg. F Pressure: 1000.0 psig Dry Gas Flow Rate: 60.0000 MMSCF/day Glycol Losses with Dry Gas: 3.7963 lb/hr Wet Gas Water Content: Saturated Calculated Wet Gas Water Content: 102.41 lbs. H2O/MMSCF Calculated Lean Glycol Recirc. Ratio: 3.76 gal/lb H2O Remaining Absorbed Component in Dry Gas in Glycol Water 6.66% 93.34% Carbon Dioxide 99.693 0.31% Nitrogen 99.97% 0.03% Methane 99.973 0.03% Ethane 99.93% 0.07% Propane 99.89% 0.11% Isobutane 99.87% 0.13% n-Butane 99.84% 0.16% Isopentane 99.85% 0.15% n-Pentane 99.82% 0.18% Page: 5 Cyclopentane 99.22% 0.78% n-Hexane 99.75% 0.25% Cyclohexane 98.86% 1.14% Other Hexanes 99.808 0.20% Heptanes 99.60% 0.40% Benzene 91.088 8.92% Toluene 88.95% 11.05% Ethylbenzene 87.20% 12.80% Xylenes 82.75% 17.25% C8+ Heavies 98.92% 1.08% FLASH TANK Flash Control: Recycle/recompression Flash Temperature: 160.0 deg. F Flash Pressure: 30.0 psig Left in Removed in Component Glycol Flash Gas Water 99.83% 0.17% Carbon Dioxide 20.718 79.29% Nitrogen 2.56% 97.44% Methane 2.668 97.34% Ethane 7.89% 92.11% Propane 15.35% 84.65% Isobutane 20.29% 79.71% n-Butane 24.43% 75.57% Isopentane 26.288 73.72% n-Pentane 30.14% 69.86% Cyclopentane 62.05% 37.95% n-Hexane 41.81% 58.19% Cyclohexane 73.94% 26.06% Other Hexanes 36.078 63.93% Heptanes 57.46% 42.54% Benzene 94.78% 5.22% Toluene 96.43% 3.578 Ethylbenzene 97.82% 2.18% Xylenes 98.49% 1.51% C8+ Heavies 87.40% 12.60% REGENERATOR No Stripping Gas used in regenerator. Remaining Distilled Component in Glycol Overhead Water 34.64% 65.368 Carbon Dioxide 0.00% 100.00% Nitrogen 0.00% 100.00% Methane 0.00% 100.00% Ethane 0.00% 100.00% Propane 0.00% 100.00% Isobutane 0.00% 100.00% n-Butane 0.00% 100.00% Isopentane 1.90% 98.10% n-Pentane 1.66% 98.34% Page: 6 Cyclopentane 0.81% 99.19% n-Hexane 1.20% 98.80% Cyclohexane 4.33% 95.67% Other Hexanes 2.77% 97.23% Heptanes 0.87% 99.13% Benzene 5.28% 94.72% Toluene 8.20% 91.80% Ethylbenzene 10.65% 89.35% Xylenes 13.13% 86.87% C8+ Heavies 13.77% 86.23% STREAM REPORTS: WET GAS STREAM Temperature: 120.00 deg. F Pressure: 1014.70 psia Flow Rate: 2.51e+006 scfh Component Conc. Loading (vol%) (lb/hr) Water 2.16e-001 2.57e+002 Carbon Dioxide 2.65e+000 7.72e+003 Nitrogen 3.19e-001 5.91e+002 Methane 7.34e+001 7.78e+004 Ethane 1.34e+001 2.66e+004 Propane 5.75e+000 1.68e+004 Isobutane 8.l0e-001 3.11e+003 n-Butane 1.87e+000 7.18e+003 Isopentane 4.99e-001 2.38e+003 n-Pentane 5.13e-001 2.45e+003 Cyclopentane 2.39e-002 1.11e+002 n-Hexane 1.12e-001 6.38e+002 Cyclohexane 2.85e-002 1.59e+002 Other Hexanes 2.06e-001 1.17e+003 Heptanes 7.80e-002 5.17e+002 Benzene 2.50e-002 1.29e+002 Toluene 2.04e-002 1.24e+002 Ethylbenzene 3.99e-004 2.80e+000 Xylenes 3.79e-003 2.66e+001 C8+ Heavies 2.26e-002 2.55e+002 Total Components 100.00 1.48e+005 DRY GAS STREAM Temperature: 120.00 deg. F Pressure: 1014.70 psia Flow Rate: 2.50e+006 scfh Component Conc. Loading (vol%) (lb/hr) Water 1.44e-002 1.71e+001 Carbon Dioxide 2.65e+000 7.69e+003 Nitrogen 3.20e-001 5.91e+002 Page: 7 Methane 7.36e+001 7.78e+004 Ethane 1.34e+001 2.66e+004 Propane 5.76e+000 1.67e+004 Isobutane 8.11e-001 3.11e+003 n-Butane 1.87e+000 7.17e+003 Isopentane 5.Oce-001 2.38e+003 n-Pentane 5.14e-001 2.44e+003 Cyclopentane 2.38e-002 1.10e+002 n-Hexane 1.12e-001 6.36e+002 Cyclohexane 2.83e-002 1.57e+002 Other Hexanes 2.06e-001 1.17e+003 Heptanes 7.79e-002 5.14e+002 Benzene 2.29e-002 1.18e+002 Toluene 1.82e-002 1.10e+002 Ethylbenzene 3.49e-004 2.44e+000 Xylenes 3.15e-003 2.20e+001 C8+ Heavies 2.25e-002 2.52e+002 Total Components 100.00 1.48e+005 LEAN GLYCOL STREAM Temperature: 120.00 deg. F Flow Rate: 1.50e+001 gpm Component Conc. Loading (wt%) (1b/hr) TEG 9.85e+001 8.31e+003 Water 1.50e+000 1.27e+002 Carbon Dioxide 2.80e-011 2.36e-009 Nitrogen 2.31e-013 1.95e-011 Methane 8.76e-018 7.40e-016 Ethane 1.12e-007 9.42e-006 Propane 8.48e-009 7.16e-007 Isobutane 1.41e-009 1.19e-007 n-Butane 3.42e-009 2.89e-007 Isopentane 2.o8e-004 1.75e-002 n-Pentane 2.65e-004 2.24e-002 Cyclopentane 5.14e-005 4.34e-003 n-Hexane 9.64e-005 8.14e-003 Cyclohexane 7.08e-004 5.98e-002 Other Hexanes 2.64e-004 2.40e-002 Heptanes 1.24e-004 1.05e-002 Benzene 7.19e-003 6.07e-001 Toluene 1.39e-002 1.17e+000 Ethylbenzene 4.93e-004 4.16e-002 Xylenes 8.07e-003 6.81e-001 C8+ Heavies 4.45e-003 3.75e-001 Total Components 100.00 8.44e+003 RICH GLYCOL STREAM Temperature: 120.00 deg. F Pressure: 1014.70 psia Flow Rate: 1.58e+001 gpm NOTE: Stream has more than one phase. Page: 8 Component Conc. Loading (wt%) (lb/hr) TEG 9.41e+001 8.31e+003 Water 4.15e+000 3.66e+002 Carbon Dioxide 2.68e-001 2.36e+001 Nitrogen 2.21e-003 1.95e-001 Methane 2.50e-001 2.20e+001 Ethane 2.26e-001 2.00e+001 Propane 1.99e-001 1.76e+001 Isobutane 4.51e-002 3.98e+000 n-Butane 1.32e-001 1.16e+001 Isopentane 3.97e-002 3.51e+000 n-Pentane 5.07e-002 4.47e+000 Cyclopentane 9.84e-003 8.68e-001 n-Hexane 1.84e-002 1.63e+000 Cyclohexane 2.12e-002 1.87e+000 Other Hexanes 2.72e-002 2.40e+000 Heptanes 2.37e-002 2.09e+000 Benzene 1.38e-001 1.21e+001 Toluene 1.68e-001 1.49e+001 Ethylbenzene 4.53e-003 4.OOe-001 Xylenes 5.97e-002 5.27e+000 C8+ Heavies 3.54e-002 3.12e+000 Total Components 100.00 8.82e+003 FLASH TANK OFF GAS STREAM Temperature: 160.00 deg. F Pressure: 44.70 psia Flow Rate: 1.18e+003 scfh Component Conc. Loading (volt) (lb/hr) Water 1.13e+000 6.30e-001 Carbon Dioxide 1.37e+001 1.87e+001 Nitrogen 2.19e-001 1.90e-001 Methane 4.31e+001 2.14e+001 Ethane 1.97e+001 1.84e+001 Propane 1.09e+001 1.49e+001 Isobutane 1.76e+000 3.17e+000 n-Butane 4.88e+000 8.79e+000 Isopentane 1.15e+000 2.58e+000 n-Pentane 1.40e+000 3.12e+000 Cyclopentane 1.51e-001 3.30e-001 n-Hexane 3.54e-001 9.47e-001 Cyclohexane 1.86e-001 4.87e-001 Other Hexanes 5.74e-001 1.53e+000 Heptanes 2.86e-001 8.90e-001 Benzene 2.61e-001 6.33e-001 Toluene 1.86e-001 5.31e-001 Ethylbenzene 2.65e-003 8.73e-003 Xylenes 2.41e-002 7.93e-002 C8+ Heavies 7.43e-002 3.93e-001 Total Components 100.00 9.78e+001 Page: 9 FLASH TANK GLYCOL STREAM Temperature: 160.00 deg. F Flow Rate: 1.56e+001 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9.52e+001 8.31e+003 Water 4.19e+000 3.66e+002 Carbon Dioxide S.60e-002 4.89e+000 Nitrogen 5.73e-005 5.OOe-003 Methane 6.70e-003 5.85e-001 Ethane 1.81e-002 1.58e+000 Propane 3.10e-002 2.70e+000 Isobutane 9.25e-003 8.07e-001 n-Butane 3.26e-002 2.84e+000 Isopentane 1.06e-002 9.21e-001 n-Pentane 1.54e-002 1.35e+000 Cyclopentane 6.18e-003 5.39e-001 n-Hexane 7.80e-003 6.81e-001 Cyclohexane 1.58e-002 1.38e+000 Other Hexanes 9.92e-003 8.66e-001 Heptanes 1.38e-002 1.20e+000 Benzene 1.32e-001 1.15e+001 Toluene 1.64e-001 1.43e+001 Ethylbenzene 4.48e-003 3.91e-001 Xylenes 5.94e-002 5.19e+000 C8+ Heavies 3.12e-002 2.73e+0D0 Total Components 100.00 8.73e+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 Pressure: 14.70 psia Flow Rate: 5.32e+003 scfh Component Conc. Loading (vol8) (lb/hr) Water 9.47e+001 2.39e+002 Carbon Dioxide 7.92e-001 4.89e+000 Nitrogen 1.27e-003 5.OOe-003 Methane 2.60e-001 5.85e-001 Ethane 3.74e-001 1.58e+000 Propane 4.37e-001 2.70e+000 Isobutane 9.90e-002 8.07e-001 n-Butane 3.49e-001 2.84e+000 Isopentane 8.94e-002 9.04e-001 n-Pentane 1.31e-001 1.33e+000 Cyclopentane 5.44e-002 5.35e-001 Page: 10 n-Hexane 5.57e-002 6.72e-001 Cyclohexane 1.12e-001 1.32e+000 Other Hexanes 6.97e-002 8.42e-001 Heptanes 8.49e-002 1.19e+000 Benzene 9.95e-001 1.09e+001 Toluene 1.02e+000 1.32e+001 Ethylbenzene 2.35e-002 3.50e-001 Xylenes 3.03e-001 4.50e+000 C8+ Heavies 9.84e-002 2.35e+000 Total Components 100.00 2.90e+002 CONDENSER PRODUCED WATER STREAM Temperature: 120.00 deg. F Flow Rate: 4.76e-001 gpm Component Conc. Loading (wt%) (lb/hr) (ppm) Water 9.99e+001 2.38e+002 998853. Carbon Dioxide 1.54e-002 3.67e-002 154. Nitrogen 4.15e-007 9.88e-007 0. Methane 9.37e-005 2.23e-004 1. Ethane 2.86e-004 6.80e-004 3. Propane 4.94e-004 1.18e-003 5. Isobutane 7.79e-005 1.85e-004 1. n-Butane 3.55e-004 8.45e-004 4. Isopentane 6.95e-005 1.65e-004 1. n-Pentane 1.06e-004 2.51e-004 1. Cyclopentane 2.75e-004 6.53e-004 3. n-Hexane 3.41e-005 8.11e-005 0. Cyclohexane 3.15e-004 7.49e-004 3. Other Hexanes 3.91e-005 9.30e-005 0. Heptanes 1.89e-005 4.49e-005 0. Benzene 6.32e-002 1.50e-001 632. Toluene 3.04e-002 7.24e-002 304. Ethylbenzene 2.25e-004 5.36e-004 2. Xylenes 3.25e-003 7.73e-003 32. C8+ Heavies 9.30e-008 2.21e-007 0. Total Components 100.00 2.38e+002 1000000. CONDENSER RECOVERED OIL STREAM Temperature: 120.00 deg. F Flow Rate: 6.21e-002 gpm Component Conc. Loading (wt8) (lb/hr) Water 5.76e-002 1.52e-002 Carbon Dioxide 7.12e-002 1.88e-002 Nitrogen 4.79e-005 1.26e-005 Methane 2.34e-003 6.18e-004 Ethane 3.82e-002 1.O1e-002 Propane 3.20e-001 8.46e-002 Isobutane 1.87e-001 4.95e-002 n-Butane 9.34e-001 2.47e-001 Isopentane 6.89e-001 1.82e-001 n-Pentane 1.15e+000 3.04e-001 Page: 11 Cyclopentane 5.90e-001 1.56e-001 n-Hexane 1.04e+000 2.75e-001 Cyclohexane 2.53e+000 6.70e-001 Other Hexanes 1.04e+000 2.76e-001 Heptanes 3.01e+000 7.95e-001 Benzene 2.31e+001 6.10e+000 Toluene 3.92e+001 1.04e+001 Ethylbenzene 1.22e+000 3.22e-001 Xylenes 1.60e+001 4.22e+000 C8+ Heavies 8.88e+000 2.35e+000 Total Components 100.00 2.64e+001 CONDENSER VENT STREAM Temperature: 120.00 deg. F Pressure: 12.50 psia Flow Rate: 2.02e+002 scfh Component Conc. Loading (vol%) (lb/hr) Water 1.36e+001 1.31e+000 Carbon Dioxide 2.06e+001 4.83e+000 Nitrogen 3.34e-002 4.98e-003 Methane 6.84e+000 5.64e-001 Ethane 9.77e+000 1.56e+000 Propane 1.11e+001 2.62e+000 Isobutane 2.45e+000 7.57e-001 n-Butane 8.39e+000 2.59e+000 Isopentane 1.86e+000 7.22e-001 n-Pentane 2.66e+000 1.02e+000 Cyclopentane 1.O1e+000 3.78e-001 n-Hexane 8.67e-001 3.9Be-001 Cyclohexane 1.45e+000 6.51e-001 Other Hexanes 1.23e+000 5.66e-001 Heptanes 7.44e-001 3.97e-001 Benzene 1.12e+001 4.65e+000 Toluene 5.55e+000 2.72e+000 Ethylbenzene 4.72e-002 2.66e-002 Xylenes 4.91e-001 2.78e-001 C8+ Heavies 3.41e-003 3.09e-003 Total Components 100.00 2.61e+001 COMBUSTION DEVICE OFF GAS STREAM Temperature: 1000.00 deg. F Pressure: 14.70 psia Flow Rate: 6.63e+000 scfh Component Conc. Loading (volt) (lb/hr) Methane 1.04e+001 2.92e-002 Ethane 1.49e+001 7.82e-002 Propane 1.70e+001 1.31e-001 Isobutane 3.73e+000 3.79e-002 n-Butane 1.28e+001 1.30e-001 Isopentane 2.86e+000 3.61e-002 Page: 12 n-Pentane 4.05e+000 5.10e-002 Cyclopentane 1.54e+000 1.89e-002 n-Hexane 1.32e+000 1.99e-002 Cyclohexane 2.21e+000 3.26e-002 Other Hexanes 1.88e+000 2.83e-002 Heptanes 1.13e+000 1.98e-002 Benzene 1.70e+001 2.32e-001 Toluene 8.44e+000 1.36e-001 Ethylbenzene 7.18e-002 1.33e-003 xylenes 7.47e-001 1.39e-002 C8+ Heavies 5.18e-003 1.54e-004 Total Components 100.00 9.96e-001 dor ' 1nt 162-144-, MP ACT ANALYTIC lllc INC. . a1 YSTEMS �' MILO/it vAr BRIGHTON,365 S' CO ; 80601 303-837-0150 EXTENDED NATURAL GAS ANALYSIS 0DHA) MAIN PAGE, PROJECT NO. : 201103130 ANALYSIS NO.: 02 COMPANY NAME: OCP MIDSTREAM-LP ANALYSIS DATE: MARCH 19,2011 ACCOUNT NO. : SAMPLE DATE : MARCH 18,2011 PRODUCER : CYLINDER NO.: 888 LEASE NO. : SAMPLED BY : STEPHEN ONDAK NAMEJDESCRIP: ENTERPRISE INLET PRE DENY®14:30 "'FIELD DATA"' SAMPLE TEMP.: 100 SAMPLE PIES.: 900 AMBIENT TEMP.: .. VAPOR PRES. : GRAVITY . COMMENTS : SPOT;NO PROBE GPM® GPM® COMPONENT MOLE% MASS% 14.650 14.730 ALCOHOLS 0.0006 0.0016 HELIUM 0.01 0.00 --- --- HYDROGEN 0.00 0.00 --- -- OXYGEN/ARGON 0.01 0.01 --- -- NITROGEN 0.32 0.40 --- -- CARBON DIOXIDE 2.59 5.09 --- -- METHANE 73.60980 52.69890 -- -- ETHANE 13.4436 18.0401 3.5886 3.6082 PROPANE 5.7633 11.3416 1.5851 1.5938 I-BUTANE 0.8191 2.1247 0.2872 0.2688 N-BUTANE 1.8738 4.8604 0.6894 0.5928 I-PENTANE 0.5245 1.8888 0.1901 0.1911 N-PENTANE 0.5144 1.8563 0.1861 0.1871 HEXANES PLUS 0.5210 2.0898 0.2930 a2940 TOTALS 100.00000 100.0000D 6.6995 6.7354 BTU COMPONENTS MOLE% OT% BTU® 14.850 14.730 BENZENE 0.0251 0.0875 LOW NET DRY REAL: 1183.7 hcf 1170.1 lid TOLUENE 0.0204 0.0839 NET WET REAL: 1143.4 hcf 1149.7 hH ETHYLBENZENE 0.0004 0.0019 HIGH GROSS DRY REAL: 1280.8 luf 1287.8 he XYLENES 0.0038 0.0181 GROSS WET REAL: 1268.4 tad 1285.4 lid TOTAL BTEX 0.0497 0.1914 NET DRY REAL: 19719.6 Mb 19827.3 f b GROSS ORY REAL: 21713.0/15 21831.5/Ib RELATIVE DENSITY(AIR=1): 0.7727 ICAIL.'Oat STD 2I.(1 A 7r.JJVVL698 a MBE) COMPRESSIBILITY FACTOR : 0.99818 YDATALLFJ)HTDROCARBONANALYMSOLI!WV:AMfD6730 MIS DATA lUSBEFXACQIRRED TflROfNDI APPLICATION OF CURRENT SGTFOF-7NC./RTANILITICAL YECHNJQUIS ME(ATE OF 171ST 1NPVjWA(ION(S THEREPONSIBUITOF Mg USER.EliPACIAN4LYHCALST3W.R ASSUMES 10 MTPO,YSIBUIY FOR ACCURACY OFWEREFORIFD;N ORMA?I HOFAMCONSEQIHM'F3'W'ITSAEFLICAHON. I is MPACT ANALYTICAL YSTEMS INC. LUL ut*hit Auto/Sir `Y365 S.MAIN ST. "hA\\II irlie L . BRIGHTON, CO //;I/////! 80601 V Sim 303.637.0180 EXTENDED NATURAL GAS ANALYSIS("DHA) OLYCALC INFORMATION PROJECT NO. : 201103130 ANALYSIS NO.: 02 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: MARCH 19,2011 ACCOUNT NO. : SAMPLE DATE : MARCH 18,2011 PRODUCER : CYLINDER NO.: 868 LEASE NO. : SAMPLED BY : STEPHEN ONDAK NAME/DESCRIP: ENTERPRISE INLET PRE DENY @@ 14:30 ""'FIELD DATA*** SAMPLE TEMP.: 100 SAMPLE PRES.: 900 AMBIENT TEMP.: VAPOR PRES. : GRAVITY . COMMENTS : SPOT;NO PROBE Componet Mole% W1.4 Helium 0.01 0.00 Hydrogen 0.00 0.00 Carbon Dloxlde 2.59 5.09 Nitrogen 0.32 0.40 Methane 73.60980 52.69890 Ethane 13.4435 18.0401 Propane 6.7833 11.3418 Isobulane 0.8191 2.1247 n-Butane 1.8738 4.8804 Isopentane 0.5005 1.6115 n-Pentane 0.5144 1.6583 Cyclopentane 0.0240 0.0751 n-Hexane 0.1123 0.4319 Cyclohexane 0.0286 0.1074 Other Hexane 0.2068 0.7920 • Haplanes 0.0782 0.3486 Methycydohexane 0.0227 0.0995 2,2,4 Trimethylpentane 0.0000 0.0000 Benzene 0.0251 0.0875 Toluene 0.0204 0.0839 Ethylbenzene 0.0004 0.0019 Xylenes 0.0038 0.0181 C8*Heavies 0.0227 0.1190 Subtotal 99.98940 99.98840 Oxygen/Argon 0.01 0.01 Alcohols 0.0006 0.0016 Tetel 100.00000 100.00000 THE DATA PRESENTED HEREIN HAS SEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT STATE•OF•THE ART ANALYTICAL TECHNIQUES. THE APPLICATIONS OF THIS INFORMATION IS THE RESPONSIBILITY OF THE USER. EMPACTANALYTICAL SYSTEMS INC.ASSUMES NO RESPONSIBILITY FOR ACCURACY OF THE REPORTED INFORMA HON NOR ANY CONSEQUENCES OF IFS APPLICATION. ...-- ; ev.. '&II._ EMPACT ►%is -",Ii 122g, e'1/41.1hi.-A 1.._6-I.___`. y.7CPFNDED NATURAL FAR ANALYSIS f*DHAI PHA COMPONENT LIST PROJECT NO. : 201103130 ANALYSIS NO.: 02 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: MARCH 19,2011 ACCOUNT NO. : SAMPLE DATE: MARCH It,7011 PRODUCER : CYLINDER 140.: 886 LEASE NO. : SAMPLED BY : STEPHENONOAK NAL1P/DESCRIP: ENTERPRISE INLET PRE DENY @14:30 aaaPIELD DATA" SAMPLE TEMP.: 100 SAMPLE PRES.: 900 AMBIENT TEOIP. VAPORPRE&: GRAVITY : COMMENTS : SPOT,NO PROBE GPM® OPM® COMPONENT PIANO MOLE% MASS 54 14.650 14.730 Helium ... 0.01 0.00 -- -.- NyimKn ..- 0.00 0.00 -- --. Own/Argon --- 0.01 001 - --- Ninon --- 0.32 0.40 --- --- CarbonDiwide --- 239 5.09 --. --- Methane PI 73.60%0 52.69890 --- --- Ethane P2 13.4435 18.0401 3.5886 3.6081 Propane P3 5.7633 11.3416 15851 1.5931 I-Wane 14 08191 2.1297 02671 0.2686 n-Bulane P4 1.8738 4.8604 0.5894 0.5916 2,2-Dimechylprepane IS 0.0051 0.0164 0.0020 0.0020 Elhnel 7.2 00001 0.0002 0.0000 0.0000 1-Pentane 15 0.4954 1.5951 0.1811 01821 i-Pmpand X3 0.0004 0.0011 0.0000 0.0000 n-Ptnbge PS 03144 1.6563 0.1261 01871 2,2-Dlme3I)tM ne 16 0.0072 0.0177 0.0030 0.0030 6-Pmpen0l X3 0.0001 0.0003 0.0000 0.0000 C)cbpmtane NS 0.0240 0.0751 0.0070 0.0070 2.3-DimNglbmne 16 0.0160 0.0615 0.0070 0.0070 2-Melhylpemaoe 16 0.0971 0.3735 0.0400 0.0402 3.31ethylpentene 16 0.0492 0.1892 0.0200 0.0201 a-Hexane 76 0.1123 0.4319 0.0160 0.0463 2,2.Dimelhylpealane 17 0.0012 0.0098 0.0010 0.0010 MNNyleyelopenlane N6 0.0373 01401 0.0130 0.0131 7,443imeihylpentue I7 0.0041 0.0183 0.0020 0.0010 2,23-TrimethylLuwre I7 0.0004 0.0018 0.0000 00000 Beane. A6 0.0231 0.0873 0.0070 0.0070 3,3-Dime®ylpenuee 17 0.0008 0.0036 0.0000 0.0000 Cyclohexane 146 0.0286 0.1074 0.0100 00101 LMethylhame H 0.0146 0.0653 0.0070 0.0070 23-D'methylpm ene 17 0.0036 0.0161 0.0020 00020 I,I-0Imetgkydopenlane 147 0.0033 0.0145 0.0010 00010 3-hleihylhocme 17 00129 0.0377 0.0060 0.0060 I43'Dimethylgelopeelene N7 0.0035 0.0154 00020 0.0020 IL3-D2nethylnydopenlme N7 0.0031 0.0136 0.0010 0.0010 3-ElhylpeWme 17 0.0003 0.0013 0.0000 0.0000 11,2-INmehylcydopmene N7 0.0051 0.0224 0.0020 0.0010 n-Nepla a P7 0.0133 0.1042 0.0110 0.0111 Ie,2.Dimlhykryclopcniane N7 0.0001 0.0005 00000 0.0000 Pp.I EIIPACTAmytW Symmm,toe 3068.Met Slre.L 860hIm,CO 80001 303437-0150 Mahylwebhe ne N7 00227 0.0995 0.0090 00091 2,2-DImclhylhexnc II 0.0009 0.0016 0.0000 0.0000 1,1,3.Trimetbylcyclopeatanc N7 00003 0.0015 0.0000 00000 E41014111004.1em N7 00006 0.0026 0.0000 00000 2,5•D)me005hesan IS 00007 00036 0.0000 40000 2,4•Dimetbylhcxte I8 0.0006 0.0041 0.0000 0.0000 I;2 4-Trimelhylcyelapemne NB 0.0007 0.0035 0.0000 0.0000 3.3-Dlmahylhexane IS 0.0002 00010 0.0000 00000 II.2o.4•'R melhylcktIopenune NI 00005 00025 0.0000 0.0000 Toluca A7 0.0204 00839 0.0070 0.0070 2)-DimMylkenne I8 40004 0.0021 0.0000 0.0000 241081464110811 IS 0.0028 00143 0.0010 0.0010 44leth0lhepne II 0.0009 0.0016 0.0000 0.0000 3•Mel0y1.3• hylpenine II 0.0001 (w005 0.0000 0.0000 3Mahylhepme II 0.0001 00005 0.0000 0.0000 le,2t,3Trimelby1cycicpemme NB 0.0035 0.0175 00020 0.0020 3413,44hexne II 40002 0.0010 00000 0.0000 11A•Dime00igtlohexna NB 0.0009 0.0045 0.000) 0.0000 1,14)ImAyleycbhesan NB 00004 0.0020 0.0000 00000 31-EAhylnMhylLydopalme NB 0.0001 0.0005 0.0000 0.0000 21-Elhylmelhykydopame NB 0.0001 0.0005 0.0000 0.0000 1,1-hlahylethylryelopemne 148 0.0001 0.0005 0.0000 00000 142-Dimelhyicyclohane MI 0.0006 0.0030 0.0000 00000 6-Octane P8 0.0036 00183 0.0020 40020 Ip4.Dimeth3leyelobeaoa 248 0.0002 0.0010 00000 0.0000 23,5-Trimahy0wnenc 19 40001 00006 40000 0.0000 2,3,4-Trimahylhaene 9 0.0003 0.0006 0.0000 0.0000 Ic,2•Dinahylcycbhemaa N8 00001 00005 0.0000 0.0000 1,1,4•TrimethyIyclohecns N9 0.0007 0.0039 0.0000 0.0000 2,2,3-Thmetdiihexaue 19 00002 0.0012 0.0000 0.0000 EOtylyclohaese N8 0.0002 0.0010 0.0000 0.0000 n•PI4Pykyclspemane N8 00002 0.0010 0.0000 0.0000 14,38,5-Trimclltyl yclohcvue N9 0.0001 0.0006 0.0000 0.0000 EOrylbenaeoe I6 0.0004 0.0019 00000 0.0000 Ie,b,4t•Tdmefhylcyclohexana N9 0.0001 0.0006 0.0000 0.0000 1.7•IXmethyl6eoum(m-Xylene) AS 0.0023 0.0109 0.0010 00010 L.4.Dlmahylbenuoc(p•XYlate) A8 0.0309 0.0043 0.0000 0.0000 3,4.Dlmahylltgnnp 19 0.0302 00012 00000 00000 3.4-Dlmmhylhepine(2) 19 0.0001 40006 0.0030 0.0000 4-EIOdWeptne 19 0.0001 0.0006 00000 0.0000 4.63 ylacmse 19 40002 0.0012 0.0000 0.0000 2\Ie0 4440vie 19 0.0032 0.0012 00000 0.0000 1\%Ihylocin. 19 0.0002 0.0012 0.0000 0.0000 l,2-gme4yibenune(o•Xyh%e) AS 0.0006 40029 0.0000 0.0000 i•Bmylcyclopemme N9 0.0001 00006 0.0000 00000 Unb.ownctl UB 0.0002 0.0010 40000 0.0000 *Nome P9 0.0006 0.0034 0.0000 0.0000 a41a05cyclopmune N9 40001 00006 40000 0.0000 e•P,opyibeaune A9 0.0001 00005 0.0000 0.0000 1,1. 14404elhy16emme A9 0.0001 0.0005 0.0000 0.0000 l.3,531methylbenan% A9 0.0001 00005 0.0000 0.0000 t-Butylbenzwe A10 0.0001 0.0006 0.0000 00000 Umb owoC9s U9 40003 00017 0.0000 00000 a-Decane PIO 0.0001 0.0006 0.0000 00000 UnblownClOs U10 0.0001 00006 0.0000 0.0000 UnhnowvCl&s U18 08002 0.0023 0.0000 0.0000 TOTAL 100.00000 100.00000 46095 6.6454 BTEXCOMFONENTS MOLE% %T% HTU® 14.850 14.730 BENZENE 0.0261 0.0078 LOW NET DRY REAL: 1163.7 Ott 1170.1 her TOLUENE 0.0204 00830 NET WET REAL: 1143.4 fief 11491 her ETNYLBENZENE 00004 00010 DIOR GROSS DRY REAL: 1200.8 Ad 1287.8 Aef XYLEIEO 0.0050 0.0101 GROSSWET REAL: 1268.4 Oct 1260.4 Acf TOTALBTEX 0.0487 0.1914 NET DRY REAL: 19719.066 18827.381 GROSS DRY REAL: 20713.0 61 11031.6 41 RELATIVE DENSITY(A1 R•1): 0.7727 CAIna)A3N!ILIA mR91 tall e Nee COMPRESSIBIUIY FACTOR: 0.09610 •aHTAIIEDa7amARfVAYALta9NLIIV6;WUD100 annum It 4S SW ACQUIRED mmwH AM/CUM a c'a.wreraeeoFIwESMALneae ua7c Qtu RIrL.EWelate'10011,11x'amaREYa4efJII chlel7tlt WEICTAMILJI7C.lt a13mf4 A018m00 RIWtARRRagtxttLIEClol ITIEADOJITEDno.£og'WAAMMMATELX.eWLVOV WWI'Mang Pews 2 EMPACT Amylct Systems.Inc 3658.Nab Street Mahlon.CO 00801 303. 37.0160 I 1 n I I 1 GM ' cr HU t w FFFF it a 46....- rA O 0 t rn Zg ,i Ind . . �l A a 8 W Z • fl W8 # 0 At 0 jjS��'$��y1 m to it x g 0 14 QC V Y O pfp m T 1. 39 6 MM -A, .11:: b� � jJ • d "f L • it CI 21 • n Y • ''js Q." •rfl. Y 6i z•. E +Z ��y 12q 19 Q - f +�q�= u r.i: �■�' g� age $M MPACT ANALYTICAL SYSTEMS INC. 365 S. MAIN ST. BRIGHTON, CO JL 80601 303-637-0150 EXTENDED NATURAL GAS LIOUID ANALYSIS(`DHAI MAIN PAGE PROJECT NO. : 201105150 ANALYSIS NO.: 01 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: JUNE 3,2011 ACCOUNT NO. : SAMPLE DATE : MAY 26,2011 PRODUCER : CYLINDER NO.: 2821 LEASE NO. : SAMPLED BY : 3.MOSER NAME/DESCRIP: ENTERPRISE COMPRESSOR EMPACT 3 PHASE SEPARATOR @12:00 ***FIELD DATA••• SAMPLE TEMP.: 106 SAMPLE PRES.: 30 AMBIENT TEMP.: VAPOR PRES. : GRAVITY . COMMENTS : SPOT;NO PROBE COMPONENT MOLE% MASS% VOL NITROGEN(AIR) 0.0284 0.0087 0.0076 CARBON DIOXIDE 0.0667 0.0321 0.0276 METHANE 0.2743 0.0481 0.1130 ETHANE 0.8199 0.2693 0.5324 PROPANE 3.0885 1.4877 2.0666 I-BUTANE 1.5839 1.0055 1.2581 N-BUTANE 5.5719 3.5372 4.2657 1-PENTANE 4.1245 3.2503 3.6658 N-PENTANE 5.5219 4.3516 4.8559 HEXANES PLUS 78.9200 86.0095 83.2073 TOTALS 100.0000 100.0000 100.0000 BTEX COMPONENTS MOLE% MASS% (CALC: GPA STD 2145-94&TP-17(@14.696&60 F) BENZENE 1.5855 1.3527 TOTAL C6+ TOLUENE 4.4720 4.5007 SAMPLE FRACTION ETHYLBENZENE 0.2952 0.3423 Specific Gravity(1120=1) = 0.7043 0.7274 60/60 XYLENE 2.7873 3.2323 API Gravity = 69.41 63.03 60/60 TOTAL BTEX 9.1400 9.4280 Molecular Weight = 91.55 99.984 Absolute Density — 5.87 6.07 LBS/GAL Heating Value Liq.Idl Gas= 119555 123799 BTU/GAL Vapor/Liquid = 24.20 23.07 CUFT/GAL Vapor Pressure = 34.02 2.76 PSIA @100 F NDETAILED HYDROCARBON ANALISISW.1 1993);ASTMD6730 THIS DATA HAS BEEN ACQUIRED THROUGHAPPL!CATION OF CURRENT STATE-OF-THE-ART ANALYTICAL TECHNIQUES THE USE OF THIS INFORMATION IS THE R.EIPONSIBL III OF THE USER. EMPACT ANALYTICAL SYSTEMS ASSUMES NO RESPONSJBLITYFOR ACCURACY OF THE REPORTED JNFORMADONNOR ANY CONSEQUENCES OF ITS APPLICATION. EMPACT ANALYTICAL SYSTEMS INC. 365 S. MAIN ST. BRIGHTON,CO 80601 303-637-0150 EXTENDED NATURAL GAS LIQUID ANALYSIS rDHA) E&P TANK/GLYCALC INFORMATION PROJECT NO. : 201105150 ANALYSIS NO.: 01 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: JUNE 3,2011 ACCOUNT NO. : SAMPLE DATE : MAY 26.2011 PRODUCER : CYLINDER NO.: 2821 LEASE NO. : SAMPLED BY : J.MOSER NAMEJDESCRIP: ENTERPRISE COMPRESSOR EMPACT 3 PHASE SEPARATOR 012:00 "'FIELD DATA"' SAMPLE TEMP.: 106 SAMPLE PRES.: 30 AMBIENT TEMP.: VAPOR PRES. : GRAVITY . COMMENTS : SPOT;NO PROBE COMPONENT Mole% Wt% LV% CARBON DIOXIDE 0.0667 0.0321 0.0276 NITROGEN(AIR) 0.0284 0.0087 0.0076 METHANE 0.2743 0.0481 0.1130 ETHANE 0.8199 0.2693 0.5324 PROPANE 3.0885 1.4877 2.0666 I-BUTANE 1.5839 1.0055 1.2581 N-BUTANE 5.5719 3.5372 4.2657 I-PENTANE 4.1245 3.2503 3.6658 N-PENTANE 5.5219 4.3516 4.8559 CYCLOPENTANE(N-05) 0.5479 0.4197 0.3888 N-HEXANE 10.3687 9.7595 10.3548 CYCLOHEXANE(OTHER C6) 3.0484 2.8022 2.5190 OTHER HEPANES 15.0673 14.1140 14.6408 OTHER HEPTANES 15.7930 17.2287 17.3737 METHYLCYCLOHEXANE(OTHER C7) 5.1024 5.4723 4.9748 2.2,4TRIMETHYLPENTANE 0.5059 0.5426 0.5072 BENZENE 1.5855 1.3527 1.0790 TOLUENE 4.4720 4.5007 3.6256 ETHYLBENZENE 0.2952 0.3423 0.2757 XYLENES 2.7873 3.2323 2.6141 OTHER OCTANES 10.6105 13.2502 12.8308 OCTANES PLUS -- 22.9348 - 30.3597 - 28.2508 NONANES 4.9634 6.8883 6.4556 DECANES PLUS 3.7725 6.1040 5.5674 TOTAL 100.0000 100.0000 100.0000 API Gravity 69.41 60/60 Vapor Pressure = 34.02 PSIA&100 F Average Molecular Weight of Decanes plus = 14.14 Average Specific Gravity of Decanes plus = 0.7740 THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT STATE-OF-THE ART ANALYTICAL TECHNIQUES. THE APPLICATIONS OF THIS INFORMATION IS THE RESPONSIBILITY OF THE USER EMPACTANALYTICAL SYSTEMS,INC.ASSUMES NO RESPONSIBILITY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF ITS APPLICATION.' EMPACT ANALYTICAL SYSTEMS INC. 365 S. MAIN ST. BRIGHTON, CO 80601 303-637-0150 EXTENDED NATURAL GAS LIQUID ANALYSIS(*DNA) DHA COMPONENT LIST PROJECT NO. : 201105150 ANALYSIS NO.: 01 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: JUNE 3,2011 ACCOUNT NO. : SAMPLE DATE : MAY 26,2011 PRODUCER : CYLINDER NO.: 2821 LEASE NO, : SAMPLED BY : J.MOSER NAME/DESCRIP: ENTERPRISE COMPRESSOR EMPACT 3 PHASE SEPARATOR @12:00 "'FIELD DATA"' SAMPLE TEMP.: 106 SAMPLE PRES.: 30 AMBIENT TEMP.: VAPOR PRES. : GRAVITY . COMMENTS : SPOT;NO PROBE COMPONENT PIANO# MOLE% MASS% VOL% Nitrogen 0.0284 0.0087 0.0078 Carbon Dioxide 0.0667 0.0321 0.0276 Methane P1 0.2743 0.0481 0.1130 Ethane P2 0.8199 0.2693 0.5324 Propane P3 3.0885 1.4877 2.0666 i-Butane 14 1.5839 1.0055 1.2581 n-Butane P4 5.5719 3.5372 4.2657 2,2-Dimethylpropane 15 0.0300 0.0236 0.0278 i-Pentane 15 4.0945 3.2267 3.6380 n-Pentane P5 5.5219 4.3516 4.8559 2,2-Dimethylbutane 16 0.3632 0.3419 0.3682 Cydopentane N5 0.5479 0.4197 0.3888 2,3-Dimethylbutane 16 1.1668 1.0983 1.1597 2-Methylpentane 16 6.6067 6.2190 6.6586 3-Methylpentane 16 3.8006 3.5776 3.7667 n-Hexane P6 10.3687 9.7595 10.3548 2,2-Dimethylpentane 17 0.2513 0.2750 0.2840 Methylcydopentane N6 3.1300 2.8772 2.6876 2,4-Dimethytpentane 17 0.5598 0.6127 0.6380 2,2,3-Trimethylbutane 17 0.0640 0.0700 0.0709 Benzene A6 1.5855 1.3527 1.0790 3,3-Dimethylpentane 17 0.1550 0.1696 0.1718 Cydohexane N6 3.0484 2.8022 2.5190 2-Methylhexane 17 2.5078 2.7447 2.8329 2,3-Dimethylpentane 17 0.8002 0.8758 0.8782 1,1-Dimethylcydopentane N7 0.4969 0.5329 0.4943 3-Methylhexane 17 2.6113 2.8579 2.9053 1c,3-Dimethylcydopentane N7 0.5694 0.6107 0.5738 11,3-Dimethylcyclopentane N7 0.5059 0.5426 0.5072 3-Ethyipentane 17 0.1701 0.1862 0.1862 11,2-Dlmethylcydopentane N7 0.7986 0.8565 0.7978 2,2,4-Trimettylpentane 18 0.0391 0.0488 0.0492 n-Heptane P7 6.1240 6.7024 6.8586 1c,2-Dimethylcydopentane N7 0.0341 0.0366 0.0332 Methylcydohexane N7 5.1024 5.4723 4.9748 2,2-Dimethylhexane 18 0.4695 0.5858 0.5893 Ethylcyclopentane N7 0.1446 0.1551 0.1417 2,5-Dimethylhexane 18 0.2747 0.3427 0.3456 2,2,3-Trlmethylpentane 18 0.0160 0.0200 0.0196 2,4-Dimethylhexane 18 0.3531 0.4406 0.4422 1c,2t,4-Trimethylcyclopentane N8 0.2139 0.2622 0.2404 3,3-Dimethylhexane 18 0.1006 0.1255 0.1238 2,3,4-Trimethylpentane 18 0.0151 0.0188 0.0183 2,3,3-Trime8tylpentane 18 0.0160 0.0200 0.0193 Toluene A7 4.4720 4.5007 3.6256 2,3-Dimethylhexane IB 0.1952 0.2436 0.2396 2-Methyl3-ethylpentane IB 0.0384 0.0479 0.0466 1,1,2-Trimethylcydopentane N8 0.0156 0.0191 0.0173 2-Methylheptane 18 1.5176 1.8935 1.8954 4-Methylheptane 18 0.5377 0.6709 0.6554 3-Methyl-3-ethylpentane 18 0.0458 0.0571 0.0550 3,4-Dimethylhexane 18 0.0838 0.1046 0.1017 1c,2c,4-Trlmethylcydopentane N8 0.0208 0.0255 0.0231 1c,3-Dimethylcyclohexane NB O0167 0.0205 0.0187 3-Methylheptane 18 1.1214 1.3992 1.3885 1c,2t,3-Trimethylcydopentane N8 0.9891 1.2123 1.1017 3-Ethyhexane 18 0.0641 0.0800 0.0788 1t,4-Dimethylcydohexane N8 0.4727 0.5794 0.5320 1,1-Dlmethylcydohexane N8 0.1686 0.2066 0.1853 2,2,5-Trimethylhexane 19 0.0188 0.0263 0.0259 3t-Ethylmethylcydopentane N8 0.0329 0.0403 0.0368 2t-Ethylmethylcydopentane NB 0.0293 0.0359 0.0327 1,1-Methylethylcyclopentane N8 0.0483 0.0592 0.0531 2,2,4-Trimethylhexane 19 0.0134 0.0188 0.0184 1t,2-Dlmethylcydohexane NB 0.3000 0.3677 0.3319 1 c,20,3-Trimethylcydopentane NB 0.0020 0.0024 0.0022 1t,3-Dimethylcydohexane NB 0.0030 0.0037 0.0033 n-Octane P8 2.6376 3.2909 3.2785 1c,4-Dimethylcyclohexane NB 0.4566 0.5596 0.5006 i-Propylcydopentane 18 0.0316 0.0387 0.0349 2,4,4-Trlmethylhexane 19 0.0142 0.0199 0.0193 2,2,3,4-Tetramethylpentane 19 0.0175 0.0245 0.0239 2,3,4-Trimethylhexane 19 0.0887 0.1243 0.1206 1c,2-DImethylcyclohexane NB 0.1905 0.2335 0.2054 2,3,5-Trimethylhexane 19 0.0182 0.0227 0.0220 2,2-Dimethylheptane 19 0.0061 0.0085 0.0084 1,1,4-Trimet ylcyclohexane N9 0.4337 0.5980 0.5426 2,2,3-Trimethylhexane 19 0.2723 0.3815 0.3883 2,4-Dimethylheptane 19 0.0127 0.0178 0.0174 4,4-Dlmethylheptane 19 0.0178 0.0249 0.0244 Ethylcyclohexane NB 0.1758 0.2155 0.1916 n-Propylcyclopentane N8 0.3321 0.4070 0.3670 1c,3c,5-Trimethylcydohexane N9 0.0857 0.1182 0.1072 2,5-Dimethylheptane 19 0.0119 0.0167 0.0163 3,3-Dimethylheptane 19 0.0156 0.0219 0.0214 3,5-Dlmethylheptane 19 0.0097 0.0136 0.0133 2,6-Dlmethylheptane 19 0.0043 0.0060 0.0059 1,1,3-Trimethylcydohexane N9 0.0287 0.0396 0.0359 Ethylbenzene A8 0.2952 0.3423 0.2757 1c,2t,4t-Trimethylcydohexane N9 0.0069 0.0095 0.0085 2,3-Dimethylheptane 19 0.0187 0.0262 0.0253 1,3-Dlmethylbenzene(m-Xylene) A8 1.7410 2.0190 1.6356 1,4-Dimethylbenzene(p-Xylene) AB 0.6596 0.7649 0.6216 3.4-Dimethylheptane 9 0.0716 0.1003 0.0960 3,4-Dlmethylheptane(2) 9 0.0675 0.0946 0.0906 4-Ethylheptane 9 0.0615 0.0862 0.0844 4-Methylocane 9 0.2624 0.3676 0.3572 2-Metyloctane 9 0.3496 0.4898 0.4808 1c,2t,4c-Trimethylcydohexane 9 0.0131 0.0183 0.0177 3-Ethylheptane 9 0.0598 0.0838 0.0808 3-Methyloctane 9 0.3301 0.4625 0.4493 3,3-Diethylpentane 9 0.0052 0.0073 0.0068 lc,2t,3-Trlmethylcyclohexane N9 0.0198 0.0270 0.0240 1,1,2-Trimethylcyclohexane N9 0.0055 0.0076 0.0068 1,2-Dimethylbenzene(o-Xylene) A8 0.3867 0.4484 0.3569 i-Butylcyclopentane N9 0.1368 0.1886 0.1691 UnknownC8s U8 0.0912 0.1138 0.1134 n-Nonane P9 1.0380 1.4542 1.4189 1,1-Methylethylcydohexane N9 0.1376 0.1928 0.1887 i-Propylbenzene A9 0.0380 0.0499 0.0405 I-Propykyclohexane N9 0.0267 0.0368 0.0321 2,2-Dimethyloctane 110 0.0142 0.0221 0.0209 2,4-Dimethyloctane 110 0.0650 0.1010 0.0957 2,6-Dimethyloctane 110 0.0122 0.0190 0.0186 2,5-Dimethyloctane 110 0.0082 0.0127 0.012D n-Butylcydopentane N9 0.1168 0.1790 0.1569 3,3-Dimethyloctane 110 0.0206 0.0320 0.0303 n-Propylbenzene A9 0.1446 0.1898 0.1540 3,6-Dimehhyloctane 110 0.0461 0.0716 0.0678 3-Methyl-5-ethylheptane 110 0.0324 0.0454 0.0438 1,3-Methylethylbenzene A9 0.1377 0.1808 0.1454 1,4-Methylethylbenzene A9 0.0529 0.0694 0.0558 1,3,5-Trimethylbenzene A9 0.1865 0.2448 0.1983 2,3-Dimethyloctane 110 0.0421 0.0654 0.0619 5-Methylnonane 110 0.1012 0.1573 0.1504 1,2-Methylethylbenzene A9 0.1372 0.1801 0.1441 2-Methylnonane 110 0.0179 0.0278 0.0268 3-Ethyloctane 110 0.0183 0.0284 0.0269 3-Methylnonane 110 0.0885 0.1375 0.1313 1.2,4-Trimelhylbenzene A9 0.0011 0.0014 0.0011 t-Butylbenzene A10 0.2112 0.3096 0.2504 i-Butylcydohexane NI0 0.0489 0.0749 0.0646 lt-Methyl-2-n-propylcydohexane 110 0.0099 0.0139 0.0134 i-Butylbenzene A10 0.0160 0.0235 0.0193 sec-Butylbenzene A10 0.0111 0.0163 0.0133 UnknownC9s U9 0.4413 0.6182 0.6032 n-Decane P10 0.3955 0.6146 0.5896 1,2,3-Trimethylbenzene A9 0.0294 0.0386 0.0303 1,3-Methyl-i-propylbenzene A10 0.0192 0.0252 0.0202 1,4-Methyl-i-propylbenzene A10 0.0116 0.0152 0.0122 Sec-Butylcyclohexane N10 0.0622 0.0953 0.0821 1,2-Methyl-I-propylbenzene A10 0.0553 0.0811 0.0648 3-Ethylnonane 110 0.0075 0.0117 0.0113 1,3-Diethylbenzene A10 0.0114 0.0167 0.0135 1,3-Methyl-n-propylbenzene Al0 0.0164 0.0240 0.0195 1.4-Diethylbenzene A10 0.0392 0.0575 0.0468 1,4-Methyl-n-propylbenzene Al0 0.0057 0.0084 0.0069 n-Butylbenzene A10 0.0114 0.0167 0.0136 1,3-Dimethyl-5-ethylbenzene A10 0.0197 0.0289 0O234 1,2-Diethylbenzene A10 0.0087 0.0128 0.0102 1,2-Methyl-n-propylbenzene A10 0.0256 0.0375 0.0301 1,4-Dimethyl-2-ethylbenzene A10 0.0307 0.0450 0.0359 1,3-Dimethy1-Dethylbenzene A10 0.0031 0.0045 0.0036 1,2-Dimethyl-4-et11ylbenzene A10 0.0494 0.0724 0.0580 1,3-Dimethyl-2-ethylbenzene A10 0.0189 0.0277 0.0218 1t,2c,4-Trimethylcyclopentane A10 0.1675 0.2053 0.1923 1,2-Dimethyl-3-ethylbenzene A10 0.0167 0.0245 0.0192 1,2-Ethyl-l-propylbenzene A10 0.0097 0.0142 0.0114 1,4-Methyl-t-butylbenzene All 0.0337 0.0494 0.0198 UnknownClOs U10 0.6136 0.9536 0.9148 n-Undecane P11 0.1878 0.3206 0.3033 1,4-Ethyl-I-propylbenzene All 0.0124 0.0182 0.0146 1,2,4,5-Tetramethylbenzene All 0.0119 0.0174 0.0138 1,2-Methyl-n-butylbenzene All 0.0111 0.0163 0.0130 1,2,3,5-Tetramethylbenzene All 0.0149 0.0218 0.0172 1,2-Methyl-t-butylbenzene All 0.0219 0.0321 0.0257 5-Methylindan All 0.0080 0.0149 0.0139 4-Methylindan All 0.0055 0.0102 0.0095 1,2-Ethyl-n-propylbenzene All 0.0014 0.0021 0.0017 2-Methylindan All 0.0030 0.0056 0.0052 1,3-Methyl-n-butylbenzene All 0.0041 0.0060 0.0048 1,3-Di-i-propylbenzene All 0.0057 0.0084 0.0067 sec-Pentylbenzene All 0.0151 0.0221 0.0177 n-Pentylbenzene All 0.0069 0.0112 0.0091 lt-M-2-(4MP)cydopentane P12 0.0138 0.0257 0.0241 1,4-Di-i-propylbenzene All 0.0191 0.0280 0.0224 t-Decahydronaphthalene MO 0.0061 0.0089 0.0071 Naphthalene A10 0.0148 0.0207 0.0165 1-t-Butyl-3,5-dimethylbenzene Al2 0.0042 0.0062 0.0050 1,4-Ethylt-butylbenzene All 0.0086 0.0126 0.0101 UnknownClls Ull 0.2547 0.4349 0.4114 n-Dodecane P12 0.1155 0.2149 0.2011 1,3-DI-n-propylbenzene Alt 0.0064 0.0094 0.0075 1,3,5-Triethylbenzene Alt 0.0081 0.0106 0.0088 1,2,4-Triethylbenzene Al2 0.0340 0.0446 0.0357 1,4-Methyl-n-pentylbenzene Al2 0.0106 0.0155 0.0124 n-Hexylbenzene Al2 0.0131 0.0232 0.0190 1,2,3,4,5-Pentamethylbenzene A13 0.0122 0.0179 0.0143 2-Methylnaphthalene All 0.0172 0.0267 0.0213 1-Methylnaphthalene All 0.0148 0.0230 0.0158 UnknownCl2s U12 0.1213 0.2257 0.2112 n-Tridecane P13 0.0600 0.1208 0.1117 UnknownClls W3 0.0949 0.1911 0.1767 n-Tetradecane P14 0.0290 0.0628 0.0579 UnknownClls U14 0.0966 0.2093 0.1931 n-Pentadecane P15 0.0164 0.0381 0.0347 UnknownClls U15 0.0632 0.1466 0.1337 n-Hexadecane P16 0.0038 0.0094 0.0085 UnknownCies U16 0.0230 0.0569 0.0516 n-Heptadecane P17 0.0004 0.0010 0.0009 UnknownCl7s U17 0.0037 0.0097 0.0088 n-Octadecane P18 . 0.0002 0.0006 0.0005 UnknownClls U18 0.0004 0.0011 0.0010 UnknownCl9s U19 0.0002 0.0006 0.0005 TOTAL 100.0000 100.0000 100.0000 THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT STATE-OF-THEARTANALYTICAL TECHNIQUES. THE APPLICATIONS OF THIS INFORMATION IS THE RESPONSIBILITY OF THE USER. EMPACT ANALYTICAL SYSTEMS,INC ASSUMES NO RESPONSIBILITY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF IT'S APPLICATION. III,U.` (*EL EMPACT \h h IRIS'WM,Auld///... PROJECT NO: 201105150 ANALYSIS NO.: 02 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: JUNE 21,2011 SAMPLE DATE: MAY 26,2011 COMMENTS: IL JAR SAMPLED BY: J.MOSER SPOT @ 87°F;LIGHT BROWN/ORANGE EMPACT TEST PROCEDURE/METHOD: API GRAVITY DESCRIPTION: API GRAVITY(et 60/60 ENTERPRISE COMPRESSOR 58.5 PROCUTION TANK C812:10 • THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT STATE-OF-THE ART ANALYTICAL TECHNIQUES. THE APPLICATIONS OF THIS INFORMATION IS THE RESPONSIBILITY OF THE USER. EMPACT ANALYTICAL SYSTEMS,INC.ASSUMES NO RESPONSIBILITY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF IT'S APPLICATION. EMPACT Analytical Systems, Inc. 365 South Main St. Brighton, CO. 80601 (303)637-0150 EMPACT PROJECT NO: 201105150 ANALYSIS NO.: 02 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: JUNE21,2011 SAMPLE DATE: MAY 26.2011 COMMENTS: 1L JAR SAMPLED BY: J.MOSER SPOT @ 67°F;LIGHT BROWN/ORANGE EMPACT TEST PROCEDURE!METHOD: REID VAPOR PRESSURE(ASTM D-323) DESCRIPTION: REID VAPOR PRFSSURF ENTERPRISE COMPRESSOR 6.1 PROCUTION TANK @12:10 THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT STATE-OF-THE ART ANALYTICAL TECHNIQUES. THE APPLICATIONS OF THIS INFORMATION IS THE RESPONSIBILITY OF THE USER. EMPACT ANALYTICAL SYSTEMS,INC.ASSUMES NO RESPONSIBILITY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF MS APPLICATION. EMPACT Analytical Systems,Inc. 365 South Main St. Brighton, CO. 80601 (303)637-0150 PIC c701l y —p-437 E„-Tv 95 8-T-(4 tattier ' /03 j qae; cl, �j r - iiy0 Ile-- EMPACT MN,.me.i/uf) t AV,�NRtl,,,,4- ,>yc'N'� n f'a . 1 '''.� /f/ NATURAL GAS ANALYSIS YI `l� 1 PROJECT NO. : 201107057 ANALYSISNO.: 01 V COMPANY NAME: DCP MIDSTREAMP-LP ANALYSIS DATE: JULY v,2011 ACCOUNT NO. : BILLING CODE: G031 SAMPLE DATE : JULY 11,2011 PRODUCER : TO: LEASE NO. : CYLINDER NO.: DCP-#6 NAME/DESCRIP: ENTERPRISE FUEL GAS ***FIELD DATA*** SAMPLED BY : TERRY JOSE SAMPLE TENDiki:'112' SAMPLE PRES.: 296# AMBIENT TEMP.: COMMENTS : SPOT;STATE: CO NORM. GPs GPM @ ' COMPONENTS MOLE% 14.65 14.73 HELIUM 0.01 - - HYDROGEN 0.00 - - OXYGEN/ARGON 0.01 - - NITROGEN 0.40 - - CO2 0.00 - - METHANE 85.10 - - ETHANE 11.93 3.172 3.190 PROPANE 2.30 0.630 0.633 ISOBUTANE 0.10 0.033 0.033 N-BUTANE ' 0.14 0.044 0.044 ISOPENTANE 0.01 . 0.004 0.004 N-PENTANE 0.00 0.000 0.000 HEXANES+ 0.00 0.000 0.000 TOTAL 100.00 3.883 3.904 BTU@ 60 DEG F 14.65 14.73 GROSS DRY REAL= 11363 11423 GROSS SATURATED REAL= 1116.4 1122.6 RELATIVE DENSITY(AIR=1 @14.696 PSIA 60F): 0.6408 COMPRESSIBILITY FACTOR : 0.99726 • NOTE: REFERENCE CPA 2261(ASTMDIPJS d.ASMF`PTC),2145,d 21 72 CURRENT PUBLfGTJONS EMPACT Analytical Systems Inc. 365 S Main St Brighton, CO 80601 303-637-0150 Attachment D Company Contact Information Enterprise Compressor Station Form APCD-101 ; Colorado Department of Public Health and Environment Air Pollution Control Division 4, y Colorado oitubbcraviatimelil Company Contact Information Form Ver.September 10,2008 Company Name: DCP Midstream, LP Source Name: Enterprise Compressor Station Permit Compliance Contact': Wesley Hill Contact?: Michael Barrett ** 370 176 Street, Suite 2500 3026 4i'Avenue Address: Street Address: Street Denver CO 80202 Greeley CO 80631 City State Zip City State Zip Phone Number: 303-605-1716 Phone Number: 970-378-6383 Fax Number: 303-605-1957 Fax Number: 303-572-3516 E-mail: WDHill@dcpmidstream.com E-mail: MiBarrett@dcpmidstream.com Billing Contact: Billing Contact: fPermirFees)r Wesley Hill fAnnuaiFees)4 Wesley Hill See Permit Contact See Permit Contact Address: Street Address: Street City State Zip City State Zip Phone Number: Phone Number: Fax Number: Fax Number: E-mail: E-mail: ** NOTE-New Compliance Contact for all Colorado facilities Check how would you like to receive your permit fee invoice? Mail: ® E-mail: ® Fax: O Footnotes: ' The permit contact should be the point of contact for technical information contained in the permit application. This may be a company representative or a consultant. E The compliance contact should be the point of contact for discussing inspection and compliance at the permitted facility. a The billing contact(Permit fees)should be the point of contact that should receive the invoice for fees associated with processing the permit application&issuing the permit.(Reg.3,Part A,Section VI.B) The billing contact(Annual fees)should be the point of contact that should receive the invoices issued on an annual basis for fees associated with actual emissions reported on APENs for the facility.(Reg.3,Part A, Section VI.C) Page 1 of 1 05 Company Contact Sheet Attachment E Ambient Air Quality Analysis Enterprise Compressor Station Ambient Air Impact Analysis The Colorado Department of Public Health and Environment Colorado Modeling Guideline for Air Quality Permits,dated August 20, 2010, states that the preliminary air impact analysis for construction permit applications can be done using quantitative(modeling)or qualitative(non- modeling)methods. Table 1,Modeling Thresholds,describes that modeling is usually warranted for sources that meet any of the following criteria: • Carbon Monoxide(CO)emissions equal to or greater than 100 tons per year(tpy)or 23 pounds per hour. • Nitrogen Oxides(NOx)emissions equal to or greater than 40 tpy or 0.46 pounds per hour. • Sulfur Dioxide(5O2)emissions equal to or greater than 40 tpy or 0.46 pounds per hour. • Particulate Matter(PM 10)emission equal to or greater than 15 tpy or 82 pounds per day. • Lead emissions equal to or greater than 0.6 tpy or 100 pounds per month. • Sources of SO2,PM10,CO,or Pb where a substantial portion of the new or modified emissions have poor dispersion characteristics(e.g.,rain caps, horizontal stacks,fugitive releases, 12 or building downwashl3)in close proximity to ambient air at the site boundary. • Sources of 5O2,PM10,CO,or Pb located in complex terrain(e.g.,terrain above stack height in close proximity to the source). • Sources located in areas with poor existing air quality. • Modifications at existing major stationary sources,including grandfathered sources that have never been modeled before. None of the above mentioned thresholds will be exceeded with this modification. Therefore, further analysis is not needed. Attachment F Facility Emission Inventory Enterprise Compressor Station a 3 FascFR...••, o c. I •g a J RRaROR----•• 6 a — 1. cor 111 itt: vER47,4.. 5 : : - .3 " IltEEER5..,,.. a , . 9 : tii"vy'a ' aR ••.... R . . . R - k=--tRFR_St.. R • • • ! . 3 o x^s••• R . . • R . I _ _ 'r? t34: 6 !F_ _ i • , • 3 1 3i9Yi23aRFp••' ! .....•__ • a Y .4 `saz%pq--R- S 3 - - a i E G I 6 c Z �g da a in � e • . 1 t ,z- a; 8 R __-.,.,.••.•. : 1,51 C R . : _ sp ."a aR:ttrR :i° d — gg 4aasaxR . R. • . - _ 2 w 1J 3P333-----:... . 2 . • 2 w i F5tFR%.,...e 4 • • . F S C '"' `-A -- IE•: 1 . • g 2 a ! iiG6:F'J eAFee • e • 3 9 I II I4 enF __ ..••ry F I § 111 Nil lee:aae..;eeg ; : . . . 1 s . P. Aye ..••.. P. • , . — X19 1 it' Ji ; g V lij 12LIt g 1 llH !a t 5 3a•d3akza2 amx� x •F 1. 2 1 . l .n „3 , . . . 13 . 33 . IWWWWW WW WWWWMe , l W .,Illill W'o' y1.4„, „ !HHfiIIHHHHiH W ouu ouu 000uuouuuuuoVVVVVUUU F'-n I.M. iianiSMdni#Miisn ,7 s. z r zz gggggggggggggggggggg 511151 cm HH llijfl l 3 yyj p @ i Bs e € 3 1 EE I nmool 12 i - Iacaaupacw 43 as = a t $ a AHcodoe!oa.e- 14!CCClECCCEL' EC !!l b :r880 g J00 000 0aoo0000eee000000aee0000 o' C$o�SS.0000000eoe000000000000000. MuutLtLLLth vVi8g Lii g ., a2sas:x::xae$$$$$e$$$a$ e$$ 00ii ±. ff�sa a a a m am mn.h m`H 3 A OA 0 3 tIIHhIIIfUh1duii14!J1huLdLil 1 0 Attachment G Process Description,Flow Diagram,and Plot Plan Enterprise Compressor Station Enterprise Compressor Station Process Description The Enterprise Compressor Station classified as a natural gas compressor station as set forth under Standard Industrial Classification Code 4922.The plant uses four(4)gas-fired internal combustion engines to drive compressors to boost the inlet gas pressure from about 80 PSIG to about 1,050 PSIG to facilitate movement of the gas in the pipeline.All four(4)engines have individual stacks to vent the products of combustion.The station also includes a triethylene glycol(TEG)dehydrator unit which contacts"lean"triethylene glycol with the inlet natural gas stream to remove moisture.The"rich"glycol mixture is regenerated in a still for reuse in the process.The still vent exhaust stream is sent to a flare where it is combusted. The TEG dehydration system operates with a flash tank.The flash tank emissions are routed back to the process.A condensate product is generated when the inlet gas is routed through the inlet scrubber.The condensate is transferred first to a 30,000 gallon pressurized storage tank,then to a stabilizer tank to remove any volatile material,and finally to four(4)300 barrel atmospheric storage tanks.The atmospheric tanks are controlled by a combustor.A loading system is provided for moving the liquid condensate material from the tanks into a truck for transport offsite.The facility is located one(1)mile north of US Highway 76 on the Gutterson Road between the towns of Keenesburg and Roggen,Weld County,Colorado. This modification will adjust the HP and emissions of the 4 existing Caterpillar 3612 compressor engines and add 2 new Caterpillar 3616 compressor engines.The TEG dehydration unit D2 will be increased to 110 MMSCFD and one additional TEG dehydration unit will be added with a capacity of 60 MMSCFD. Both dehydration units will be controlled with a VRU for the flash tank emission and a condenser/flare for the still vents.The stabilized condensate throughput will be increased to 6.46 MMgaUyr and 4 additional 300 stabilized condensate tanks will be constructed at the facility. The condensate tanks and associated load out will be controlled with a combustor at 95%destruction efficiency. ENTERPRISE COMPRESSOR STATIION jg`° es. 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S g'S a l�,'{a „k'r-"zt'.` M.7 . ex'' f a " `1 Y' ,_° :n �. -_ .. s. Gk'mr a lSi v -� , Cog n1gfd O lgee-2002 nsmeon 0 mi 0.5 1 1.5 2 2.5 OCoaaht 2001M0eogr.clalcDais Tetlndavi..InIL Al ll eserrved02001Na .ml eras ioIog ebee6 Cenemenmzool ae O Her FfJesy tlhe 0- a in Right of Cagi,Ma. vlppYan Tetlraologiee.MI rights reserved.This data lntlaNee lnipmatlm taken Tab pdmixiion ham Attachment H Operating and Maintenance Plans Enterprise Compressor Station Form APCD-301 Colorado Department of Public Health and Environment Air Pollution Control Division Cobrado of Pu Operating and Maintenance Plan Template forand EnvironmentReciprocating Internal Combustion Engines Ver.September 10,2008 The Air Pollution Control Division (Division) developed this Operating and Maintenance Plan (O&M Plan) template for reciprocating internal combustion engines that are permitted at synthetic minor facilities in the State of Colorado. The O&M Plan shall be submitted with the permit application. A single O&M Plan can be used for all engines at the facility.If the O&M Plan template is completed correctly,the Division will approve the O&M Plan and a construction permit will be issued with the requirement to follow the O&M Plan as submitted. If the template is not completed correctly,the Division will work with the facility to make corrections. Once a construction permit is issued,the facility operator must comply with the requirements of the O&M Plan upon commencement of operation. Operators are not required to use this template. Independent case specific O&M Plans may be developed and submitted for approval with the permit application. However, the Division encourages the use of this template to expedite the permit application approval process. Submittal Date: 1/4/2012 Section 1-Source Identification For new permits some of this information(i.e.Facility AIRS ID,Facility Equipment ID,Permit Number,and AIRS Point ID) may not be known at the time of application.Please only fill out those fields that are known and leave the others blank. Company Name: DCP Midstream,LP Facility Location: SW SW Setion 30.T2N,R63W Facility Name: Enterprise Compressor Station Facility AIRS ID(for existing facilities) 123/0277 Units Covered bythis O&M form Facility Equipment C235 C236 C238 P01S TBD1 TBD2 ID AIRS Point ID 055 056 053 070 TBD TBD Permit Number 95OPWE103 95OPWE103 95OPWE103 95OPWE103 TBD TBD Rich Burn(RB)or LB LB LB LB LB LB Lean Burn (LB) Air Fuel Ratio N N N N N N Controller(Y/N) Catalyst Type SCO SCO SCO SCO SCO SCO Non-selective Catalytic Reduction(NSCR)or Selective Oxidation Catalyst(SCO) Section 2-Maintenance Schedules Check one of the following: Facility shall follow manufacturer recommendations for the operation and maintenance of equipment and control Z devices.These schedules and practices,as well as any maintenance records showing compliance with these recommendations,shall be made available to the Division upon request. Facility shall follow individually developed maintenance practices and schedules for the operation and maintenance of equipment and control devices.These schedules and practices,as well as any maintenance records showing compliance ❑ with these recommendations,shall be made available to the division upon request and should be consistent with good air pollution control practices for minimizing emissions as defined in the New Source Performance Standard(NSPS) general conditions. Page 1 of 4 024 Engine O&M Plan Colorado Department of Public Health and Environment Air Pollution Control Division Section 3-Monthly Emission Modeling or Calculations The following box must be checked for O&M plan to be considered complete. The operator will calculate emissions based on the methods and emission factors provided in the permit application and approved by the division,as reflected in the construction permit.Please see the operation and maintenance plan guidance document for further details and examples of emission calculations. Section 4-General Monitoring Requirements Table 1 below details the schedule by which fuel consumption and hours of operation must be tracked by the source. The hours of operation must be tracked only if emissions,fuel consumption or maintenance activities are based on hours of operation. Table 1 Parameter Monitoring Frequency Fuel Consumption Monthly Hours of Operation Monthly Table 2 outlines fuel use monitoring methods. The source must choose one primary monitoring method and,optionally,may choose up to two backup methods. Check each box that applies. Table 2 Primary Back-up Fuel Consumption Monitoring Method ❑ 0 Individual engine fuel meter 0 Facility-wide fuel meter attributed to fuel consumption rating and hours of operation ❑ ® Manufacturer-provided fuel consumption ❑ ❑ Other(to be approved by the division)-attach explanation and sample calculations Table 3 details the portable testing frequency for engines at the facility based on the requested permitted emission totals for the entire facility. Check the appropriate box based on facility-wide NOx and CO permitted emissions. All portable analyzer tests must be performed per Division protocol,which can be found at http://www.cdphe.state.co.usiap/downiportanalyzeproto.odf Table 3 Portable Testing Frequency Control Status ®Permitted Facility Emissions i_J Permitted Facility Emissions ≥80tpy NO,or CO <8Otpy NO,or CO Quarterly;then semi-annual after 4 Semi-annual;then annual after 2 NSCR or SCO consecutive quarterly passing tests.If any consecutive passing semi-annual tests.If of the semi-annual tests fail then the source any of the annual tests fail then the source shall return to quarterly tests. shall return to semi-annual testing. No catalyst Annual Annual Section 5-Emission Control Equipment Monitoring Requirements—fill out applicable sections only Table 4 details control equipment monitoring frequency for rich bum engines. Check the appropriate box based on facility- wide NOx and CO permitted emissions. See the footnotes following Tables 4 and 5 for details on proper control equipment operating parameter monitoring and compliance requirements. Page 2 of 4 Osa Engine O&M Plan Colorado Department of Public Health and Environment Air Pollution Control Division Table 4 Rich Burn Engine Monitoring Frequency Monitoring Fre uency Emissions Control Device Monitoring Requirement O Permitted Facility Permitted Facility Emissions Emissions ≥8Otpv NO,orCO <80tpy NO.orCO Non-selective catalytic Pre-catalyst Temperature b Daily - Weekly reduction(NSCR) Catalyst Differential Pressure° Monthly Monthly Air-Fuel Ratio AFRC O2 sensor mV reading` Weekly Weekly Controller(AFRC) b Pre-catalyst temperature shall stay within the range of 750°F to 1250°F.If the temperature is outside of this range then appropriate maintenance activities shall be performed. AFRC O2 Sensor Monitoring and Maintenance Requirements • If the engine uses an oxygen sensor then it will be replaced per manufacturer's recommended schedule. If the replacement is determined by hours of operation then the source will track the hours of operation. • In addition to the weekly AFRC O2 Sensor mV reading,this parameter must be recorded during each portable analyzer test. Table 5 details control equipment monitoring frequency for lean burn engines. Check appropriate box based on facility-wide NOx and CO permitted emissions. See the footnotes following Table 5 for details on proper control equipment operating parameter monitoring and compliance requirements. Table 5 Lean Burn Engine Monitoring Frequency Monitoring Fre uency Emissions Control Device Monitoring Requirement ®Permitted Facility Permitted Facility Emissions Emissions ≥B0tpy NO,orCO <S0tpy NO,orCO Selective Oxidation Catalyst Pre-catalyst Temperature d Daily Weekly (SCO) Catalyst Differential Pressure° Monthly Monthly d Pre-catalyst temperature shall stay within the range of 450°F to 1350°F.If the temperature is outside of this range then appropriate maintenance activities shall be performed. 'Catalyst Differential Pressure Baseline Establishment and Monitoring Requirements • The pressure drop shall not exceed 2 inches of water column from the baseline value established by the source when the engine is operating at maximum achievable load. This baseline pressure drop shall be established by the source during each initial compliance and portable analyzer test,and as noted below. • If the pressure is outside this range then the appropriate maintenance shall be performed to bring the pressure back into range.In lieu of maintenance the source may choose to perform a portable analyzer test of the engine to establish a new pressure drop value. If the test demonstrates that the engine is in compliance with its emission limits,the pressure drop value at which the engine is tested shall become the new baseline. • The catalyst will he cleaned,reconditioned and replaced pa the manufacturer's recommended schedule and a copy of maintenance reports shall be kept. If the catalyst cleaning,reconditioning and replacement depends on hours of operation then the source shall track the hours of operation for the engine. • For new,cleaned or reconditioned catalyst on an existing engine: the new pressure drop baseline must be established by the operator within the first 7 days of engine/catalyst operation and re-established during the next regularly scheduled emission test. • For new cleaned or reconditioned catalyst on a new engine:the new pressure drop baseline must be established within the first 180 days of engine operation. Page 3 of 4 08a Engine O&M Plan Colorado Department of Public Health and Environment Air Pollution Control Division Section 6—Recordkeenine Requirements The following box must be checked for O&M plan to be considered complete. Synthetic minor sources arc required to maintain maintenance and monitoring records for the requirements listed in sections 2,3,4 and 5 for a period of 2 years. If an applicable Federal NSPS,NESHAP or MACE requires a longer record retention period the operator must comply with the longest record retention requirement. Section 7•Additional Notes and O&M Activities. Please use this section to describe any additional notes or operation and maintenance activities. Note:These templates are intended to address operation and maintenance requirements of the State of Colorado for equipment operated at synthetic minor facilities./f the facility or equipment is subject to other state or federal regulations with duplicative requirements,the source shall follow the most stringent regulatory requirement Page 4 of 4 08a Engine O&M Plan Form APCD-302 A >^',� Colorado Department of Public Health and Environment a; Air Pollution Control Division Colorado [kprtmmt and1'avirFmleatefldt6 Operating and Maintenance Plan Template for Glycol Dehydration Systems Ver.September 10,2008 The Air Pollution Control Division (Division) developed this Operating and Maintenance Plan (O&M Plan) for glycol dehydration systems that are permitted at synthetic minor facilities in the State of Colorado. An O&M Plan fur each type of glycol dehydration system configuration,as described in Section 1,shall be submitted with the permit application. One O&M Plan may be used for multiple glycol dehydration systems at one facility if each are controlled and monitored in the same manner.If the O&M Plan template is completed correctly,the Division will approve the O&M Plan and a construction permit will be issued with the requirement to follow the O&M Plan as submitted. I f the template is not completed correctly, the Division will work with the facility to make corrections. Once a construction permit is issued, the facility operator must comply with the requirements of the O&M Plan upon commencement of operation. Operators are not required to use this template. Independent case specific O&M Plans may be developed and submitted for approval with the permit application. However,the Division encourages the use of this template to expedite the permit application approval process. Submittal Date: 1/4/2012 Section 1-Source Identification For new permits some of this information(i.e.Facility MRS ID,Facility Equipment ID,Permit Number,and MRS Point ID) may not be known at the time of application.Please only fill out those fields that are known and leave the others blank. Company Name: DCP Midstream,LP Facility Location: SW SW Setion 30.T2N,R63W Facility Name: Enterprise Compressor Station Facility AIRS ID(for existing facilities) 123/0277 Units Covered by this O&M form Facility Equipment ID D2 D3 Permit Number 95OPWE103 TBD AIRS Point ID 068 TIM Glycol Type Used' TEG TEG 'Glycol types include Ethylene Glycol(EG),Di-Ethylene Glycol(DEG),and Tri-Ethylene Glycol(TEG) Emission Points and Control Status:Check the appropriate boxes indicating whether the dehydration system(s)are equipped with a flash tank and whether or not the flash tank(tf present)and still vent emissions are controlled or recycled or vented to atmosphere. ®Flash Tank ®Still Vent ®Controlled/Recycled ®Controlled/Recycled ❑Vented to atmosphere ❑Vented to atmosphere Section 2-Maintenance Schedules Check one of the following: Facility shall follow manufacturer recommendations for the operation and maintenance of equipment and control ® devices.These schedules and practices,as well as any maintenance records showing compliance with these recommendations,shall be made available to the Division upon request. Page I of 4 08b Oehy O&M Plan Colorado Department of Public Health and Environment Air Pollution Control Division Facility shall follow individually developed maintenance practices and schedules for the operation and maintenance of equipment and control devices.These schedules and practices,as well as any maintenance records showing compliance ❑ with these recommendations,shall be made available to the division upon request and should be consistent with good air pollution control practices for minimizing emissions as defined in the New Source Performance Standard(NSPS) general conditions. Section 3-Monthly Emission Modeling or Calculations The following box must be checked for O&M plan to be considered complete. The source will calculate emissions based on the methods and emission factors provided in the permit application and ® approved by the division,as reflected in the construction permit.Please see the operation and maintenance plan guidance document for further details and examples of emission calculations. Section 4—General Monitoring Requirements Table 1 below details the schedule on which the source must monitor each of the listed operating parameters depending on the requested permitted emissions at the facility. Check the appropriate box based on facility wide permitted VOC emissions. Table 1 Monitoring Frequency Parameter ®Permitted Facility 0 Permitted Facility Emissions 2 80 tpy VOC Emissions <80 tpy VOC Lean Glycol Circulation Rate Daily Weekly Wet Gas Inlet Temperature Weekly Monthly Wet Gas Inlet Pressure Weekly Monthly Volume of Gas Processed Monthly Monthly Chiller(Cold Separator)Pressure(EG units only) Weekly Monthly Chiller(Cold Separator)Temperature(EG units only) Weekly Monthly Tables 2 and 3 outline the methods by which the source may monitor the lean glycol recirculation rate and the volume of gas processed,respectively. In Tables 2 and 3 the source must chose one primary monitoring method and,optionally,up to two backup monitoring methods. Check each box that applies. Table 2 Primary Back-up Lean Glycol Recirculation Rate Monitoring Method Glycol flow meter(s)—including flow from all injection points or pumps ❑ ® Record strokes per minute and convert to circulation rate—pump make/model and stokes per minute/circulation rate relationship must be made available to the division upon request ❑ ❑ Assume maximum design pump rate b—pump make/model and circulation rate specifications must be made available to the division upon request bNote:if you are requesting to permit at a rate lower than the maximum design pump rate then this option should not be used as it will create de facto non-compliance. Table 3 Primary Back-up Volume of Gas Processed Monitoring Method ® Metered®Inlet❑Outlet 0 Fuel Gas Compressor Discharge['Other: ❑ ® Metered U Inlet®Outlet 0 Fuel Gas DU Compressor Discharge UOther: U U Assume maximum design rate specifications shall be made available to the division upon request ❑ 0 Other(to be approved by the division):attach method explanation and sample calculations `Note:if you are requesting to permit at a rate lower than the maximum contactor design rate then this option should not be used as it will create de facto non-compliance. Page 2 of 4 08b Dehy O&M Plan Colorado Department of Public Health and Environment Air Pollution Control Division Section 5-Emission Control or Recycling Equipment Monitoring Requirements Table 4 below details the monitoring frequency for control equipment depending on the type of control equipment used and the requested permitted emissions at the facility. Check the appropriate box for"Monitoring Frequency"based on the facility- wide permitted VOC emissions. In addition,indicate still vent and flash tank emissions controls by checking the appropriate boxes. Table 4 Monitorin_ Frequency Emissions Control or Still Flash Z Permitted Facility ❑ Permitted Facility Recycling Method Vent Tank Parameter Y g Emissions Emissions ≥S0tpyVOC <S0tpyVOC Condenser ® ❑ Condenser Outlet Weekly Monthly Temperature a Thermal Oxidizer 0 0 Combustion Chamber Daily Weekly Temperature` Combustor or Flare 0 0 Pilot Light Monitoring r Daily Weekly Method 22 Readings Daily Weekly Recycled or Closed Loop System(Including 0 ® To be determined by the source and approved by the division s Vapor Recovery Units) Re-routed to Reboiler Burner O 0 To be determined by the source and approved by the division s a Maximum Condenser Outlet Temperature If the equipment is controlled with a secondary control device and no control efficiency is being claimed for the condenser then the condenser outlet temperature does not need to be monitored and there will be no maximum condenser outlet temperature. For all other equipment the maximum condenser outlet temperature shall be:Select one of the following options from Table 5: Table 5 Z 160°F .F (Upon approval from the division)—attach supporting documentation if a higher limit is requested `Minimum Thermal Oxidizer Combustion Chamber Temperature If the facility uses a thermal oxidizer to control emissions then the minimum combustion chamber temperature shall be:Select one of the following options from Table 6: Table 6 1400°F °F Based on manufacturer specifications. Specifications must be submitted with the permit application and made available to the Division upon request 9 Based on testing performed. The test data shall be submitted and attached to the O&M Plan Page 3 of 4 08b Dehy O&M Plan Colorado Department of Public Health and Environment Air Pollution Control Division r Pilot Light Monitoring Options If the facility uses a Combustor or Flare then the source must indicate the method by which the presence of a pilot light will be monitored in Table 7. One primary method for Pilot Light Monitoring must be checked and,optionally,up to two backup methods can be checked. Table 7 Primary Back-up Monitoring Method ❑ ® Visual Inspection ❑ O Optical Sensor ❑ ® Auto-Igniter Signal ® ❑ Thermocouple r Recycled or Closed Loop System Monitoring Plan In the space provided below please provide a brief description of the emission control or recycling system,including an explanation of how the system design ensures that emissions are being routed to the appropriate system at all times,or during all permitted runtime. VRU will route flash tank vapors back the process. There will be a back-up VRU if the primary goes down. ° Reboiler Burner Control Monitoring Plan In the s.nrr provided below please provide a brief description of the emission control system,including an explanation of how the system design ensures that emissions are being held or rerouted when the reboiler is not firing. Section 6—Recordkeepinu Requirements The following box must be checked for O&M plan to be considered complete. Synthetic minor sources are required to maintain maintenance and monitoring records for the requirements listed in ® sections 2,3,4 and 5 for a period of 2 years. If an applicable Federal NSPS,NESHAP or MACT requires a longer record retention period the operator must comply with the longest record retention requirement. Section 7-Additional Notes and O&M Activities Please use this section to describe any additional notes or operation and maintenance activities. Note:These templates are intended to address operation and maintenance requirements of the State of Colorado for equipment operated at synthetic minor facilities.If the facility or equipment is subject to other state or federal regulations with duplicative requirements,the source shall follow the most stringent regulatory requirement Page 4 of 4 oah Dehy O&M Plan Form APCD-304 Colorado Department of Public Health and Environment ; LW Air Pollution Control Division Colorado artntent Operating and Maintenance Plan Template for aad viFty romena Condensate and Mixed Liquid Storage Tanks Ver.September 10,2008 The Air Pollution Control Division(Division)developed this Operating and Maintenance Plan(O&M Plan)for condensate and mixed liquid storage tanks permitted at synthetic minor facilities in the State of Colorado.An O&M Plan shall be submitted with the permit application.One O&M Plan may be used for multiple tanks at one facility if each are controlled and monitored in the same manner. If the O&M Plan template is completed correctly, the Division will approve the O&M Plan and a construction permit will be issued with the requirement to follow the O&M Plan as submitted. If the template is not completed correctly, the Division will work with the facility to make corrections. Once a construction permit is issued, the facility operator must comply with the requirements of the O&M Plan upon commencement of operation. Operators are not required to use this template. Independent case specific O&M Plans may be developed and submitted for approval with the permit application. However,the Division encourages the use of this template to expedite the permit application approval process. Submittal Date: 1/4/2012 Section 1-Source Identification For new permits some of this information(i.e.Facility AIRS ID,Facility Equipment ID,Permit Number,and AIRS Point ID) may not be known at the time of application.Please only till out those fields that are known and leave the others blank. Company Name: DCP Midstream,LP Facility Location: SW SW Setion 30.T2N,R63W Facility Name: Enterprise Compressor Station Facility MRS ID(for existing facilities) 123/0277 Units Covered by this O&M form Facility Equipment ID P-013 Permit Number 95OPWE103 AIRS Point ID 063 Tank Type' C Controlled(Y/N) Y ' Tank types include condensate(C)and mixed liquid(ML) Section 2-Maintenance Schedules Check one of the following: Facility shall follow manufacturer recommendations for the operation and maintenance of equipment and control devices.These schedules and practices,as well as any maintenance records showing compliance with these recommendations,shall be made available to the Division upon request. Facility shall follow individually developed maintenance practices and schedules for the operation and maintenance of equipment and control devices.These schedules and practices,as well as any maintenance records showing compliance ❑ with these recommendations,shall be made available to the division upon request and should be consistent with good air pollution control practices for minimizing emissions as defined in the New Source Performance Standard(NSPS) general conditions. Page 1 of 4 oBc Condensate Tank O&M Colorado Department of Public Health and Environment Air Pollution Control Division Section 3-Monthly Emission Modeling or Calculations The following box must be checked for O&M plan to be considered complete. The source will calculate emissions based on the methods and emission factors provided in the permit application and approved by the division,as reflected in the construction permit.Please see the operation and maintenance plan guidance document for further details and examples of emission calculations. Section 4—General Monitoring Requirements All condensate collection,storage,processing and handling operations,regardless of size,shall be designed,operated and maintained to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. Table I below details the schedule on which the source must monitor each of the listed operating parameters depending on the requested permitted emissions at the facility. Check the appropriate box based on the facility wide permitted VOC emissions. Table 1 Monitoring Frequency Parameter El Permitted Facility U Permitted Facility Emissions 2 80 tpy VOC Emissions C 80 tpy VOC Condensate Throughput Monthly Monthly Separator Temperature(if present) Weekly Monthly Separator Pressure(if present) Weekly Monthly Table 2 outlines condensate and mixed liquid throughput monitoring methods. The source must chose one primary monitoring method and,optionally,may chose up to two backup methods.Check each box that applies. Table 2 Primary Back-up Condensate or Mixed Liquid Throughput Monitoring Method Inlet meter(s) n❑ Tank level measurements which take Into account all additions and loadout activity El N Sales or haul tickets El ❑ Other(to be approved by the division):attach method explanation and sample calculations Section 5-Emission Control or Recycling Equipment Monitoring Requirements If a control device is used then leakage of VOCs to the atmosphere must be minimized as follows: • Thief hatch seals shall be inspected for integrity annually and replaced as necessary; • Thief hatch covers shall be weighted and properly seated; • Pressure relief valves(PRV)shall be inspected annually for proper operation and replaced as necessary; • PRVs shall be set to release at a pressure that will ensure flashing,working and breathing losses(as applicable)are routed to the control device under normal operating conditions; • Annual inspections shall be documented with an indication of status,a description of any problems found,and their resolution. Page 2 of 4 OBc Condensate Tank O&M Colorado Department of Public Health and Environment Air Pollution Control Division Table 3 below details the monitoring frequency for control equipment depending on the type of control equipment used and the requested permitted emissions at the facility.Check the appropriate box for"Monitoring Frequency"based on the facility-wide permitted VOC emissions. In addition,indicate storage tank emissions controls by checking the appropriate boxes. Table 3 Emissions Control Monitoring Fr uency or Parameter ® Permitted Facility U Permitted Facility Recycling Method Emissions Emissions ≥S0tpyVOC <80tpyVOC Combustion Chamber Thermal Oxidizer er ❑ ° Daily Weekly Temperature Combustor or Flare ® Pilot Light Monitoring` Daily Weekly Method 22 Readings Daily Weekly Recycled or Closed Loop System(Including fl To be determined by the source and approved by the division° Vapor Recovery Units) Re-routed to Reboiler Burner To be determined by the source and approved by the division b Minimum Thermal Oxidizer Combustion Chamber Temperature If the facility uses a thermal oxidizer to control emissions then the minimum combustion chamber temperature shall be:Select one of the following options from Table 4: Table 4 ❑ 1400°F ❑ °F Based on manufacturer specifications. Specifications must be submitted with the permit application and made available to the Division upon request ❑ Based on testing performed. The test data shall be submitted and attached to the O&M Plan `Pilot Light Monitoring Options If the facility uses a Combustor or Flare then the source must indicate the method by which the presence of a pilot light will be monitored in Table 5. One primary method for Pilot Light Monitoring must be checked and,optionally,up to two backup methods may be checked. Table 5 Primary Back-up Monitoring Method ❑ Visual Inspection ❑ Optical Sensor ❑ ® Auto-Igniter Signal ❑ Thermocouple °Recycled or Closed Loop System Monitoring Plan In the space provided below please provide a brief description of the emission control or recycling system,including an explanation of how the system design ensures that emissions are being routed to the appropriate system at all times,or during all permitted runtime. Page 3 of 4 08c Condensate Tank O&M Colorado Department of Public Health and Environment Air Pollution Control Division Reboller Burner Control Monitoring Plan In the space provided below please provide a brief description of the emission control system,including an explanation of how the system design ensures that emissions are being held or rerouted when the reboiler is not firing. Section 6—Recordkeeuina Requirements The following box must be checked for O&M plan to be considered complete. Synthetic minor sources are required to maintain maintenance and monitoring records for the requirements listed in sections 2,3,4 and 5 for a period of 2 years. If an applicable Federal NSPS,NESHAP or MACT requires a longer record retention period the operator must comply with the longest record retention requirement. Section 7-Additional Notes and O&M Activities Please use this section to describe any additional notes or operation and maintenance activities. Note:These templates are intended to address operation and maintenance requirements of the State of Colorado for equipment operated at synthetic minor facilities.If the facility or equipment is subject to other state or federal regulations with duplicative requirements,the source shall follow the most stringent regulatory requirement. Page 4 of 4 Dac Condensate Tank O&M Additional O&M Requirements Tank Loading The tank loading emissions will be routed to the same combustor as the tank vapors during all load out activity. Dehv Flare/Combustor Although a separate APEN was submitted for this source the O&M requirements for this control device are outlined in the Dehydrator O&M Plan. Fugitive Emissions • Weekly Audio,Visual,and Olfactory Inspections(AVOs). • If a leak is found,it will be tagged and a first attempt to fix the leak will be made within 5 days from the time the leak was detected. • If the leak is unable to be fixed on the first attempt,a second attempt will be made within 15 days unless a facility shutdown is required to isolate the component to fix the leak.In that situation,the leak will be fixed during the next shutdown. • A soap test or equivalent will be used to ensure the leak is fixed. • Documentation of the weekly AVOs will be kept onsite. Attachment I Regulatory Analysis Enterprise Compressor Station ENTERPRISE COMPRESSOR STATION REGULATORY ANALYSIS 1.0 Federal 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 major sources with respect to Non-Attainment New Source Review(NNSR) if emissions of NO.or VOC are in excess of 100 tpy.This facility emits more than 100 tpy of both NO,, and VOC and therefore, is a major source under NNSR. However,this modification will not result in an increase in NO,,or VOC emissions of more than 40 tpy,therefore,this is a minor modification with respect to NNSR and will not trigger new source review. 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. This facility 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. 75 Fed.Reg. 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. In this case,the proposed project is not subject to PSD review for any criteria pollutant;therefore,GHG emissions from the project are not subject to PSD review.The emissions of CO2e from the facility(approximately 87,332 tpy), which is less than any Step 2 period GHG permitting threshold. 2.0 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 hazardous air pollutant(HAP),25 tpy of any group of HAPs in the aggregate, or 100 tpy of any criteria air pollutant. This facility is a major source for NO,,,VOC,and HAPs and currently operates under Operating Permit 95OPWE103. Regulation No.3,Part A, Section I.B.44.e specifies that beginning July 1, 2011,GHG emissions shall be"subject to regulation"under Title V operating permit requirements if a new or modified stationary source will emit 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"). This facility,does not emit more than 100,000 tpy of CO2e,Title V does not apply to the GHG emissions from the project. 3.0 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." No steam generating units with a design heat input capacity in excess of 10.0 MMBtu/hr are located at this facility;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 storage tanks at this facility are either pressurized or have a capacity less than 19,800 gallons;therefore, Subpart Kb does not apply. 40 CFR Pan 60 Subpart KICK-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]. This facility does not process natural gas and is therefore,not subject to Subpart KKK. 40 CFR Pan 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 I-IP(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 existing engines at this facility were constructed prior to July 1,2007 and are therefore not subject to Subpart JJJJ.The new engines may be subject depending on their manufacture date. If subject the appropriate notifications and records will be kept. 4.0 National E mission 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]. This facility is a major source of HAPs however, this facility is defined as a production field facility as it is before the point of custody transfer(i.e.prior to the gas plant). Since the facility is a production field facility,only HAPs from glycol dehydration units and storage vessels with the potential for flash emissions are aggregated for major source determination under this subpart[§63.671].Therefore,this in an area source with respect to this subpart and as such,the initial notifications and recordkeeping requirements of this subpart will be completed as necessary to show compliance. 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. Asa major source of HAP emissions,the engines at this facility are subject to Subpart ZZZZ and are currently maintaining compliance with all requirements. 5.0 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. Eleven APENs are included in this application. All of the heaters are this facility are less than 5 MMBTU/hr and are therefore APEN exempt per Reg 3,Part A,Section II.D.1.k.. Regulation 3, Part B Regulation 3,Part B describes the requirements for Construction Permits. DCP requests one facility-wide construction permit for the proposed changes requested in this application. Regulation 3, Part C Regulation 3,Part C describes the requirements for Title V Operating Permits. The facility is a major source and currently operates under Operating Permit Number 95OPWE103. The changes will be rolled into the operating permit with-in one year of construction permit issuance. Regulation 3, Part D Regulation 3,Part D sets forth PSD and NNSR requirements. The facility is not a PSD major source and this modification will not trigger NNSR as discussed above. 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 XII 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.I.b; Section XII.C.1.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. 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 natural gas dehydrator at this facility is controlled by greater than 90%. • Section XVI specifies emission control requirements applicable to portable and stationary RICE located in 8-Hour Ozone Control Area. The compressor engines are controlled with selective oxidation catalysts 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. Attachment J Construction Permit Application Completeness Checklist Enterprise Compressor Station Form APCD-100 4 'a Colorado Department of Public Health and Environment Air Pollution Control Division to logy,: irstr do Oil & Gas Industry c° lora abscDS Construction Permit Application Completeness Checklist Ver.September 28,2009 Company Name: DCP Midstream,LP Source Name: Enterprise Compressor Station Date: 1/4/2012 Yes No Are you requesting a facility wide permit for multiple emissions points? ® ❑ In order to have a complete application,the following attachments must be provided, unless stated otherwise. If application is incomplete, it will be returned to sender and filing fees will not be refunded. Attachment Application Element Applicant APCD A APEN Filing Fees ® ❑ B Air Pollutant Emission Notice(s)(APENs)& ® ❑ Application(s)for Construction Permit(s)—APCD Form Series 200 C Emissions Calculations and Supporting Documentation ® ❑ D Company Contact Information-Form APCD-101 ® ❑ E Ambient Air Impact Analysis ® ❑ ❑ Check here if source emits only VOC(Attachment E not required) F Facility Emissions Inventory—Form APCD-102 ® ❑ El Check here if single emissions point source(Attachment F not required) G Process description, flow diagram and plot plan of emissions unit and/or ® ❑ facility El Check here if single emissions point source(Attachment G not required) H Operating&Maintenance(O&M)Plan—APCD Form Series 300 ® ❑ ❑ Check here if true minor emissions source or application is for a general permit(Attachment H not required) I Regulatory Analysis ® ❑ ❑ Check here to request APCD to complete regulatory analysis (Attachment I not required) Colorado Oil and Gas Conservation Commission(COGCC)805 Series Rule ® ❑ Requirements—Form APCD-105 ® Check here if source is not subject to C0GCC 805 Series requirements (Attachment I not required) Send Complete Application to: Colorado Department of Public Health&Environment APCD-SS-Bl 4300 Cherry Creek Drive South Denver,Colorado 80246-1530 Check box if facility is an existing Title V source: ® Send an additional application copy Check box if refined modeling analysis included: ❑ Send an additional application copy Page 1 of 1 10 CompleteChecklist-Ver.9-28-2009 Attachment K RACT Analysis Enterprise Compressor Station Enterprise Compressor Station RACT All of the sources at the this compressor station will utilize RACT per Regulation Number 7 to minimize the NOx and VOC emissions since this facility is located in the non- attainment area. Please see a description of the controls below. TEG Dehydration Unit • Still vent overhead emissions controlled by BTEX condenser and the overhead stream from the condenser is routed to the flare. • Flash gas emissions are recycled back to the inlet via the VRU to achieve 100% control efficiency Stabilized Condensate • Raw condensate that enters the facility is heated and stabilized where the flash vapors are captured and recycled back to the inlet gas stream. The stabilized condensate is stored in atmospheric tanks. The atmospheric tank vents and load out emissions are routed to an enclosed combustor for 95%control of VOC emissions. Compressor Engines • Compressor engines utilize oxidation catalysts. Although not required by Regulation Number 7, DCP will also commit to the follow RACT requirement for the equipment listed below: Fugitive Emissions from Equipment Leaks • Weekly Audio,Visual, and Olfactory Inspections(AVOs). • If a leak is found, it will be tagged and a first attempt to fix the leak will be made within 5 days from the time the leak was detected. • If the leak is unable to be fixed on the first attempt, a second attempt will be made within 15 days unless a facility shutdown is required to isolate the component to fix the leak. In that situation,the leak will be fixed during the next shutdown. • A soap test or equivalent will be used to ensure the leak is fixed. • Documentation of the weekly AVOs will be kept onsite. • DCP Midstream, LP cicp 'p Midstiearn. Enterprise 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 November 2011 Prepared By: Olsson Associates 4690 Table Mountain Drive, Suite 200 Golden, Colorado 80403 iccA • `_.OLSSON A150CIA115 CC DCP Midstream 370 17th Street,Suite 2500 �— Denver,CO 80202 • Midstream 303-595-3331 November 18, 2011 Hand Delivered Ms. Bailey Smith N�� 2\ 2�� Operating Permit Engineer Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B1 Denver,Colorado 80246-1530 Re: Enterprise Compressor Station Operating Permit 95OPWE103 Title V Permit Renewal Application Dear Ms. Smith: DCP Midstream, LP(DCP) is submitting the attached Title V Operating Permit renewal application for the Enterprise Compressor Station(Enterprise) located in the Section 30,Township 3N,Range 63W,in Weld County. The current Operating Permit 95OPWE103 was originally issued by the Colorado • Department of Public Health and Environment, (CDPHE), Air Pollution Control Division on May 1, 1999 and most recently reissued on December 1,2007. Enterprise is classified as a natural gas compressor station as set forth under Standard Industrial Classification Code 4922.The facility uses four(4) gas-fired internal combustion engines to drive compressors boosting the inlet gas pressure from about 80 PSIG to 1,050 PSIG to facilitate movement of the gas in the pipeline. A 10,142 HP Solar Taurus Turbine is being permitted at the facility to also run a compressor. The station also includes a triethylene glycol (TEG)dehydrator unit which contacts"lean" triethylene glycol with the inlet natural gas stream to remove moisture. The"rich"glycol mixture is regenerated in a still for reuse in the process.The still vent exhaust stream is sent to a flare where it is combusted.The TEG dehydration system operates with a flash tank. The flash tank emissions are routed back to the process. A condensate product is generated when the inlet gas is routed through the inlet scrubber.The condensate is transferred first to a 30,000 gallon pressurized storage tank,then to a stabilizer tank to remove any volatile material, and finally to four(4) 300 barrel atmospheric storage tanks.The working and breathing emissions from the stabilized, atmospheric, condensate tanks are controlled by a combustor. A loading system is provided for moving the liquid condensate material from the tanks into a truck for transport offsite. The facility is located one(1)mile north of US Highway 76 on the Gutterson Road between the towns of Keenesburg and Roggen,Weld County, Colorado. Since the last issuance of Operating Permit 95OPWE103,there have been a few changes to the facility which have either been modified through a minor modification or and a construction permit application. • April 1, 2010 -A minor modification was submitted the Division requesting that the wording in the CAM plan be modified to allow the use of temperature sensing instruments other than • thermocouples to verify the presence of a flame. Also, in this modification the compliance factors for Engine P018 were corrected to properly correspond with tpy emission limits. Please note that this change will now apply to the rest of the engines which are permitted at the same • emission levels. • June 21, 2010—Engine C234(AIRS ID 123/0277/054) and the SVE units(AIRS ID 123/0277/069)were cancelled. These sources will need to be removed from the permit during the renewal. • October 25, 2011 —Construction permit modification application. Engines C-238, C-235, and C- 236 were repermitted at the same HP and emissions as P018.The 10,142 HP Solar Taurus 70 turbine was added to aide in compression. The plant throughput was increased to 120 MMSCFD and the condensate production was bumped up to 5.6 MMgal/yr. Controls were also added to the condensate tanks. The dehydrator,condensate tanks, loadout, and fugitive emissions were all updated with this application. This Title V renewal application incorporates all of the changes requested in the construction permit modification application. • P018 APEN update—DCP is submitting an APEN update with this renewal application. The serial number of the engine is incorrectly listed as BEK00356 in the current TV permit and most recent APEN. DCP has field verified that the actual serial number is BKE00356. The initial APEN which was attached to the construction permit application for this unit did list the serial number correctly. It seems that it was transposed when the permit was written. In the most recent APEN on file with the Division, the VOC limit was also incorrectly listed. The attached APEN lists to correct limit as listed in the current operating permit. (APEN and Check are located in Appendix F. A copy of that APEN is in Appendix E with the other current APENs) Since the last issuance of Operating Permit 95OPWE103,the Green House Gas (GHG)Tailoring Rule • has been passed which sets the major source threshold for GHG emissions at 100,000 tpy CO2e. GHG emissions from Enterprise were estimated to be approximately 92,020 CO2e. GHG emission calculations can be found in Appendix B of the renewal application. The following summarizes the enclosed attachments and their location within the renewal application: • Appendix A Operating Permit Application Forms • Appendix B Emission Calculations w/GHG • Appendix C Diagrams • Appendix D Regulatory Analysis • Appendix E Current APENS, Construction Permit Application, AOS and Minor Modification If you have any questions or require any additional information about the project, please feel free to contact me at (303) 605-1716 orWDHifl@dcpmidstrcam.com.Also, since so many changes are being made to this permit, DCP would like to review the permit before it is sent out for EPA review. Sincerely, DCP Midstream, LP Wesley Hill Senior Environmental Specialist • Enclosures �rww.dcpmidstrcam.com • Appendix A Operating Permit Application Forms 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 Enterprise Compressor Station mailing address Street or Route 370 Seventeenth Street,Suite 2500 City, State,Zip Code Denver,Colorado 80202 2. Facility location Street Address SW SW Sec 30,T2N,R63W (No P.O.Box) City,County,Zip Between Keenesburg and Roggen,Weld County,Colorado Code 3. Parent corporation Name DCP Midstream,LP Street or Route 370 Seventeenth Street,Suite 2500 City, State,Zip Code Denver,Colorado 80202 Country(if not U.S.) 4. Responsible Name Joseph Kuchinski official Title Vice President,Area Operations North Telephone (970)378-6345 5. Permit contact person Name Wesley Hill Title Senior Environmental Specialist (If Different than 4) Telephone (303)605-1716 6. Facility SIC code: 4922 7. Facility identification code: CO 1230277 8. Federal Tax I. D.Number: 841041166 • 9. The Platteville Gas Processing Plant is a natural gas processing plant and compressor station designed to extract natural gas liquids from field-produced natural gas,and recompress the processed gas prior to transmission to the sales pipeline. 10. Type of operating permit I New -I Modified x Renewal 11. Is the facility located in a"nonattainment" area: X Yes I No If"Yes",check the designated"non-attainment" pollutant(s): Carbon Monoxide X Ozone PMIO I Other(specify) 12. List all(Federal and State)air pollution permits(including grandfathered units),plan approvals and exemptions issued to this facility. List the number,date and what unit/process is covered by each permit. For a Modified Operating Permit,do not complete this item. 95OPWE103,Title V Operating Permit,December 1,2007 See attached construction permit application from October 25,2011 for updated emissions and equipment. (Not assigned a permit number yet) • 1 Operating Permit Application FACILITY PLOT PLAN FORM 2000-101 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division Facility Name: Enterprise Compressor Station Facility Identification Code: CO 1230277 •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 C I 2. The maximum height of each building (excluding stack height). 3. The location and coded designation of each stack. Please ensure these designations correspond to the appropriate stacks listed on the other permit forms in this application. The drawings need not be to scale if pertinent dimensions are annotated, including positional distances of structures, outdoor processes and free standing stacks to each other and the property boundaries. I 4. The location of property boundary lines. I.. 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: N/A • 2 Operating Permit Application SOURCE AND SITE DESCRIPTIONS FORM 2000-102 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division Facility Name: Enterprise Compressor Station Facility Identification Code: CO 1230277 One 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. Enterprise is classified as a natural gas compressor station as set forth under Standard Industrial Classification Code 4922. The facility uses four (4) gas-fired internal combustion engines to drive compressors boosting the inlet gas pressure from about 80 PSIG to 1,050 PSIG to facilitate movement of the gas in the pipeline. A 10,142 HP Solar Taurus Turbine is being permitted at the facility to also run a compressor. The station also includes a triethylene glycol (TEG) dehydrator unit which contacts "lean" triethylene glycol with the inlet natural gas stream to remove moisture. The "rich" glycol mixture is regenerated in a still for reuse in the process. The still vent exhaust stream is sent to a flare where it is combusted. The TEG dehydration system operates with a flash tank. The flash tank emissions are routed back to the process. A condensate product is generated when the inlet gas is routed through the inlet scrubber. The condensate is transferred first to a 30,000 gallon pressurized storage tank, then to a stabilizer tank to remove any volatile material, and finally to four(4) 300 barrel atmospheric storage tanks. The working and breathing emissions from the stabilized, atmospheric, condensate tanks are controlled by a combustor.A loading system is provided for moving the liquid condensate material from the tanks into a truck for transport offsite. The facility has a natural gas throughput of 120 MMSCFD and •a condensate a maximum stabilized condensate production rate of 5.6 MMgal/yr. 2.Site Location and Description (Include instructions needed to drive to remote sites not identified by street addresses) Site location: SW SW Section 30, T2N, R63W The facility is located one (1) mile north of US Highway 76 on the Gutterson Road between the towns of Keenesburg and Roggen, Weld County, Colorado. 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 • 3 Operating Permit Application SOURCE DESCRIPTION-APENS FORM 2000-102A Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division Facility Name: Enterprise Compressor Station Facility Identification Code: CO 1230277 41 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-235 055 Natural Gas Compressor 3,550 hp, Caterpillar G3612SI, Natural Gas Fired, Engine Reciprocating Internal Combustion Engine, 4-cycle, Standard Lean Burn w/Oxidation Catalyst C-236 056 Natural Gas Compressor 3,550 hp, Caterpillar G361251, Natural Gas Fired, Engine Reciprocating Internal Combustion Engine, 4-cycle, Standard Lean Burn w/Oxidation Catalyst C-238 053 Natural Gas Compressor 3,550 hp, Caterpillar G3612SI, Natural Gas Fired, Engine Reciprocating Internal Combustion Engine, 4-cycle, Standard Lean Burn w/Oxidation Catalyst P018 070 Natural Gas Compressor 3,550 hp, Caterpillar G36125I, Natural Gas Fired, Engine Reciprocating Internal Combustion Engine, 4-cycle, Standard Lean Burn wl Oxidation Catalyst T1 TBD Turbine Powering a Natural 10,142 hp, Solar Taurus 70, Natural Gas Fired Gas Compressor Turbine D2 068 Dehydration of Natural Gas 120 MMSCFD, Lakota Tri-ethylene Glycol (TEG) • Dehydration Unit, 35 gpm TEG Recirculation Rate, Flash Tank Routed to Reboiler, Equipped with a Condenser Routed to a Flare P012 062 Fugitive Emissions from Fugitive Emissions from Equipment Leaks Equipment Leaks P013 063 Stabilized Condensate Storage 4-300bb1 Atmospheric Vertical Stabilized Condensate Storage Tanks Controlled with a Combustor P016 066 Stabilized Condensate Truck 5.6 MMgal/yr Stabilized Condensate Truck Loading Loading 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 • *NOTE:A copy of the most recent permit application(10/26/2011)is attached in Appendix C. 4 Operating Permit Application SOURCE DESCRIPTION-INSIGNIFICANT ACTIVITIES FORM 2000-102B Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division Facility Name: Enterprise Compressor Station Facility Identification Code: CO 1230277 •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 fonn 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 l.B.58 of Regulation 3. For the facility, mark all insignificant existing or proposed air pollution emission units, operations, and activities listed below. (a) noncommercial (in-house) experimental and analytical laboratory equipment which is bench scale in nature including quality control/quality assurance laboratories, process support laboratories, environmental laboratories supporting a manufacturing or industrial facility, and research and development laboratories. (b) research and development activities which are of a small pilot scale and which process less than 10,000 pounds of test material per year. (c) small pilot scale research and development projects less than six months in duration with controlled actual emissions less than 500 pounds of any criteria pollutant or 10 pounds of any non-criteria reportable pollutant. Disturbance of surface areas for purposes of land development,which do not exceed 25 contiguous acres and which do not exceed six months in duration. (This does not include mining operations or disturbance of contaminated soil). 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). x Petroleum industry flares, not associated with refineries, combusting natural gas containing no H2S except in •trace(less than 500 ppmw)amounts,approved by the Colorado Oil and Gas Conservation Commission and having uncontrolled emissions of any pollutant of less than five tons per year. x 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. x 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. x 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. r Crude oil or condensate storage tanks with a capacity of 40,000 gallons or less. 5 Storage tanks meeting all of the following criteria: (i) annual throughput is less than 400,000 gallons; and (ii) the liquid stored is one of the following: (A) diesel fuels 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 I 6 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: Enterprise Compressor Station 2. Facility identification code: CO 1230277 • 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 75-07-0 Acetaldehyde 1.77 TPY 107-02-8 Acrolein 1.08 TPY 71-43-2 Benzene 2.69 TPY 50-00-0 Formaldehyde 11.20 TPY 67-56-1 Methanol 0.53 TPY 110-54-3 n-Hexane 1.55 TPY 108-88-3 Toluene 2.05 TPY 1330-20-7 Xylenes 0.54 TPY 100-41-4 Ethylbenzene 0.07 TPY 540-84-1 2,2,4 Trimethylpentane 0.05 TPY • • i NOTE: If there is a permit for this unit,the permit limits are the same as the potential to emit. Operating Permit Application PLANT-WIDE CRITERIA AIR POLLUTANTS FORM 2000-603 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Enterprise Compressor Station 2. Facility identification code: CO 1230277 . 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) 6.3 6.3 PM-10 6.3 6.3 Nitrogen oxides 117.3 117.3 Volatile organic compounds 200.5 200.5 Carbon monoxide 48.0 48.0 Lead Sulfur dioxide 1.3 1.3 Total reduced sulfur Reduced sulfur compounds Hydrogen sulfide Sulfuric acid mist • Fluorides • 8 Operating Operating Permit Application TABULATION OF PERMIT APPLICATION FORMS FORM 2000-800 Colorado Department of Health 09-94 Air Pollution Control Division Facility Name: Enterprise Compressor Station Facility Identification Code: CO 1230277 ADMINISTRATION is application contains the following forms: x Form 2000-100,Facility Identification x Form 2000-101,Facility Plot Plan x Forms 2000-102,-102A,and-102B,Source and Site Descriptions IL EMISSIONS SOURCE Total Number DESCRIPTION of This Form This application contains the following forms -1 Form 2000-200,Stack Identification (one form for each facility boiler,printing Form 2000-300,Boiler or Furnace Operation Form 2000-301,Storage Tanks Form 2000-302,Internal Combustion Engine Form 2000-303,Incineration Form 2000-304,Printing Operations Form 2000-305,Painting and Coating Operations Form 2000-306,Miscellaneous Processes Form 2000-307,Glycol Dehydration Unit III. AIR POLLUTION CONTROL Total Number SYSTEM of This Form This application contains the following forms: r- Form 2000-400,Miscellaneous • Form 2000-401,Condensers Form 2000-402,Adsorbers Form 2000403,Catalytic or Thermal Oxidation Form 2000-404,Cyclones/Settling Chambers Form 2000-405,Electrostatic Precipitators I.. 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 x Form 2000-500,Compliance Certification-Monitoring and 2 (one for each facility boiler,printing operation, Reporting Form 2000-501,Continuous Emission Monitoring X Form 2000-502,Periodic Emission Monitoring Using 1 Portable Monitors x Form 2000-503,Control System Parameters or Operation 1 Parameters of a Process I Form 2000-504,Monitoring Maintenance Procedures Form 2000-505,Stack Testing Form 2000-506,Fuel Sampling and Analysis x Form 2000-507,Recordkeeping 2 x Form 2000-508,Other Methods 1 • 9 - V. EMISSION SUMMARY AND Total Number COMPLIANCE CERTIFICATION of This Form .This application contains the following forms ❑ Form 2000-600,Emission Unit Hazardous Air Pollutants quantifying emissions,certifying compliance with applicable requirements,and developing a compliance plan O Form 2000-601,Emission Unit Criteria Air Pollutants x Form 2000-602,Facility Hazardous Air Pollutants 1 x Form 2000-603,Facility Criteria Air Pollutants 1 ❑ Form 2000-604,Applicable Requirements and Status of Emission Unit ❑ Form 2000-605,Permit Shield Protection Identification ❑ Form 2000-606,Emission Unit Compliance Plan- Commitments and Schedule ❑ Form 2000-607,Plant-Wide Applicable Requirements o Form 2000-608,Plant-Wide Compliance Plan- Commitments and Schedule VI. SIGNATURE OF RESPONSIBLE OFFICIAL - FEDERAL/STATE CONDITIONS J A. STATEMENT OF COMPLETENESS I have reviewed this application in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this application are true, accurate and complete. B. CERTIFICATION OF FACILITY COMPLIANCE STATUS -FEDERAL/STATE CONDITIONS (check-one box only) X I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. O I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements, except for the following emissions unit(s): (list all non-complying units) WARNING: Any person who knowingly, as defined in § 18-1-501(6), C.R.S., makes any false material statement, representation, or certification in, or omits material information from this application is guilty of a misdemeanor and may be punished in accordance with the provisions of§25-7 122.1, C.R.S. Printed or Typed Name Title Joseph Kuchinski Vice President, Area Operations North Signature ,{ Date Signed 10 • Operating Permit Application CERTIFICATION FOR STATE-ONLY CONDITIONS FORM 2000-800 Colorado Department of Health 09-94 Air Pollution Control Division Facility Name: Enterprise Compressor Station Facility Identification Code: CO 1230277 VI. SIGNATURE OF RESPONSIBLE OFFICIAL-STATE ONLY CONDITIONS A. STATEMENT OF COMPLETENESS I have reviewed this application in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this application are true, accurate and complete. B. CERTIFICATION OF FACILITY COMPLIANCE STATUS FOR STATE-ONLY CONDITIONS (check one box only) I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements, except for the following emissions unit(s): (list all non-complying units) WARNING: Any person who knowingly, as defined in § 18-1-501(6), C.R.S., makes any false material statement, representation,or certification in, or omits material information from this application is guilty of a misdemeanor and may be punished in accordance with the provisions of§25-7122.1, C.R.S. Printed or Typed Name Title Joseph Kuchinski Vice President, Area Operations North Signature Date Signed iCr4..-9/4O:te I /1 - 7G - 20 ,) SEND ALL MATERIALS TO: COLORADO DEPARTMENT OF HEALTH APCD-SS-B1 4300 CHERRY CREEK DRIVE SOUTH DENVER, CO 80246-1530 • 11 MAJOR SOURCE OPERATING PERMIT APPLICATION APPLICATION COMPLETENESS SUMMARY FORM 1. FACILITY NAME: 2. PERMIT: •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 Or COMPLETE(BASIC INFORMATION PRESENT TO BEGIN PROCESSING) INCOMPLETE-RETURN WITH ADDITIONAL INFORMATION BY: COMMENTS REVIEWED BY: DATE MAJOR SOURCE OPERATING PERMIT APPLICATION APPLICATION COMPLETENESS CHECK LIST I. IDENTIFYING INFORMATION COMPLETE INCOMPLETE NOT APPLICABLE 12 A. FACILITY INFORMATION FACILITY NAME, LOCATION&MAILING ADDRESS _ YES NO PERMIT CONTACT PERSON YES _ NO RESPONSIBLE OFFICIAL YES _ NO �ERMIT 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 _ YES 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 YES _ NO N/A 6. OTHER INFORMATION REQUIRED BY ANY APPLICABLE REQUIREMENTS FOR ALL REGULATED AIR POLLUTANTS SUCH AS: FLOW RATES _ YES NO _ N/A STACK PARAMETERS _ YES NO _ N/A 7. CALCULATIONS ON WHICH EMISSIONS RELATED INFORMATION ARE BASED YES NO _ N/A 13 III. APPLICABILITY COMPLETE _ INCOMPLETE NOT APPLICABLE 1. CITATION AND DESCRIPTION OF ALL APPLICABLE REQUIREMENTS YES 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 eT 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 0 14 . Operating Permit Application COMPLIANCE CERTIFICATION-MONITORING AND REPORTING FORM 2000-500 Colorado Department of Public Health and Environment DESCRIPTION OF METHODS USED Rev 06-95 Air Pollution Control Division FOR DETERMINING COMPLIANCE All applicants are required to certify compliance with all applicable air pollution permit requirements by including a statement within the permit application of the methods used for determining compliance. This statement must include a description of the monitoring,recordkeeping,and reporting requirements and test methods. In addition,the application must include a schedule for compliance certification submittals during the permit term. These submittals must be no less frequent than annually,and may need to be more frequent if specified by the underlying applicable requirement or by the Division. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Enterprise Compressor Station 2. Facility identification code: CO 1230277 3. Stack identification code: TBD 4. Unit identification code: Tl 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): X Periodic Emission Monitoring Using Portable Monitors-Form 2000-502 Pollutant(s): NOx and CO • 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): X Recordkeeping-Form 2000-507 Pollutant(s): NOx,CO,VOC,Fuel Consumption X Other(please describe)-Form 2000-508 Pollutant(s): Visible emissions shall not exceed 20%Opacity • • 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: Will follow same schedule as current reports-January 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:Will follow same schedule as current reports—January/July and every 6 months thereafter. (6 month maximum interval) • • Operating Permit Application COMPLIANCE DEMONSTRATION BY PERIODIC EMISSIONFORM 2000-502 Colorado Department of Public Health and Environment MONITORING USING PORTABLE MONITORS Rev 06-95 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: Enterprise Compressor Station 2. Facility identification code: CO 1230277 3. Stack identification code: TBD 4. Unit identification code: Tl 5. Pollutant(s)or diluent(s)being monitored: NOx and CO 6. Name of manufacturer: Ecom AC Plus and Other 7. Model & serial number: Unknown 8. Is this an existing system? X Yes No 10. Type: In situ X Extractive LIDilution Other(specify) 11. Very briefly explain the measurement design concept of the monitor Will follow the Colorado Portable Analyzer Protocol. 12. Backup system: Similar portable monitor 13. Compliance shall be demonstrated: Daily I I Weekly In Monthly x Other-specify-Quarterly 14. Quality Assurance/Quality Control: DCP will follow the Colorado Portable Analyzer Protocol. • ***** Any test value over the emission limit shall be reported as an excess emission. ***** • Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of Public Health and Environment BY RECORDKEEPING Rev 06-95 Air Pollution Control Division Recordkeeping may be acceptable as a compliance demonstration method provided that a correlation between the parameter value recorded and the emission rate of a particular pollutant is established in the form of a curve or chart of emission rate versus parameter values. This correlation may constitute the certification of the system. For an existing program,the correlation demonstration must be attached for Division consideration for approval. If the correlation information has not yet been developed,please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Enterprise Compressor Station 2. Facility identification code:CO 1230277 3. Stack identification code: TBD 4. Unit identification code: T1 5. Pollutant(s)being monitored:NOx,CO,VOC 6. Material or parameter being monitored and recorded: Fuel Consumption 7. Method of monitoring and recording(see information on back of this page): DCP will monitor the facility-wide fuel consumption and calculate the turbine fuel consumption based on hours of operation and heat rate of the unit. The emissions will be calculated based on the emissions factors listed in the permit and required operating parameters required to complete that calculation. 8. List any EPA methods used: 9. Is this an existing method of demonstrating 10. Start date: TBD • compliance? Yes X No—New unit but similar records 11. Backup system: 12 a. Data collection frequency: Daily I Weekly X Monthly I Batch(not to exceed monthly) Other-specify 12 b. Compliance shall be demonstrated: I Daily I Weekly X Monthly I Batch(not to exceed monthly) J Other-specify 13. Quality ControllQuality Assurance: The monitoring system shall be subject to appropriate performance specifications,calibration requirements,and quality assurance procedures. J DCP already completes this type of recordkeeping for the existing sources at the facility. This source will just be added to that spreadsheet. 14. A proposed format for the compliance certification report and excess emission report is attached. ***** 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: Enterprise Compressor Station 2.Facility identification code: CO 1230277 3. Stack identification code:TBD 4.Unit Identification code: T1 5.Pollutant(s)or Parameter(s)being monitored: Opacity of effluent 6. Description of the method of monitoring: This source combusts natural gas;therefore,compliance with the 20%opacity limit is presumed. • 7. Compliance shall be demonstrated: (Specify the frequency with which compliance will be demonstrated) N/A • • COMPLIANCE CERTIFICATION- MONITORING AND REPORTING FORM 2000-500 Colorado Department of Public Health and Environment DESCRIPTION OF METHODS USED Rev 06-95 Air Pollution Control Division FOR DETERMINING COMPLIANCE All applicants are required to certify compliance with all applicable air pollution permit requirements by including a statement within the permit application of the methods used for determining compliance. This statement must include a description of the monitoring,recordkeeping,and reporting requirements and test methods. In addition,the application must include a schedule for compliance certification submittals during the permit term. These submittals must be no less frequent than annually,and may need to be more frequent if specified by the underlying applicable requirement or by the Division. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Enterprise Compressor Station 2. Facility identification code: CO 1230277 3. Stack identification code: 063 4. Unit identification code: P013 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): • x Monitoring Control System Parameters or Operating Parameters of a Process-Form 2000-503 Pollutant(s): VOC I Monitoring Maintenance Procedures-Form 2000-504 Pollutant(s): I Stack Testing-Form 2000-505 Pollutant(s): L Fuel Sampling and Analysis(FSA)-Form 2000-506 Pollutant(s): X Recordkeeping-Form 2000-507 Pollutant(s): VOC,Throughput X 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: Will follow same schedule as current reports-January 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: Will follow same schedule as current reports—January/July and every 6 months thereafter. (6 month maximum interval) • • • Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-503 Colorado Department of Public Health and Environment MONITORING CONTROL SYSTEM PARAMETERS OR Rev 06-95 Air Pollution Control Division OPERATING PARAMETERS OF A PROCESS The monitoring of a control system parameter or a process may be acceptable as a compliance demonstration method provided that a correlation between the parameter value and the emission rate of a particular pollutant is established in the form of a curve of emission rate versus parameter values. Ideally stack test data that bracket the emission limit,if possible,could be used to define the emission curve. This correlation shall constitute the certification of the system. It should be attached for Division approval. If it is not attached,please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Enterprise Compressor Station 2. Facility identification code: CO 1230277 3. Stack identification code: 063 4. Unit identification code: P013 5. Pollutant(s)being monitored: VOC 6. Name of manufacturer: Teed Fabrication Combustor 7. Model number: EF36 8. Is this an existing system? X Yes No 9. Reserved for future use 10. Describe the method of monitoring: There will be continuous pilot monitoring(verify presence of flame,thermocouple, fire eye or other equivalent method)and an auto igniter. • 11. Backup system: Auto igniter with battery and solar panel.Also,operator visually checks flare on a daily basis. 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 13. The applicant shall propose an appropriate avenging period,(i.e.,a particular number of continuous hours)for the purpose of defining excess emissions. The Division may approve the proposed avenging period,or other period which the Division determines to be appropriate. Provide the proposed avenging period(s)below. Parameter Averaging Period • • Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of Public Health and Environment BY RECORDKEEPING Rev 06-95 Air Pollution Control Division Recordkeeping may be acceptable as a compliance demonstration method provided that a correlation between the parameter value recorded and the emission rate of a particular pollutant is established in the form of a curve or chart of emission rate versus parameter values. This correlation may constitute the certification of the system. For an existing program,the correlation demonstration must be attached for Division consideration for approval. If the correlation information has not yet been developed,please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Enterprise Compressor Station 2. Facility identification code: CO 1230277 3. Stack identification code: 063 4. Unit identification code: P013 5. Pollutant(s)being monitored: VOC 6. Material or parameter being monitored and recorded: Condensate Production 7. Method of monitoring and recording(see information on back of this page): Emissions will be calculated using the emission factors established in the permit. The amount of condensate produced will be tracked on a monthly basis. 8. List any EPA methods used: 9. Is this an existing method of demonstrating 10. Start date: compliance? X Yes 41) 11. Backup system: 12 a. Data collection frequency: Daily 1 Weekly X Monthly Batch(not to exceed monthly) '. .Other-specify 12 b. Compliance shall be demonstrated: Daily I Weekly X 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. This is an existing source.The emissions are now controlled by 95%with a combustor. The emissions will be calculated based on the emission factors in the permit and a 95%control factor will be applied. 14. I A proposed format for the compliance certification report and excess emission report is attached The compliance reports will remain the same. ***** 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. Appendix B Emission Calculations w/ GHG 0 N en a a r00000 _ e 0 0 a t'atiyY ¢e q1'•C FMNIIV e _ e oLfr. : : : ; : ee 6 rv - M • Os c N N „ e o 0 0 o e o e a tn ` 4 D P P ^ .e O O O O „ O O O. a< m m m n e ,� a= hha a U e N N N 0 0 0 0 .q. e o e 5 ," N k - - - - e ry 72 a o e ° 0 e co c a u a - - _ a _ 0l e e e e N ,,ry o et;_ e o e o e 74 ri tm a F e. 4444 on - 0 0 0 r ca CI- e e o., o m eesama 2, -a 1 e o o r ry • « N e II II en en n n - a N o _ �, e - - e IN a a — Z' a U rvrvrv ," ^ 0000 4 e e ,o e _ U e e e e a o v o M v E = 6 a a g 1 0 7�I 0 et et • • - '_e a. e _ - .. Z F C le F : E N O 'AO o0 00o_. r_� a,n 0 0 0 0 -: c o e a .. U U C Wal '`C — o a �a uh _ _•a So i - - ^ ^ ry 0000 a e a o e o W — C e 0 0 0 0 ai O a 0 0 •„ ,y0. ,�I - - - - oi0000 ,e a a to F = O Tit: O m 0000 0 0 n e0 0 0 o e 'i 0 N f „1 0' CD a : 2 WI O HCD 3 . E F ,� 000 0 - e o e V,y "' S O E N 0 CI 0 cc a y ei -•- d 00000m .ery .1. 0 0 0 e � m t o o o 0 0 6 e o e ry m . a e e a U Ca) `$ 0 0 0 e 0 6 0 0 "n LT. as - - - - a,0 - - - - a, eee s, I - S= e a e e°' 0 6 0 e o e U ,� e o e r Q & — �( m m .On m e N f"" O P 0 0 O R W a O q err e F 6 _ C 1 m w - ^ 0 0 0 v h I P ry e o — eV - n `. f mmm - 0 ' 7. a ," CI eV O S n It r Ivs t — — N N e o e & G y� a a rn rn °° e m n ,n' ry ry .O (� V- 4000 0 O O N Et U mmmn = 6666 rive, 0 ,., n a E 4 d ¢ Q 0 T)II w 4 0 6 0 o, a a F lie. to Z .= 0 ,,T, ,7, ry ry y` o 066 _ e — wm yx < raj' � S v 1 F P O 0 0 0 - 0 0 0 0 - 0 0 0 - e O 2o e — 0 U,.; o X _ _ _ _ rv0000 a e 6 e .1 E i 6 0 - - - - ri 0 0 0 0 as e o e a t O tN — 2 O a el 4 g m _ -. - - ," 6000 ' e a e a; ;L; ^ N II II II r ZZce e o $ Y a a s` e O a, o me y e r,, me A W a d o I- c o L w a 1 Ern° '� � � � 5 ` eC. o P `- e Po U �i ,o ,o �o F o ° �i a 0 r, F •T y Q `a e e O U P - E g u E a c a E '�Fp. f4p�Fµ P�p.. ' a.m P. 63 0 To m a p G G G G F 0 'E .y '�' v O d d@ M 0 e U U U U .M W r4 y a § NC 6 2 C O 4 W y a N O S "= 7, 33II y ', ° ° o ",.� _ _ _ 0 ? o I m F W x Q U UUUa F- 0 as g II II II II 'y' 0 N o 0 a,U a a a • Compressor Engine Emissions Calculations DCP Midstream,LP Enterprise Compressor Station Caterpillar 63612 SI•Compressor Engine(4 Strobe Lean Bum,3,66041P) Engines P016,C236,0.236,and C-238 um iLDno 4 3.550 M 6900 6.750_➢010,'. I4a0.64e4n Heat P•pul 24 00 mmbpder OOtol3 BtA.4 1. 6,703 tiny 955 butt: a t,onru.lij.e: 21544 n-npq/yr 'Ma rwaeweel od4 rated At SI 0-PI pleb Criteria Poeutenl Engelke,CAlcula0ona Uncontrolled Emblon Factors P r4.n0s1 Ep;.alona Collimate Emission lectors "Coo0WM0 Emissions Peltuum (eoruyrl (ton/PI „00:-<, 0 70➢IE6pte 24.00 0.70$rnnohr 24 00 CO 260 a%hpM 65.70 0.16 p'DAD-t o 6.17 10C° 6.15 ma�4 r 219 67 11C 0,06P-6, 34 26 PM' 9.40E-03 1l+mm�eu 1.05 699E-93 W or91. 105 1 5,5,` 5.06E-04 Itrmm&e t.oe 5 66E-04 INnena. 0.06 'Eves msnoice ren ton vim ha.. 'uncoMte0ed a rnos,on!65 000 Iran 4-40ake.Inn-bun 44888)money from EPA's 41'42 C'taper 3.2.Tatr 32-2 Note PSI emvan faolor r dudes bAth coodensabt 1047005006 Non.CrM.rl.Rvoelabre P01/Ober Colcof.tlemr 7 Potential Emissions Comm ECom o), Controlled Emw4ons a Nlalmj r Poll✓.ent HAP Qnli loo facto,.' Dam&mroe <p_ j 05M) % (314/1u, (1-53 B9 1'.,2 7-1.ya<Nplee0-er, 4 -0%ly NEEP4 EPA 3.e0E-a 48 41 50% 420 r A 50 1,1 2.1npHpreeMane <0 16E-05 Mime,-&v EPA 4 761E-04 `669 30% 3 Y A 50 1�8wdw,n. 67E-04 1bA1,mQF•C 1v EPA 6.41J 50.13 90% 26 05 A 50 13,Ohar4ptpptne 4264--05 RVrvrAf7 EPA 0634E-04 0565 50% 277 A 50 2,24•7renN5ylpentspe 2 50E-64 6,P1,4nEJV % 6.00[-03 0 52 56 50% 2676 0 1920 2- 4, Gene 331E-OS IW•o 9% 7.07E-04 c 696 349 Aeenapeutep4 . 1 255.455 11.nn,Div EPA 3.000.75 << 30 E 59% 313 Ac.n1pn111yprt. 6630Eg 99QQ99¢¢INmm810 _ EPA 133E-04 <116 5jp�%, 0Se AC.Ie'd9hyPi 636E-9'J'Iphry,.flli EPA 2Q'E-01 0770746 E 67673 A Ao0,5in 5.146 1y EPA 0.23E-01 <1060.54 550 0 Q.nf004 440E-041ymrrRtc EPA to(e-02 402.50 S0% 467 A 56 ena0(b)e:vorenew4 160E-07Iymn0le EPA 39156•06 00.03 50% 002 . M01P1n4ne 4.16E-07 rym'ndie _ EPA 9906.06 00.09 50% -2 - 50% 001 '.094,40YCarton 7eLartlpgp 03E7E b-0.441yrvnRtu EPA 5 C9t-07 044,57 50% 'x'.26 C 10cc • IC-16101 tnL.r,e <704E-0Sf' EPA < 81♦j•01 , e 7.72 SO% 3116 A Sc dr m@1y EPA <7,10E-04 4 6.Yj 50% J 201 A So GH101010- <745P-0514frr1mfltu EPA <604E-04 0999 56% 7.00 A 50 Gnryune 6.01E-07,IDhnmetu EPA 166E-OS 00.15 00% 057 EP,rDtditr. 3976.70 tN,[Iln$7u EPA 457E-9. 0$35 90% 4.17 C 1000 1EtAll re 3160076876 44.13E-0S 0Nrnln0,u EPA r <006E-00 <9.31 00% 464 A so Elupppthene 111E-05,IOlmno. F4 2.66E-05 49,2,7 50% 012 P:<0.eae 947E 14Emmtto tPA 1.36E44 0119 50% 060 F4lmlldchyo. 040)30So4o 6400 3.136.00 _ 037423.74540425 Mr."6 2540.05 wr.mao EPA 6.09E-54 0 525 56 CS 267 75 P c 1300 Mc letend Mallet 20045 Emvn81.1 EPA 0 480E-04 <4 23 50% 210 A 90 54stlEaltno /44E-0S:es1I.- k EPA 1.79E-03 <15 54 50% 7 62 C 1QQpppp n a-e 111E-03 term 919 EPA 266E-12 023335 50% 11607 . C 1909 PAH 269E-05'Iymm8'.u FPA 6.46E-54 0565 2 Pn.nm1ne 1.04E-05 Iym _mEno EPA 2SOF-04 <759 - 00% � ti 60 h P1vr,01 2.406.05 440 EPA 3.760.04 c 05 60% 252 C 1000 Ppeon 136E-06 690W00..: EPA 3.26E-05 c 29 5054 014 Elyrer. .2.15.E.05,5,/mm55.. EPA r 0266E-04 <1,46 50% 2.40 C 1009 Telachlom09.3ne 746E-061 pm,mRw EPA 5956-05 00.52 - 50% 0.26 P 60 Towtn. 4 36E-94 19AR^Bw EPA 9 79E.05 $5.77 50% 42.69 C 1009 1AnA CkA{ 1.44E-0r3 bAnmEMu EPA 3.58E-04 05.13 50% 1.57 _ A 4•� 50 mieresimy of 1.64E-04 en/mmElu EPA 4.436 05 t <36.60 soli 19.14 C iota 70TAL _ 5.60 31501,01 7625.41 -- - •0,5r:ro-Id a m%so6 1101045 ham 4-etr0kt.1150-0„00(4509)en➢-nes 110,,,EPA's A0-42 Chapter 3 7 Table 3 2-2 'Den*:...As eM4 lo,,.7061 4.on.cr4ena polulamf,pm Cob ado Reyulrion Na 3 ill 207 Ma.Ire4m,LP 1O2420I' 111 Gas G3612 CATERPILLAR' Petroleum 3195-3550 bhp 2383-2647 bkW Engine 900-1000 rpm CATERPILLAR. ENGINE SPECIFICATIONS i i j y V-12, 4-Stroke-Cycle Bore — in (mm) 11,8(300) ,.d-t , •f> Stroke-in (mm) 11.8 (300) i i 1 ++ a'. i ` i 3i1^�• Displacement—cu in (L) 15,528(254.4) -V ' ,t 11r 6 A�;. Aspiration Turbocharged and Aftercooled �� ga s Capacity for Liquids—U.S. gal(L) j '1 _ � Jacket Water Circuit' 177 (669) i , , Aftercooler Circuit' 17 (64) 1 Lube Oil System (refill) 272 (1030) Shown with Lube Shipping Weight Optional Equipment (Dry)—lb (kg) 55,300(25 084) `Engine only FEATURES ■ FULL RANGE OF ATTACHMENTS a G3612 • Wide range of bolt-on system expansion • Low emissions attachments,factory designed and tested • Broad operating speed range and ■ UNMATCHED PRODUCT SUPPORT ability to burn a wide spectrum of OFFERED THROUGH WORLDWIDE gaseous fuels • CATERPILLAR DEALER NETWORK • Caterpillar Advanced Digital Engine • More than 1,500 dealer outlets Management(ADEM Ill)control system • Caterpillar factory-trained dealer with detonation-sensitive timing control technicians service every aspect of your for individual cylinders petroleum engine • Robust diesel strength design provides • 99.7% of parts orders filled within 24 prolonged life and lower owning and hours—worldwide operating costs. • Caterpillar parts and labor warranty ■ TESTING • Preventive maintenance agreements • Prototype testing on every model: available for "repair before failure" - proves computer design options - verifies system torsional stability • Scheduled Oil Sampling (5.0.5") —functionality tests every model program matches your oil sample • Every Caterpillar engine is dynamometer against Caterpillar set standards to tested under full load to ensure proper determine: engine performance. - internal engine component condition • WEB SITE - presence of unwanted fluids • For additional information on all your - presence of combustion by-products ' petroleum power requirements, visit • SINGLE-SOURCE SUPPLIER www.cat-oilendgas.com. • Caterpillar: —casts engine blocks, heads, cylinder liners,and flywheel housings — machines critical components assembles complete engine yet'P4 Ownership of these manufacturing Q Baint� CE processes enables Caterpillar to produceISO A Dfl high quality, dependableproduct. ER IF E 9 P CERTIFIED • Factory-designed systems built at t Caterpillar ISO certified facilities LFHW0814-01 CATERPILLAR` G3612 GAS PETROLEUM ENGINE • FACTORY INSTALLED STANDARD & OPTIONAL EQUIPMENT SYSTEM STANDARD OPTIONAL Air Inlet Air cleaner--- standard-duty Heavy-duly air cleaner with precleaners Inlet air adapter Heavy-duty air cleaner with rain protection Charging System Charging alternators Control System Caterpillar ADEM III control system Custom control system software is available provides electronic governing integrated for non-standard ratings.Software is field with air/fuel ratio control and individual programmable using flash memory. cylinder ignition timing control Cooling System Jacket water pump Expansion tank Jacket water thermostats end housing Flexible connections Aftercooler pump Jacket water heater Aftorcooler water thermostats and housing Single-stage aftercooler Exhaust System Dry wrapped exhaust manifolds Flexible bellows adapters Vertical outlet adapter Exhaust expander Weld flanges Flywheel/ SAE No.00 flywheel Flywheel Housing SAE No.00 flywheel housing SAE standard rotation • Fuel System Gas admission valves with electronically Fuel filter controlled fuel supply pressure Gas pressure regulator Flexible connection Low energy fuel system Corrosive gas fuel system Ignition System ADEM ill control system senses individual CSA certification cylinder detonation and controls Individual cylinder timing Instrumentation LCD display panel monitors engine Remote date monitoring and speed control parameters and displays diagnostic codes Compatible with Cat Electronic Technician(ET) and Date View Customer Communication Module(CCM) Display panel deletion is optional Lube System Crankcase breathers hop mounted) Air or efectric motor-driven prelube Oil cooler Duplex oil filter Oil filter LH or HH service Oil pen drain valve Lube oil makeup system Mounting System Engine mounting feet(six total) Mounting plates(set of six) Power Take-Offs Front stub shafts Protection Electronic shutoff system with purge cycle Crankcase explosion relief valveS Gas shutoff valve Starting System Air starting system Air pressure reducing valve Natural gas starting system General Paint,Caterpillar yellow Engine barring device Vibration dampers Damper guard LEHIN0814-01 • Ili G3612 GAS PETROLEUM ENGINE CATERPILLAR' TECHNICAL DATA G3612 Gas Petroleum Engine— 900-1000 rpm DM5312.00 DM5310-00 Engine Power @ 100%Load bhp(bkW) 3195(2383) 3550(2547) @ 75%Load bhp(bkW) 2397(1787) 2662(1985) Engine Speed rpm 900 1000 SCAC Temperature °F(°C) 130(54) 130(54) Compression Ratio 9.0:1 9.0:1 Emissions` NOx g/bhp-hr 0.70 0.70 CO g/bhp-hr 2.50 2.50 Total Hydrocarbons g/bhp-hr 5.85 6.15 Fuel Consumption @ 100%Load Btu@hp-hr(MJ/bkW-hr) 6,670(9.30) 6,76019.57) @ 76%Load Btu1hp-hr(MJ/bkW-hr) 6.805(9.631 7,05019.98) Heat Balance Heat Rejection to Jacket Water @ 100%Load Btu/mn(bkW) 32,168(566) 36,195(636) • @ 75% Load Btu/mn(bkW) 28,721 (505) 31,271(550) Heat Rejection to Aftercooler @ 100%Load Btu/mn(bkW) 21,222(373) 26,509(466) @ 75% Load Btu/mn(bkW) 9,333(164) 14,525(255) Heat Rejection to Exhaust @ 100%Load Btu/mn(bkW) 134,721 (2369) 154,67312720) @ 75%Load Btu/mn(bkW) 107,091(1883) 123,769(2176) Exhaust System Exhaust Gas Flow Rate @ 100%Load cfm(m'/min) 20,634(584) 23,461 (664) @ 75%Load cfm(m3/min) 16,100(456) 18,554(525) Exhaust Stack Temperature @ 100%Load °F(°C) 846(452) 858 1459) @ 75%Load °F('Cl 867(454) 8781470) Intake System Air Inlet Flow Rate @ 100%Load dm (m'/min) 8,527(241) 9.598(272) @ 75%Load dm (m3/min) 6,6421185) 7,477(212) Gas Pressure psi(kPal 43(295) 43(295) °at 100% load and speed lill LEHW0814-a1 ili ,. •_ CATERPILLAR° G3612 GAS PETROLEUM ENGINE GAS PETROLEUM ENGINE 186.42 93.68 (4735.11 (2379.5( 1 1 . F,.:. " J rn C ti �I .. 9 ' 17.6.77 (3219.91 Ei: � 1 . It w /r'-_ L I' DIMENSIONS j Note: General configuration not to be used Length in (n1m} 186.42(4735.1) for installation, See general dimension ill drawings for detail. width in(mm) 93.68(2379.5) Height in(mm) 126.77 (3219.9) Shipping Weight lb(kg) 55,300(25 084) RATING DEFINITIONS AND CONDITIONS Engine performance is obtained in accordance Conditions: Power for gas engines is based on with SAE J1995, 18O3046/1, 6S5514/1, and fuel having an LHV of 905 Btu/cu ft (33.74 kJJL) DIN6271/1 standards. at 29.91 in. Hg (101 kPa)and 59°F (15° C). Fuel rate is based on a cubic meter at 29.61 in. Hg Transient response data is acquired from an (100 kPa) and 60.1° F (15.6° C).Air flow is engine/generator combination at normal based on a cubic foot at 29.61 in. Hg (100)(Pa) operating temperature and in accordance with and 77° F (25° C) Exhaust flow is based on a 1S03046/1 standard ambient conditions. Also in cubic toot at 29.61 in• Hg(100 kPa) and stack accordance with SAE J1995, BS5514/1, and DIN6271/1 standard reference conditions, temperature. 7 TMI Reference No.:DM5312•on,Dv15310.00 Materials and apecif cations are tub1eet to chenfle without notice, T•e International System of Unit ISOis used in this publication. LE4WUA14.01 15.01; Pnnted in V.S.A. ®2001 Caterpillar All rights reserved. �/200? 1.4:51 DCP MIDSTREAM 4 9130%051957 NO.660 D03 vV� Ir +r . nn iv lr +t,J, cnV+11YYVnr Vnnicw _JJUL/JVJ all . EAS, Incorporated • 685 Saddle Ridge Crystal Lake, IL 60012 January 25, 2005 Duke Energy Ftold Services Duke Energy Field Services Mr. David Stultz Mr. Frank Watson Greeley CO Denver, CO SENT VIA EMAIL • J Subject: Slide in Silencer Design for Weld County G3612 EAS Proposal 050125.3 .-r✓�J� Gentlemen, The challenge: To find a combination silencer that can be lowered into an existing framework at the jobsite. The framework sketch shows an inside area that is 45" square. The diagonal measurement of this is 63.6". The combination unit we offer will fit into the rack. The best performance we can provide in this diameter is industrial grade. Based on the information,we are honored to offer the followinRproposai: Engine Model CAT3612TALE HP 3550 All engine data used from Caterpillar(Data Set 0M5320 RPM 9001 04 April 8,2004 Exhaust Flow ACFM 23,809 Temperature(F) 858 ThIs information is the sole basis for sizing and Calculated SCFM 9500 performance guarantees. Post Catalyst Em iselons • Pro-Catalyze Untreated Emissions from Englne(0 Ibh or e0 af i In grronp•nr. n eledl One/Or ORE Ye Reduetbn from Pre-Catalyst Values) Nox 0.7 oN % na CO 15 CO 834Je NMHC 0.92 NMHC >75% NMNEHC 0.61 NMNEHC >80% a HCHO i 0,4 HOHO >80% CATALYST DESCRIPTION Catalyst ADCAT All SS Metal Monolith Yea — Catalyst Type CO. HCHO Oxidation Anti Telescoping Bracing Yes Catalyst Size '4 ea 21"sq. x 3.5 de Precious Metals by Weight Yes CPSI 280 buret SS Band (or Frame) Yes Hartle n/a Procoated Material NONE COMBINATION 91LENCBR DESCRIPTION Nominal Outside Diameter 61" Qenmal Grade Designation Industrial _ Approximate Length '200" dbA reduction 18-Dee Material CS Backpressure BA High Temp Paint (not for SS) eye& Double Wall Construction 1st chamber Inlet Flange Size 18" Drain Plug yes __ Outlet Flange Size 2811 End in -End Out Style _Yes Toter Test Ports 6 Mounting 4 horiz. Adj. lugs nee ash $30,942 _ c it Lead Time: 8 weeks after prints approved or about 12 weeks total ARO. \\ilk.° — Telephony 815-444.0291 Fps a1S-444-020t Emoii' Indian©lnc net •- Wohatle: www.enc-Inc.mn PJr Pollution Control Systems and COneulung Services 95%Heel Rocnvory RTC's.VOC.CO,OWWOel&NSCR Catalysts Piedouc Metal Recovery,System Ungrodes,VQt;e1s 4 5nencelc.Catalytic Oxidizers r Exhaust Silencer Concept Weld County G3612LE Project Ladderless Catalyst A 01-10-05 EAS, Inc. No Scale 14" r? 0 Freq Insert'n A OIL Band Loss 98" Type 2 Test Ports ' 31.5 Hz 16dBA 56' 63 31 125 38 ,J _ � _ �� 250 36 _ 14—28".+ Flexible Design 500 32 Inlet Location to -----r —� Minimize 1K 30 Backpressure • from Pipe Bends 2K 29 . + 4K 28 A - 28"dia. 8K 28 — omposite Reduction--35dB Flexible to 216" Notes: 46-- 72' Delta P: 5.3"w.c.total Weight:—9,800 pound 362" Alumin Aluminized Steel rated Catalyst location behind access doors _ - near grade ---____ -- ) Base Skirt with r,�ro�urain holes on Ring iv - 1 1 .ii____78" tol EAS, Inc. 685 Saddle Ridge Crystal Lake, IL 60012 815-444-0291 indian@mc.net Dennis Kostrzewski Natural Gas Turbine Enterprise Compressor Station • DCP Midstream, LP Source ID T1 Stack Height ft Description Turbine 1 Stack Temp. deg F Manufacturer Solar Stack Flow acfm Model Taurus 70 Stack Velocity ft/min Serial# TBD Stack Base ft AMSL Operation Date TBD Emission Control None Latitude deg Longitude deg Fuel Heat Value 958 Btu/scf or Design Output 10,142 HP UTM Zone Site Output 10,142 HP UTM Northing m Potential Operation 8760 hrlyr UTM Easting m Potential Heat Rate 7272 Btu/hp-hr Datum Potential Heat Rate 73.75 MMBto/hr Potential Fuel Use 76983 scf/hr Potential Fuel Use 674.37 MMscf/yr Potential to Emit Emission Emission Source of CAS Factor Factor Emission Pollutant Number (lb/MMBtu) (g/hp-hr) (lb/hr) (ib/yr) (ton/yr) Factor NOx -- 0.1982 . 4.43 38820.90 19.41 Manf Spec CO -- 0.2012 4.50 39408.50 19.70 Manf Spec VOC — 0.1152 2.58 _ 22563.91 11.28 Mani Spec SO2 0.0034 0.25 2196.57 1.10 AP-42 PM 0.0066 0.49 4263.93 2.13 AP-42 1,3-Butadiene 106-99-0 4,3E-07 3.17E-05 2.78E-01 1.39E-04 _ AP-42 Acetaldehyde 75-07-0 4.0E-05 2.95E-03 2.58E+01 1.29E-02 AP-42 Acrolein 107-02-8-1 6.4E-06 4.72E-04 4,13E+00 2.07E-03 AP-42 • Benzene 71-43-2 1.2E-05 8.85E-04 7.75E+00 3.88E-03 AP-42 Ethylbenzene 100-41-4 3.2E-05 2.36E-03 2.07E+01 1.03E-02 AP-42 Formaldehyde 50-00-0 7.1E-04 5.24E-02 4.59E+02 2.29E-01 AP-42 Naphthalene 91-20-3 1.3E-06 9.59E-05 8.40E-01 4.20E-04 AP-42 PAH 2.2E-06 1.62E-04 1.42E+00 I 7,11E-04 AP-42 Propylene Oxide 75-56-9 2.9E-05 , 2.14E-03 1.87E+01 9.37E-03 AP-42 Toluene 108-88-3 1.3E-04 , 9.59E-03 8.40E+01 4.20E-02 AP-42 genes 1330-20-7 6.4E-05 4.72E-03 4.13E+01 2.07E-02 AP-42 Total HAPs 7.58E-02 6.64E+02 3.32E-01 AP-42: NOx&CO: EPA AP-42,Volume I,Fifth Edition,April 2000,Table 3.1-1. VOC, SO2,PM:EPA AP-42,Volume I,Fifth Edition,April 2000,Table 3.1-2a. HAPs:EPA AP-42,Volume I,Fifth Edition,April 2000,Table 3.1-3. Solar Turbines PREDICTED EMISSION PERFORMANCE A Caterpillar Company Customer Engine Model DCP-Midstream TAURUS 70-10302S Job ID CS/MD 59F MATCH Weld County Compression IngLiry Number Fuel Type Water Injection DN11-0028 SD NATURAL GAS NO • Run By Date Run Engine Emissions Data Michael E Clay 26-Sep-11 REV. 0.1 NOx EMISSIONS CO EMISSIONS UHC EMISSIONS 1 10142 HP 100.0% Load Elev. 5000 ft Rel. Humidity 60.0% Temperature 0 Deg. F PPMvd at 15% 02 15.00 25.00 25.00 ton/yr 19.41 19.70 11.28 Ibm/hr 4,43 4.50 2,58 gI(Hp-hr) 0.20 0.20 0.12 (gas turbine shaft pwr) 2 9485 HP 100.0% Load I Elev. 5000 ft f Rel. Humidity 60.0% I Temperature 20.0 Deg. F PPMvd at 15% 02 15.00 25,00 25.00 ton/yr 18.41 18.68 10.70 Ibm/hr 4.20 4.27 2.44 • g/(Hp-hr) 0.20 0.20 0.12 (gas turbine shaft pwr) { 3 J 8811 HP 100.0% Load Elev. 5000 ft Rel. Humidity 60.0% Temperature 40.0 Deg.F PPMvd at 15% 02 15.00 25.00 25.00 ton/yr 17.36 17.61 10.09 Ibm/hr 3.96 4.02 2,30 g/(Hp-hr) 0.20 0.21 0.12 (gas turbine shaft pwr) Notes 1. For short-term emission limits such as lbs/hr., Solar recommends using"worst case"anticipated operating conditions specific to the application and the site conditions. Worst case for one pollutant is not necessarily the same for another. 2. Solar's typical SoLoNOx warranty,for ppm values, is available for greater than 0 deg F, and between 50%and 100% load for gas fuel,and between 65% and 100% load for liquid fuel (except for the Centaur 40). An emission warranty for non-SoLoNOx equipment is available for greater than 0 deg F and between 80% and 100% load. 3. Fuel must meet Solar standard fuel specification ES 9-98. Emissions are based on the attached fuel composition, or, San Diego natural gas or equivalent. 4. If needed, Solar can provide Product Information Letters to address turbine operation outside typical warranty ranges, as well as non-warranted emissions of 502, PM10/2.5, VOC, and formaldehyde. 5. Solar can provide factory testing in San Diego to ensure the actual unit(s) meet the above values within the tolerances quoted. Pricing and schedule impact will be provided upon request. 6. Any emissions warranty is applicable only for steady-state conditions and does not apply during start-up, shut-down, malfunction, or transient event. S Solar Turbines PREDICTED EMISSION PERFORMANCE • A Caterpillar Company Customer Engine Model DCP-Midstream TAURUS 70.10302S Job ID CS/MD 59F MATCH Weld County Compression Inquiry Number Fuel Type Water Injection DN11-0028 SD NATURAL GAS NO Run 8y Date Run Engine Emiss'ons Data Michael E Clay 26-Sep-11 REV. 0.1 NOx EMISSIONS CO EMISSIONS UHC EMISSIONS 4 8060 HP 100.0% Load Elev. 5000 ft Rel. Humidity 60.0% I Temperature 60.0 Deg. F PPMvd at 15% O2 15,00 25.00 25.00 ton/yr 16.14 16.37 9.38 Ibm/hr 3.68 3.74 2.14 g/(Hp-h r) 0.21 0.21 0.12 (gas turbine shaft pwr) 5 17279 HP 100,0% Load Elev. 5000 ft 1 Rel.Humidity 60.0% Temperature 80.0 Deg. F PPMvd at 15% O2 15.00 25.00 25.00 ton/yr 14.88 15.09 8.64 Ibm/hr 3.40 3.45 1.97 • g/(Hp-hr) 0.21 0.21 0.12 (gas turbine shaft pwr) r 6 6512 HP 100,0%Load Elev. 5000 ft Rel. Humidity 60,0% Temperature 100.0 Deg. F PPMvd at 15% O2 15.00 25.00 25.00 ton/yr 13.70 13.90 7.96 Ibm/hr 3.13 3.17 1.82 g/(Hp-hr) 0.22 0.22 0.13 (gas turbine shaft pwr) Notes 1. For short-term emission limits such as lbs/hr.,Solar recommends using"worst case"anticipated operating conditions specific to the application and the site conditions. Worst case for one pollutant is not necessarily the same for another. 2. Solar's typical SoLoNOx warranty,for ppm values, is available for greater than 0 deg F,and between 50%and 100% load for gas fuel, and between 65%and 100% load for liquid fuel (except for the Centaur 40). An emission warranty for non-SoLoNOx equipment is available for greater than 0 deg F and between 80% and 100%load. 3. Fuel must meet Solar standard fuel specification ES 9-98. Emissions are based on the attached fuel composition, or, San Diego natural gas or equivalent. 4. If needed, Solar can provide Product Information Letters to address turbine operation outside typical warranty ranges,as well as non-warranted emissions of SO2,PM10/2.5,VOC, and formaldehyde. 5. Solar can provide factory testing in San Diego to ensure the actual unit(s) meet the above values within the tolerances quoted. Pricing and schedule impact will be provided upon request. 6. Any emissions warranty is applicable only for steady-state conditions and does not apply during start-up shut-down, malfunction,or transient event. S Solar Turbines PREDICTED ENGINE PERFORMANCE 0 A Caterpillar Company Customer Model TAURUS 70-10302S DCP-Midstream Package Type CS/MD Job ID Match Weld County Compression 59F MATCH Run By Dale Run Fuel System Michael E Clay 26-Sep-11 GAS Engine Performance Code Engine Performance Data Fuel Type REV. 3.53 REV. 0.6 SD NATURAL GAS DATA FOR MINIMUM PERFORMANCE Elevation feet 5000 Inlet Loss in H2O 4.0 Exhaust Loss In H2O 4.0 Accessory on GP Shaft HP 26.0 1 2 3 4 5 I 6 Engine Inlet Temperature deg F , 0 20.0 40.0 60.0 80.0 100.0 Relative Humidity °/0 60.0 60.0 60.0 60.0 60.0 60.0 Driven Equipment Speed RPM 11267 11193 11086 1 109501 r 10786 10575 • Specified Load HP FULL FULL FULL FULL FULL FULL Net Output Power HP 10142 9485 8811 8060 7279 6512 Fuel Flow mmBtu/hr 73.75 70,01 66.13 61.73 57.36 53.56 Heat Rate Btu/HP-hr 7272 7381 7506 7660 7879 8224 Therm Elf % 34.992 34.473 33.900 r 33.219 32.292 30.938, Engine Exhaust Flow Ibmlhr 205291 194310 183473 172525 160381 148996 PT Exit Temperature deg F 860 886 909 929 953 982 Exhaust Temperature deg F 860 886 909 929 953 982 Fuel Gas Composition Methane (CH4) 92.79 (Volume Percent) Ethane (C2H6) 4.16 Propane (C3H8) 0.84 N-Butane(C4H10) 0.18 N-Pentane (C5H12) 0.04 Hexane(C6H14) 0.04 Carbon Dioxide (CO2) 0.44 Hydrogen Sulfide(H2S) 0.0001 Nitrogen (N2) 1.51 Fuel Gas Properties [ LHV(Btu/Scf) 939.21 Specific Gravity 0.5970 Wobbe Index at 60F 1215.6 This performance was calculated with a basic inlet and exhaust system. Special equipment such as low noise silencers, special filters, heat recovery systems or cooling devices will affect engine performance. Performance shown is "Expected"performance at the pressure drops stated, not guaranteed. Natural Gas Dehydration Enterprise Compressor Station DCP Midstream, LP • Source ID D-2( -1 no longer in operation) Stripping Gas? N YIN Description Dehydration UM What is Stripping Gas? Manufacturer TBD Stripping Gas Flow Rate NIA sdm Model Tf3D Condenser? Y Y/N Serial 8 TBD Condenser Temperature 120 deg F Operation Dale TBD Condenses Pressure 12.5 pia Operation 8760 Iw/yr Flare? Y YIN Wel Gas 1 emperaturo 120 deg r Flare Ambient Air Temp deg F Wet Gas Pressure 1000 psig_ Flare Excess Oxygen % Wet Gas Water Content Saturated IbH2O/MMsc1 Rebate:Destruction Etlielency 95% Dry Gas Flow Rale 120 MMscfd Dry Gas Water Content 7.0 tbH2O/MMscf Lean Glycol Water Content 1.5 wt%H2O Lean Glycol Flow Rate 35 gpm Cold Separator? N Y/N Cold Separator Temperature N/A deg F Cad Separator Pressure N/A psig Glycol Pump Make&Model TBD Glycol Pump Type Electric Elec.or Gas Glycol Pump Gas Flow Rate N/A acfm/gpm Flash Tank? Y Y/N Flash Tank Temperature 160 deg F Flash Tank Pressure 30 psig Flash Tank Contror recycled wNRU Total Emissions from GRI-GLYCafc Uncontrolled Controlled CAS Emissions Emissions Pollutant Number (lolhr) (Iblyr) _,. (Ipy) (ib/hr) (iblyr) (toy) VOC 193.35 1603724.00 846 86 3.47 18310.20 1 9.16 n-hexane 110-54-3 3.81 33354.60 16.68 0.20 413 60 0.21 • Benzene 71-43-2 26.76 234391.80 117.20 0.63 4778.80 2.39 Toluene 108$&3 3171 277820.20 136.91 0.79 2798.20 1.40 Ethylbenzene 100.41.4 0.83 7282.00 3.83 0-03 27.40 0.01 k_late 1330-20-7 10.52 92144.80 48.07 0.40 283.20 0.14 Total HAP 73.63 644973.40 322.49 2.06 8301.20 4.15 Noloy The uncontrolled values include both flash and overhead MC vent streams. The flash stream is controlled with a VRU O 100%control. The still vent stream is sent to a condenser and then uncondensed overheads are combusted @ 95%control.accounted for wrlh the ncrdenser. S DCP Midstream,LP 10/21/2011 Natural Gas Dehydration • Flash Tank Off Gas Stream Detail from GRI-GLYCaIc Description Deity Flash Tank Vent Flash Tank Vern.Recycled Vent Flow Rale 0.0 sef/hr Hours of operation 8760 Irlyr Annual Flow Rate 0.000 MMscf/yr Pure Component Pule Component Component. Fraction Component Component Fraction Component Vol% P46 Fraction Mot Weight Mol Weight Mass Fraction Heat Value Heat Value (lb/lb-mo0 (lb/la-mot) (Btu/scf) I (Blu/ecf) Methane 0 000 C.0000 16.04 0.00 SDIV/0! 1010.0 0.0 Ethane 0.000 0.0000 30.07 0.00 NDtVI0I 1769.6 } 0.0 Propane 0.000 0.0000 44.10 0.00 NDIV/01 2516.1 0.0 -Butane 0.000 0.0000 58.12 0.00 NDLV/0' 32519 0.C n-Butane 0.000 0.0000 58.12 0.00 NDIVI0I 3262.3 0.0 i-Pentane 0.000 0.0000 72.15 0.00 ND!V/V.. 4000.9 0.0 n-Pentane 0.000 0.0000 72.15 0.00 SIDIV/0' 4008.9 0.0 Cydopentane 0.000 0.0000 70.13 0.00 trDIV/0t 3763.6 0.0 n-Hexane 0.000 0.0000 86.18 0.00 NDIV!0! 47559 0.0 Cyclohexane 0.000 0.0000 84.16 0.00 NDIV!0! 4481.5 0.0 Other Hexanes 0.003 0.0000 86.18 0.00 NDIV/0l 4755.9 0.0 Heptanes 0000 0.0000 1CO.20 0.00 N0IV/0! 5502.5 0.0 Methylcyclohexane 0.000 0.0000 98.19 0.00 NDIV/01 5215.7 0.0 2,2.4-Trimethylpeniane 0 000 0.0000 114.23 0.00 N01V/0! 6231.7 0 0 Benzene 0.000 0.0000 - 7811 0.00 , CDIV/01 3741.8 0.0 Toluene 0.000 0.0000 92.14 0.00 SIDIV/0! 4475.0 0.0 EILlyibenzene 0.000 - 0.0000 106.17 0.00 NDIV(0I 5222.2 0.0 Xytenes 0.000 0.0000 318.50 0.00 NDIV/0! 5208.8 0.0 Octanes• 0.000 0.0000 114.23 0.00 NDIV/01 6248 9 0 0 0.00 0.0000 .0.00 NDIV/0! 0 Condenser Vont Stream Detail from GRI-GLYCaIc • Description DeityCondenser Vent Vent Flow Rate 475 scf/hr Howe of operation 8760 Mlyr Annual Flow Rate 4.161 MMsCl/yr Pure Component Pure Component Component Fraction Component Component Fraction Component Vol% Mol Fraction Ma'Weight Mol Weight Mass Fraction Heal Value Heat Value (lb/lb-mol) (Ib/b-md) (84u/scl) (Btu/scf) Methane 6.86 0.0688 16.04 1.10 00243 1010.0 60.3 , Ethane 990 0.0995 30.07 2.98 0.0657 1769.6 175.2 Propane 11.10 0.1110 44.10 4.89 0.1080 2516.1 279.3 i•Butane ? 2.44 0.0244 58.12 1.42 0.0313 3251.9 79.3 n-Butane 8.37 0.0837 58.12 4.86 0.1073 3262.3 2731 i-Pentane 1.88 0.0188 72.15 1.36 0.0299 4000.9 75.2 n-Pentane 2.67 0.0267 72.15 1.93 0.0425 ( 40069 107.0 Cyclopentane 1.03 0.0103 70.13 0.72 0.0159 3763.9 38.8 n•Hexane 8.75 0.0875 88.18 7.54 0.1864 4755.9 416.1 Cyclohexane 1.48 0.0148 _ 84.16 1.25 0.0275 4481.5 66.3 Other Hexanes 1.24 0.0124 86.18 1.07 0.0236 4755.9 59.0 Heplanes 0.76 0.0075 100.20 0.76 0.0167 5502.5 41.7 Methylcyclohexane 000 0.0000 96.19 0.00 0.0000 5215.7 0.0 2,2.4-Trlmethl4peMane 0.000 0.0000 114.23 0.00 0.0000 6231.7 0.C Benzene 11 20 0.1120 78 51 8.75 0.1930 3741 8 419.1 Toluene - 5.54 0.0554 92.14 5.10 0.1126 4475.0 247.9 Elhytbenzene 0.047 0.0005 106.17 0.05 0 0011 5222.2 2.5 Xyenes 0.49 0.0049 318.50 1.55 0.0341 5208.8 26.3 Octanes. 0.003 0.0000 114.23 0.00 0.0001 6248.9 0.2 73.75 0.7375 45.33 1.00 2375 • DCP Midstream.LP 10/21/2011 Dehydrator Flare Emissions Enterprise Compressor Station DCP Midstream, LP Supplimental Fuel for Flare 2039 MMBTU/nr Days/mo MMBTU1mo Jan 0.355 31 264.3 Feb 0.250 28 168.0 Mar 0.344 31 256.1 Apr 0.261 30 188.0 May 0.125 31 92.9 Jun 0.117 30 84.5 Jul 0.146 31 108.7 Aug 0.146 31 108.9 Sep 0.140 30 100.8 Oct 0.172 31 128.0 Nov 0.159 30 114.4 Dec 0.139 31 103.5 1718.0 MMBTU/yr from assist gas/pilot(2009 throughput higest of last three years) 2000.0 MMBTU/yr Round up to be conservative. 9,883 MMBTU/yr from dehy condenser overhead stream from Oct 19,2011 GlyCalc 11883.5 MMBTU/yr EF Emissions 1111 lb/mmblu ton/yr NOx 0.068 0.40 CO 0.37 2.23 AP-42 Table 13.5-1 • • Page: 1 • GRI-GLYCalc VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name: Enterprise 120 MMSCFD File Name: H:\DCP\Enterprise\Enterprise 120 Modification and Engine Addition Sept 2011\120 MMSCFD Glycalc.ddf Date: September 14, 2011 DESCRIPTION; Description: Enterprise 120 MMSCFD 35 gpm Glycol Recirc Rate Annual Hours of Operation: 8760.0 hours/yr EMISSIONS REPORTS: CONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.0689 1.654 0.3018 Ethane 0.1864 4.473 0.8164 Propane 0.3057 7.337 1.3391 Isobutane 0.0889 2.133 0.3893 n-Butane 0.3046 7.311 1.3343 Isopentane 0.0851 2.042 0.3727 • n-Pentane 0.1205 2.892 0.5278 Cyclopentane 0.0450 1.081 0.1972 n-Hexane 0.0472 1.133 0.2068 Cyclohexane 0.0778 1.866 0.3406 Other Hexanes 0.0671 1.610 0.2938 Heptanes 0.0475 1.140 0.2080 Benzene 0.5455 13 .092 2.3894 Toluene 0.3194 7.667 1.3991 Ethylbenzene 0.0031 0.075 0.0137 Xylenes 0.0323 0.776 0.1416 C8+ Heavies 0.0004 0.009 0.0016 Total Emissions 2.3455 56.292 10.2733 Total Hydrocarbon Emissions 2.3455 56.292 10.2733 Total VOC Emissions 2.0902 50.165 9.1551 Total HAP Emissions 0.9476 22.743 4.1506 Total BTEX Emissions 0.9004 21.610 3.9438 UNCONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 1.3800 33 .119 6.0443 Ethane 3.7530 90.073 16.4383 Propane 6.3120 151 .487 27.6465 Isobutane 1.8929 45.430 8.2911 n-Butane 6.6663 159.991 29.1984 Isopentane 2.1265 51.035 9.3139 • n-Pentane 3 .1181 74.835 13.6574 Cyclopentane 1.2681 30.436 5.5545 n-Hexane 1.5873 38.095 6.9523 • P13 . 2 Cyclohexane 3.1338 75.211 13 .7261 Other Hexanes 1.9881 47.714 8.7078 Heptanes 2.8243 67.782 12.3703 Benzene 25.2901 606.962 110.7706 Toluene 30.4904 731.770 133.5480 Ethylbenzene 0.8090 19.415 3 .5433 Xylenes 10.3376 248.103 45.2789 C8+ Heavies 5.5805 133.933 24.4428 Total Emissions 108.5581 2605.394 475.4843 Total Hydrocarbon Emissions 108.5581 2605.394 475.4843 Total VOC Emissions 103.4250 2482.201 453.0017 Total HAP Emissions 68.5144 1644 .345 300.0930 Total BTEX Emissions 66.9271 1606.251 293.1407 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 50.4403 1210.568 220.9287 • Ethane 43.2880 1038.912 189.6014 Propane 34.8826 837.182 152.7857 Isobutane 7.4308 178.340 32.5471 n-Butane 20.6099 494.636 90.2712 Isopentane 6.0630 145.511 26.5558 n-Pentane 7.3251 175.801 32.0837 Cyclopentane 0.7704 18.490 3.3745 n-Hexane 2.2203 53.288 9.7250 Cyclohexane 1.1347 27.233 4.9699 Other Hexanes 3.5992 86.381 15.7645 Heptanes 2.0841 50.018 9.1282 Benzene 1.4670 35.207 6.4253 Toluene 1.2242 29.381 5.3621 Ethylbenzene 0.0200 0.481 0.0877 Xylenes 0.1812 4.348 0.7935 C8+ Heavies 0.9100 21 .841 3.9860 Total Emissions 183.6508 4407.618 804.3903 Total Hydrocarbon Emissions 183.6508 4407.618 804.3903 Total VOC Emissions 89.9224 2158.138 393.8603 Total HAP Emissions 5.1127 122.705 22.3937 Total BTEX Emissions 2.8924 69.418 12.6687 COMBINED REGENERATOR VENT/FLASH GAS EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.0689 1.654 0.3018 • Ethane 0.1864 4.473 0.8164 Propane 0.3057 7.337 1.3391 Isobutane 0.0889 2.133 0.3893 Page: 3 • n-Butane 0.3046 7.311 1.3343 Isopentane 0.0851 2.042 0.3727 n-Pentane 0.1205 2.892 0.5278 Cyclopentane 0.0450 1.081 0.1972 n-Hexane 0.0472 1.133 0.2068 Cyclohexane 0.0778 1.866 0.3406 Other Hexanes 0.0671 1.610 0.2938 Heptanes 0.0475 1.140 0.2080 Benzene 0.5455 13.092 2.3894 Toluene 0.3194 7.667 1.3991 Ethylbenzene 0.0031 0.075 0.0137 Xylenes 0.0323 0.776 0.1416 C8+ Heavies 0.0004 0.009 0.0016 Total Emissions 2.3455 56.292 10.2733 Total Hydrocarbon Emissions 2.3455 56.292 10.2733 Total VOC Emissions 2.0902 50.165 9.1551 Total HAP Emissions 0.9476 22.743 4.1506 Total BTEX Emissions 0.9004 21.610 3.9438 COMBINED REGENERATOR VENT/FLASH GAS EMISSION CONTROL REPORT: Component Uncontrolled Controlled % Reduction tons/yr tons/yr • Methane 226.9730 0.3018 99.87 Ethane 206.0397 0.8164 99.60 Propane 180.4322 1.3391 99.26 Isobutane 40.8381 0.3893 99.05 n-Butane 119.4696 1.3343 98.88 Isopentane 35.8696 0.3727 98.96 n-Pentane 45.7412 0.5278 98.85 Cyclopentane 8.9290 0.1972 97.79 n-Hexane 16.6773 0.2068 98.76 Cyclohexane 18.6960 0.3406 98.18 Other Hexanes 24.4723 0.2938 98.80 Heptanes 21.4985 0.2080 99.03 Benzene 117.1960 2.3894 97.96 Toluene 138.9101 1.3991 98.99 Ethylbenzene 3.6310 0.0137 99.62 Xylenes 46.0724 0.1416 99.69 C8+ Heavies 28.4288 0.0016 99.99 Total Emissions 1279.8747 10.2733 99.20 Total Hydrocarbon Emissions 1279.8747 10.2733 99.20 Total VOC Emissions 846.8620 9.1551 98.92 Total HAP Emissions 322.4867 4 .1506 98.71 Total BTEX Emissions 305.8094 3.9438 98.71 EQUIPMENT REPORTS: • CONDENSER AND COMBUSTION DEVICE • Page: 4 Condenser Outlet Temperature: 120.00 deg. F Condenser Pressure: 12.50 psia Condenser Duty: 1.90e-001 MM BTU/hr Hydrocarbon Recovery: 4.94 bbls/day Produced Water: 32.77 bbls/day Ambient Temperature: 0.00 deg. F Excess Oxygen: 0.00 % Combustion Efficiency: 95.00 % Supplemental Fuel Requirement: 1.90e-001 MM ETU/hr Component Emitted Destroyed Methane 4.99% 95.01% Ethane 4.97% 95.03% Propane 4.84% 95.16% Isobutane 4 ,70% 95.30% n-Butane 4 .57% 95.43% Isopentane 4.00% 96.00% n-Pentane 3.86% 96.14% Cyclopentane 3.55% 96.45% n-Hexane 2.97% 97.03% Cyclohexane 2 .48% 97.52% Other Hexanes 3.37% 96.63% Heptanes 1.68% 98.32% Benzene 2.16% 97.84% Toluene 1.05% 98.95% Ethylbenzene 0.39% 99.61% Xylenes 0.31% 99.69% . C8+ Heavies 0.01% 99.99% 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: 6.28 lbs. H2O/MMSCF Temperature: 120.0 deg. F Pressure: 1000.0 psig Dry Gas Flow Rate: 120.0000 MMSCF/day Glycol Losses with Dry Gas: 7.5902 lb/hr Wet Gas Water Content: Saturated Calculated Wet Gas Water Content: 102.41 lbs. H2O/MMSCF Calculated Lean Glycol Recirc. Ratio: 4.37 gal/lb H2O Remaining Absorbed Component in Dry Gas in Glycol Water 6.12% 93.88% Carbon Dioxide 99.64% 0.36% Nitrogen 99.96% 0.04% Methane 99.97% 0.03% Ethane 99.91% 0.09% Propane 99.88% 0.12% Isobutane 99.85% 0.15% • n-Butane 99.81% 0.19% Isopentane 99.83% 0.17% n-Pentane 99.79% 0.21% Page: 5 • Cyclopentane 99.08% 0.92% n-Hexane 99.70% 0.30% Cyclohexane 98.65% 1.35% Other Hexanes 99.76% 0.24% Heptanes 99.52% 0.48% Benzene 89.65% 10.35% Toluene 87.20% 12.80% Ethylbenzene 85.19% 14.81% Xylenes 80.22% 19.78% C8+ Heavies 98.73% 1.27% FLASH TANK Flash Control: Recycle/recompression Flash Temperature: 160.0 deg. F Flash Pressure: 30.0 psig Left in Removed in Component Glycol Flash Gas Water 99.83% 0.17% Carbon Dioxide 20.69% 79.31% Nitrogen 2.58% 97.42% Methane 2.66% 97.34% Ethane 7.98% 92.02% Propane 15.32% 84 .68% Isobutane 20.30% 79.70% n-Butane 24.44% 75.56% • Isopentane 26.34% 73.66% n-Pentane 30.21% 69.79% Cyclopentane 62.40% 37.60% n-Hexane 41.98% 58.02% Cyclohexane 74.27% 25.73% Other Hexanes 36.23% 63.77% Heptanes 57.75% 42.25% Benzene 94.79% 5.21% Toluene 96.44% 3 .56% Ethylbenzene 97.84% 2.16% Xylenes 98.50% 1.50% C8+ Heavies 87.67% 12.33% REGENERATOR No Stripping Gas used in regenerator. Remaining Distilled Component in Glycol Overhead Water 38.07% 61.93% Carbon Dioxide 0.00% 100.00% Nitrogen 0.00% 100.00% Methane 0.00% 100.00% Ethane 0.00% 100.00% Propane 0.00% 100.00% Isobutane 0.00% 100.00% III n-Butane 0.00% 100.00% Isopentane 1.90% 98.10% n-Pentane 1.66% 98.34% Page: 6 • Cyclopentane 0.80% 99.20% n-Hexane 1.19% 98.81% Cyclohexane 4 .31% 95.69% Other Hexanes 2.76% 97.24% Heptanes 0.87% 99.13% Benzene 5.28% 94.72% Toluene 8.19% 91.81% Ethylbenzene 10.64% 89.36% Xylenes 13.13% 86.87% C8+ Heavies 13.72% 86.28% STREAM REPORTS: WET GAS STREAM Temperature: 120.00 deg. F Pressure: 1014 .70 psia Flow Rate: 5.01e+006 scfh Component Conc. Loading (vol%) (lb/hr) Water 2.16e-001 5.13e+002 Carbon Dioxide 2.65e+000 1.54e+004 Nitrogen 3.19e-001 1.18e+003 Methane 7.34e+001 1.56e+005 • Ethane 1.34e+001 5.33e+004 Propane 5.75e+000 3.35e+004 Isobutane 8.10e-001 6.22e+003 n-Butane 1.87e+000 1.44e+004 Isopentane 4.99e-001 4.76e+003 n-Pentane 5.13e-001 4.89e+003 Cyclopentane 2.39e-002 2.22e+002 n-Hexane 1.12e-001 1.28e+003 Cyclohexane 2.85e-002 3.17e+002 Other Hexanes 2.06e-001 2.35e+003 Heptanes 7.80e-002 1.03e+003 Benzene 2.50e-002 2.58e+002 Toluene 2.04e-002 2.48e+002 Ethylbenzene 3.99e-004 5.60e+000 Xylenes 3.79e-003 5.32e+001 C8+ Heavies 2.26e-002 5. 10e+002 Total Components 100.00 2.96e+005 DRY GAS STREAM Temperature: 120.00 deg. F Pressure: 1014.70 psia Flow Rate: 5.00e+006 scfh Component Conc. Loading (vol%) (lb/hr) • Water 1.32e-002 3.14e+001 Carbon Dioxide 2.65e+000 1.54e+004 Nitrogen 3.20e-001 1.18e+003 Page: 7 • Methane 7.36e+001 1.56e+005 Ethane 1.34e+001 5.32e+004 Propane 5.76e+000 3.35e+004 Isobutane 8.ile-001 6.21e+003 n-Butane 1.87e+000 1.43e+004 Isopentane 5.OOe-001 4.75e+003 n-Pentane 5.13e-001 4.88e+003 Cyclopentane 2.38e-002 2.20e+002 n-Hexane 1.12e-001 1.27e+003 Cyclohexane 2.82e-002 3.13e+002 Other Hexanes 2.06e-001 2.34e+003 Heptanes 7.79e-002 1.03e+003 Benzene 2.25e-002 2.32e+002 Toluene 1.78e-002 2.16e+002 Ethylbenzene 3.41e-004 4.77e+000 Xylenes 3.05e-003 4.27e+001 C8+ Heavies 2.24e-002 5.03e+002 Total Components 100.00 2.95e+005 LEAN GLYCOL STREAM Temperature: 120.00 deg. F Flow Rate: 3.50e+001 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9.85e+001 1.94e+004 • Water 1.50e+000 2.95e+002 Carbon Dioxide 2.81e-011 5.52e-009 Nitrogen 2.33e-013 4 .59e-011 Methane 8.84e-018 1.74e-015 Ethane 1.13e-007 2.22e-005 Propane 8.51e-009 1.68e-006 Isobutane 1.42e-009 2,80e-007 n-Butane 3.43e-009 6.76e-007 Isopentane 2.09e-004 4 .11e-002 n-Pentane 2.66e-004 5.25e-002 Cyclopentane 5.20e-005 1.02e-002 n-Hexane 9.71e-005 1.91e-002 Cyclohexane 7.16e-004 1.41e-001 Other Hexanes 2.87e-004 5.64e-002 Heptanes 1.25e-004 2.47e-002 Benzene 7.15e-003 1.41e+000 Toluene 1.38e-002 2.72e+000 Ethylbenzene 4 .89e-004 9.63e-002 Xylenes 7.93e-003 1.56e+000 08+ Heavies 4.51e-003 8.88e-001 Total Components 100.00 1.97e+004 RICH GLYCOL STREAM Temperature: 120.00 deg. F Pressure: 1014 .70 psia Flow Rate: 3.67e+001 gpm NOTE: Stream has more than one phase. Page: 8 • Component Cone. Loading (wt%) (lb/hr) TEG 9.45e+001 1.94e+004 Water 3.79e+000 7.78e+002 Carbon Dioxide 2.69e-001 5.53e+001 Nitrogen 2.24e-003 4 .60e-001 Methane 2.53e-001 5.18e+001 Ethane 2.29e-001 4.70e+001 Propane 2.01e-001 4.12e+001 Isobutane 4.55e-002 9.32e+000 n-Butane 1.33e-001 2.73e+001 Isopentane 4 .O1e-002 8.23e+000 n-Pentane 5.12e-002 1. 05e+001 Cyclopentane 9.99e-003 2.05e+000 n-Hexane 1.87e-002 3.83e+000 Cyclohexane 2.15e-002 4 .41e+000 Other Hexanes 2.75e-002 5.64e+000 Heptanes 2.40e-002 4.93e+000 Benzene 1.37e-001 2.82e+001 Toluene 1.68e-001 3.44e+001 Ethylbenzene 4.51e-003 9.25e-001 Xylenes 5.89e-002 1.21e+001 C8+ Heavies 3.60e-002 7.38e+000 Total Components 100.00 2.050+004 FLASH TANK OFF GAS STREAM • Temperature: 160.00 deg. F Pressure: 44.70 psia Flow Rate: 2.76e+003 scfh Component Conc. Loading (volt) (lb/hr) Water 1.03e+000 1.35e+000 Carbon Dioxide 1.37e+001 4.38e+001 Nitrogen 2.20e-001 4.48e-001 Methane 4.32e+001 5.04e+001 Ethane 1.98e+001 4.33e+001 Propane 1.09e+001 3.49e+001 Isobutane 1.76e+000 7.43e+000 n-Butane 4.87e+000 2.06e+001 Isopentane 1.15e+000 6. 06e+000 n-Pentane 1.39e+000 7.33e+000 Cyclopentane 1.51e-001 7.70e-001 n-Hexane 3.54e-001 2.22e+000 Cyclohexane 1.85e-001 1.13e+000 Other Hexanes 5.74e-001 3.60e+000 Heptanes 2.66e-001 2.08e+000 Benzene 2 .58e-001 1.47e+000 Toluene 1.82e-001 1.22e+000 Ethylbenzene 2.59e-003 2.OOe-002 Xylenes 2.34e-002 1.B1e-001 CB+ Heavies 7.34e-002 9.10e-001 Total Components 100.00 2.29e+002 • Page: 9 FLASH TANK GLYCOL STREAM Temperature: 160.00 deg. F Flow Rate: 3.62e+001 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9.55e+001 1.94e+004 • Water 3 .83e+000 7.76e+002 Carbon Dioxide 5.64e-002 1.14e+001 Nitrogen 5.84e-005 1.19e-002 Methane 6.80e-003 1.38e+000 Ethane 1 .85e-002 3.75e+000 Propane 3.11e-002 6.31e+000 Isobutane 9.33e-003 1.89e+000 n-Butane 3.29e-002 6.67e+000 Isopentane 1.07e-002 2 .17e+000 n-Pentane 1.56e-002 3.17e+000 Cyclopentane 6.30e-003 1.28e+000 n-Hexane 7.92e-003 1.61e+000 Cyclohexane 1.61e-002 3.27e+000 Other Hexanes 1.O1e-002 2.04e+000 Heptanes 1.40e-002 2.85e+000 Benzene 1.32e-001 2.67e+001 Toluene 1.64e-001 3.32e+001 Ethylbenzene 4.46e-003 9.05e-001 Xylenes 5.87e-002 1.19e+001 C8+ Heavies 3.19e-002 6.47e+000 . Total Components 100.00 2.03e+004 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 Pressure: 14.70 psia Flow Rate: 1.08e+004 scfh Component Conc. Loading (vol%) (lb/hr) Water 9.38e+001 4.81e+002 Carbon Dioxide 9.13e-001 1.14e+001 Nitrogen 1.49e-003 1.19e-002 Methane 3.02e-001 1.38e+000 Ethane 4.39e-001 3.75e+000 Propane 5.03e-001 6.31e+000 Isobutane 1.15e-001 1.89e+000 n-Butane 4 .03e-001 6.67e+000 Isopentane 1.04e-001 2.13e+000 n-Pentane 1.52e-001 3.12e+000 Cyclopentane 6.36e-002 1.27e+000 Page: 10 • n-Hexane 6.48e-002 1,59e+000 Cyclohexane 1 .31e-001 3.13e+000 Other Hexanes 8.11e-002 1.99e+000 Heptanes 9.91e-002 2 ,82e+000 Benzene 1.14e+000 2.53e+001 Toluene 1.16e+000 3.05e+001 Ethylbenzene 2.68e-002 8.09e-001 Xylenes 3 .42e-001 1.03e+001 C8+ Heavies 1.15e-001 5.58e+000 Total Components 100.00 6.01e+002 CONDENSER PRODUCED WATER STREAM Temperature: 120.00 deg. F Flow Rate: 9.56e-001 gpm Component Conc. Loading (wt%) (lb/hr) (ppm) Water 9.99e+001 4 .78e+002 998856. Carbon Dioxide 1.53e-002 7.34e-002 153. Nitrogen 4.19e-007 2,00e-006 0. Methane 9.40e-005 4.50e-004 1. Ethane 2.90e-004 1.39e-003 3. Propane 4 .91e-004 2.35e-003 5. Isobutane 7 .78e-005 3.72e-004 1. n-Butane 3 .54e-004 1 .69e-003 4. Isopentane 6.97e-005 3 .33e-004 1. n-Pentane 1.06e-004 5.06e-004 1. • Cyclopentane 2.78e-004 1.33e-003 3. n-Hexane 3 .44e-005 1.65e-004 0. Cyclohexane 3.20e-004 1.53e-003 3. Other Hexanes 3.94e-005 1.88e-004 0. Heptanes 1. 92e-005 9.18e-005 0. Benzene 6.31e-002 3.02e-001 631. Toluene 3.04e-002 1.45e-001 304. Ethylbenzene 2 .24e-004 1.07e-003 2. Xylenes 3.22e-003 1.54e-002 32. C8+ Heavies 9.54e-008 4 .56e-007 0. Total Components 100.00 4.78e+002 1000000. CONDENSER RECOVERED OIL STREAM Temperature: 120.00 deg. F Flow Rate: 1.44e-001 gpm Component Conc. Loading (wt%) (lb/hr) Water 5.75e-002 3.52e-002 Carbon Dioxide 7.08e-002 4.34e-002 Nitrogen 4.78e-005 2.93e-005 Methane 2.35e-003 1.44e-003 Ethane 3.88e-002 2.38e-002 Propane 3.18e-001 1 .95e-001 Isobutane 1.87e-001 1.15e-ool n-Butane 9.34e-001 5.72e-001 • Isopentane 6.93e-001 4 .24e-001 n-Pentane 1.16e+000 7 .08e-001 Page: 11 • Cyclopentane 5.98e-001 3.66e-001 n-Hexane 1.05e+000 6.43e-001 Cyclohexane 2.57e+000 1.58e+000 Other Hexanes 1.05e+000 6.46e-001 Heptanes 3.06e+000 1.87e+000 Benzene 2.30e+001 1.41e+001 Toluene 3 .91e+001 2.40e+001 Ethylbenzene 1.22e+000 7.45e-001 Xylenes 1.58e+001 9.68e+000 C8+ Heavies 9.10e+000 5.57e+000 Total Components 100.00 6.13e+001 CONDENSER VENT STREAM Temperature: 120.00 deg. F Pressure: 12.50 psia Flow Rate: 4.75e+002 scfh Component Conc. Loading (vol%) (lb/hr) Water 1.36e+001 3.07e+000 Carbon Dioxide 2.05e+001 1.13e+001 Nitrogen 3.37e-002 1.18e-002 Methane 6.86e+000 1.38e+000 Ethane 9.90e+000 3.73e+000 Propane 1.11e+001 6.11e+000 Isobutane 2.44e+000 1.78E+000 • n-Butane 8.37e+000 6.09e+000 Isopentane 1.88e+000 1 .70e+000 n-Pentane 2.67e+000 2.41e+000 Cyclopentane 1.03e+000 9.01e-001 n-Hexane 8.75e-001 9.44e-001 Cyclohexane 1.48e+000 1.56e+000 Other Hexanes 1.24e+000 1.34e+000 Heptanes 7.57e-001 9.50e-001 Benzene 1.12e+001 1.09e+001 Toluene 5.54e+000 6.39e+000 Ethylbenzene 4.70e-002 6.25e-002 Xylenes 4.86e-001 6.47e-001 C8+ Heavies 3 .49e-003 7.45e-003 Total Components 100.00 6.13e+001 COMBUSTION DEVICE OFF GAS STREAM Temperature: 1000.00 deg. F Pressure: 14.70 psia Flow Rate: 1.56e+001 scfh Component Conc. Loading (vol%) (lb/hr) Methane 1.04e+001 6.89e-002 Ethane 1.50e+DO1 1.86e-001 Propane 1.68e+001 3.06e-001 Isobutane 3.71e+000 8.89e-002 n-Butane 1.27e+001 3.05e-D01 • Isopentane 2.86e+000 8.51e-002 Page: 12 • n-Pentane 4 .05e+000 1.21e-001 Cyclopentane 1.56e+000 4 .50e-002 n-Hexane 1.33e+000 4.72e-002 Cyclohexane 2.24e+000 7.78e-002 Other Hexanes 1.89e+000 6.71e-002 Heptanes 1.15e+000 4.75e-002 Benzene 1.70e+001 5.46e-001 Toluene 8.41e+000 3 .19e-001 Ethylbenzene 7.14e-002 3.13e-003 xylenes 7.39e-001 3.23e-002 C8+ Heavies 5.31e-003 3.73e-004 Total Components 100.00 2.35e+000 • • • Page: 1 GRI-GLYCalc VERSION 4.0 - SUMMARY OF INPUT VALUES Case Name: Enterprise 120 MMSCFD File Name: H:\DCP\Enterprise\Enterprise 120 Modification and Engine Addition Sept 2011\120 MMSCFD Glycalc.ddf Date: September 14, 2011 DESCRIPTION: Description: Enterprise 120 MMSCFD 35 gpm Glycol Recirc Rate Annual Hours of Operation: 8760.0 hours/yr WET GAS: Temperature: 120.00 deg. F Pressure: 1000.00 psig Wet Gas Water Content: Saturated Component Conc. (vol %) Carbon Dioxide 2.6600 Nitrogen 0.3200 Methane 73.6091 Ethane 13.4435 Propane 5.7633 Isobutane 0.8119 n-Butane 1.8738 ID Isopentane 0.5005 n-Pentane 0.5144 Cyclopentane 0.0240 n-Hexane 0.1123 Cyclohexane 0.0286 Other Hexanes 0.2068 Heptanes 0.0782 Benzene 0.0251 Toluene 0.0204 Ethylbenzene 0.0004 Xylenes 0.0038 C8+ Heavies 0.0227 DRY GAS: Flow Rate: 120.0 MMSCF/day Water Content: 7.0 lbs. H2O/MMSCF LEAN GLYCOL: Glycol Type: TEG Water Content: 1.5 wt% H2O Flow Rate: 35.0 gpm • PUMP: Page: 2 • Glycol Pump Type: Electric/Pneumatic FLASH TANK: Flash Control: Recycle/recompression Temperature: 160.0 deg. F Pressure: 30.0 psig REGENERATOR OVERHEADS CONTROL DEVICE: Control Device: Condenser Temperature: 120.0 deg. F Pressure: 12.5 psia Control Device: Combustion Device Destruction Efficiency: 95.0 % Excess Oxygen: 0.0 % Ambient Air Temperature: 0.0 deg. 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U.:vAc.3 - c,S u s-S ,, v' j'\-PCE API(✓. -_ — 7.1-54 5n EMISSION FACTORS 11/06 • Extended Liquid Analysis • DCP Midstream, LP Enterprise Compressor Station Carbon Dioxide 0.0667 0.0321 Nitrogen 0.0284 0.0087 Methane 0.2743 0.0481 Ethane 0.8199 0.2693 Propane 3.0885 1.4877 i-Butane 1.5839 1.0055 n-Butane 5.5719 3.5372 i-Pentane 4.1245 3.2503 HAPS Summary Wt% n-Pentane 5.5219 4.3516 Cyclopentane 0.5479 0.4197 n-hexane 9.76 n-Hexane 10.3687 9.7595 Benzene 1.35 Cyclohexane 3.0484 2.8022 Toluene 4.50 Other Hexanes 15.0673 14.114 Ethylbenzene 0.34 Other Heptanes 15.793 17.2287 Xylene 3.23 Mehylcyclohexane 5.1024 5.4723 Total HAP 19.19 224 trimethylpentane 0.5059 0.5426 Benzene 1.5855 1.3527 Toluene 4.472 4.5007 Ethylbenzene 0.2952 0.3423 Xylenes 2.7873 3.2323 Other Octanes 10.6105 13.2502 Nonanes 4.9634 6.8883 Decanes + 3.7725 6.104 100 100 I • MPACT ANALYTICAL SYSTEMS INC. 365 S. MAIN ST. BRIGHTON, CO 80601 303-637.0150 EXTENDED NATURAL GAS LIOUID ANALYSIS(*DHA1 MAIN PAGE PROJECT NO. : 201105150 ANALYSIS NO.: 01 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: JUNE 3,2011 ACCOUNT NO. : SAMPLE DATE : MAY 26,2011 PRODUCER : CYLINDER NO.: 2821 LEASE NO. : SAMPLED BY : J.MOSER NAME/DESCRIP: ENTERPRISE COMPRESSOR EMPACT 3 PHASE SEPARATOR Q12:00 ** FIELD DATA*" SAMPLE TEMP.: 106 SAMPLE PRES.: 30 AMBIENT TEMP.: VAPOR PRES. : GRAVITY COMMENTS : SPOT;NO PROBE COMPONENT MOLE% MASS% VOL% • NITROGEN(AIR) 0.0284 0.0087 0.0076 CARBON DIOXIDE 0.0667 0.0321 0.0276 METHANE 0.2743 0.0481 0.1130 ETHANE 0.8199 0.2693 0.5324 PROPANE 3.0885 1.4877 2.0666 1-BUTANE 1.5839 1.0055 1.2581 N-BUTANE 5.5719 3.5372 4.2657 1-PENTANE 4.1245 3.2503 3.6658 N-PENTANE 5.5219 4.3516 4.8559 HEXANES PLUS 78.9200 86.0095 83.2073 TOTALS 100.0000 100.0000 100.0000 BTEX COMPONENTS MOLE% MASS% (CALC: GPA STD 2)45-94&TP-17 QI4.696&60 F) BENZENE 1.5855 1.3527 TOTAL C6+ TOLUENE 4.4720 4.5007 SAMPLE FRACTION ETHYLBENZENE 0.2952 0.3423 Specific Gravity(H2O=1) = 0.7043 0.7274 60/60 XYLENE 2.7873 3.2323 API Gravity = 69.41 63.03 60/60 TOTAL BTEX 9.1400 9.4280 Molecular Weight 91.55 99.984 Absolute Density = 5.87 6.07 LBS/GAL Heating Value Liq.MI Gas= 119555 123799 BTU/GAL Vapor/Liquid = 24.20 23.07 CUFT/GAL Vapor Pressure 34.02 2,76 PSIA @100 F •(DETAILED HYDROCARBON ANALYSIS/NJ 1993):ASTM D6730 nos DATA HAS BEEN ACQUIRED THROUGH APPLICATION OFCURRENT STATE•OF-711E-ART ANALYTICAL TECHNIQUES. THE USE OF THIS INFORMATION LS THE RESPONSIBLITY OF THE USER. EMPACT ANALYTICAL SYSTEMS.ASSUMES NO RESPONSIBLI YFORACCURACYOPTHEREPORTEDINFORMATIONNORANYCONSEQUENCESOFITSAPPLJCATION I • MPACT ANALYTICAL SYSTEMS INC. _ 365 S. MAIN ST. BRIGHTON, CO 80601 L L__. T I 303-637-0150 EXTENDED NATURAL GAS LIQUID ANALYSIS(`DHA) E&P TANK/GLYCALC INFORMATION PROJECT NO. : 201105150 ANALYSIS NO.: 01 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: JUNE 3,2011 ACCOUNT NO. : SAMPLE DATE : MAY 26,2011 PRODUCER : CYLINDER NO.: 2821 LEASE NO. : SAMPLED BY : J.MOSER NAME/DESCRIP: ENTERPRISE COMPRESSOR EMPACT 3 PHASE SEPARATOR @12:00 ""FIELD DATA"" SAMPLE TEMP.: 106 SAMPLE PRES.: 30 AMBIENT TEMP.: VAPOR PRES. : GRAVITY COMMENTS : SPOT;NO PROBE COMPONENT Mole% Wt% LV% CARBON DIOXIDE 0.0667 0.0321 0.0276 • NITROGEN(AIR) 0.0284 0.0087 0,0076 METHANE 0.2743 0.0481 0.1130 ETHANE 0.8199 0.2693 0.5324 PROPANE 3.0885 1.4877 2.0666 I-BUTANE 1.5839 1.0055 1.2581 N-BUTANE 5.5719 3.5372 4.2657 I-PENTANE 4.1245 3.2503 3.6658 N-PENTANE 5.5219 4.3516 4.8559 CYCLOPENTANE(N-05) 0.5479 0.4197 0.3888 N-HEXANE 10.3687 9.7595 10.3548 CYCLOHEXANE(OTHER C6) 3.0484 2.8022 2.5190 OTHER HEXANES 15.0673 14.1140 14.6408 OTHER HEPTANES 15.7930 17.2287 17.3737 METHYLCYCLOHEXANE(OTHER C7) 5.1024 5.4723 4.9748 2,2,4 TRIMETHYLPENTANE 0.5059 0.5426 0.5072 BENZENE 1.5855 1.3527 1.0790 TOLUENE 4.4720 4.5007 3.6256 ETHYLBENZENE 0.2952 0.3423 0.2757 XYLENES 2.7873 3.2323 2.6141 OTHER OCTANES 10.6105 13.2502 12.8308 OCTANES PLUS --- 22.9348 ---- 30.3597 --- 28.2508 NONANES 4.9634 6.8883 6.4556 DECANES PLUS 3.7725 6.1040 5.5674 TOTAL 100.0000 100.0000 100.0000 API Gravity = 69A1 60/60 Vapor Pressure = 34.02 PSIA&100 F Average Molecular Weight of Decanes plus = 148.14 Average Specific Gravity of Decanes plus = 0.7740 THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT • STATE-OF-THE ART ANALYTICAL TECHNIQUES, THE APPLICATIONS OF THIS INFORMATION IS THE RESPONSIBILITY OF THE USER EMPACT ANALYTICAL SYSTEMS,INC.ASSUMES NO RESPONSIBILITY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF IT'S APPLICATION. 0 tMPTANAIcAL SYSTEMS INC. 365 S. MAIN ST. BRIGHTON, CO 8O601 303-637-0150 EXTENDED NATURAL GAS LIQUID ANALYSIS CDHA) DHA COMPONENT LIST PROJECT NO. : 201105150 ANALYSIS NO.: 01 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: JUNE 3,2011 ACCOUNT NO. : SAMPLE DATE : MAY 28,2011 PRODUCER : CYLINDER NO.: 2821 LEASE NO. : SAMPLED BY : J.MOSER NAME/DESCRIP: ENTERPRISE COMPRESSOR EMPACT 3 PHASE SEPARATOR @12:00 "FIELD DATA"' SAMPLE TEMP.: 106 SAMPLE PRES. : 30 AMBIENT TEMP.: VAPOR PRES. : GRAVITY . COMMENTS : SPOT;NO PROBE COMPONENT PIANO# MOLE% MASS% VOL% el Nitrogen 0.0284 0.0087 0.0076 Carbon Dioxide 0.0667 0.0321 0.0276 Methane P1 0.2743 0.0481 0.1130 Ethane P2 0.8199 0.2693 0.5324 Propane P3 3.0885 1.4877 2.0666 i-Butane 14 1.5839 1.0055 1.2581 n-Butane P4 5.5719 3.5372 42657 2,2-Dlmethylpropane 15 0.0300 0.0236 0.0278 I-Pentane 15 4.0945 3.2267 3.6380 n-Pentane P5 5.5219 4.3516 4.8559 2,2-Dimethylbutane 16 0.3632 0.3419 0.3682 Cydopentane N5 0.5479 0.4197 0.3888 2.3-Dimethylbutane 16 1.1668 1.0983 1.1597 2-Methylpentane 16 6.6067 6.2190 6.6586 3-Methylpentane 16 3.8006 3.5776 3.7667 n-Hexane P6 10.3687 9.7595 10.3548 2,2-Dimethylpentane 17 0.2513 0.2750 0.2840 Methylcyclopentane N6 3.1300 2.8772 2.6876 2,4-Dimethylpentane 17 0.5598 0.6127 0.6380 2,2,3-Trimethylbutane 17 0.0640 0.0700 0.0709 Benzene A6 1.5855 1.3527 1.0790 3,3-Dimethylpentane 17 0.1550 0.1696 0.1716 Cyclohexane N6 3.0484 2.8022 2.5190 2-Methylhexane 17 2.5078 2.7447 2.8329 2,3-Dimethylpentane 17 0.8002 0.8758 0.8782 1,1-Dimethylcycopentane N7 0.4969 0.5329 0.4943 3-Methylhexane 17 2.6113 2.8579 2.9053 1c,3-Dimethylcyclopentane N7 0.5694 0.6107 0.5738 lt.3-Dimethylcyclopentane N7 0.5059 0.5426 0.5072 3-Ethylpentane 17 0.1701 0.1862 0.1862 1t,2-Dimethylcyclopentane N7 0.7986 0.8565 0.7978 2,2,4-Trimethylpentane 18 0.0391 0.0488 0.0492 IIP n-Heptane P7 6.1240 6.7024 6.8586 1c,2-Dimethylcycopentane N7 0.0341 0.0366 0.0332 Methylcyclohenane N7 5.1024 5.4723 4.9748 2,2-Dimethylhexane 18 0.4695 0.5858 0.5893 Ethylcyclopentane N7 0.1446 0.1551 0.1417 2,5-Dimethylhexane 18 0.2747 0.3427 0.3456 2,2,3-Trimethylpentane IB 0.0160 0.0200 0.0196 2,4-Dimethylhexane 18 0.3531 0.4406 0.4422 1c2t,4-Trimethylcyclopen tan e N8 0.2139 0.2622 0.2404 3,3-Dimethylhexane 18 0.1006 0.1255 0.1238 2,3,4-Trimethylpentane IB 0.0151 0.0188 0.0183 2,3,3-Trimethylpentane 18 0.0160 0.0200 0.0193 Toluene A7 4.4720 4.5007 3.6256 2,3-Dimethylhexane IS 0.1952 0.2436 0.2396 2-Methyl-3-ethylpentane IS 0.0384 0.0479 0.0466 1,1,2-trimethylcyclopentane NB 0.0156 0.0191 0.0173 2-Methylheptane 18 1.5176 1.8935 1.8954 4-Methylheptane 18 0.5377 0.6709 0.6554 3-Methyl-3-ethylpentane 18 0,0458 0.0571 0.0550 3,4-Dimethylhexane 18 0.0838 0.1046 0.1017 1c,2c,4-Trimethylcyclopentane N8 0.0208 0.0255 0.0231 1c,3-Dimethylcyclohexane NB 0.0167 0.0205 0.0187 3-Methylheptane 18 1.1214 1.3992 1.3885 tc,2t,3-Trimethylcyclopentana NB 0.9891 1.2123 1.1017 3-Ethylhexane 18 0.0641 0.0800 0.0786 1t,4-Dimethylcyclohexane N8 0.4727 0.5794 0.5320 1,1-Dimethylcyclohexane N8 0.1686 0.2066 0.1853 2,2,5-Trimethylhexane 19 0.0188 0.0263 0.0259 31-Ethylmethylcyclopentane N8 0.0329 0.0403 0.0368 2t-Ethylmethylcyclopentane N8 0.0293 0.0359 0.0327 1,1-Methylethylcyclopentane N8 0.0483 0.0592 0.0531 2,2,4-Trimelhylhexane 19 0.0134 0.0188 0.0184 11,2-Dimethylcyclohexane N8 0.3000 0.3677 0.3319 1c,20,3-Trimethylcyclopentane N8 0.0020 0.0024 0.0022 1 t,3-Dimethylcyclohexane N8 0.0030 0.0037 0.0033 . n-Octane P8 2.6376 3.2909 3.2785 1 c,4-Dimethylcyclohexane N8 0.4566 0.5596 0.5006 i-Propylcyclopentane IB 0.0316 0.0387 0.0349 2,4,4-Trimethylhexane 19 0.0142 0.0199 0.0193 2,2,3.4-Tetramethylpentane 19 0.0175 0.0245 0.0239 2,3,4-Trimelhylhexane 19 0.0887 0.1243 0.1206 1c,2-Dimethylcyclohexane NS 0.1905 0.2335 0.2054 2,3,5-Trimethylhexane 19 0.0162 0.0227 0.0220 2,2-Dimethylheptane 19 0.0061 0.0085 0.0084 1,1,4-Trimethylcyclohexane N9 0.4337 0.5980 0.5426 2,2,3-Trimethylhexana 19 0.2723 0.3815 0.3663 2,4-Dimethylheptane 19 0.0127 0.0178 0.0174 4,4-Dimethylheptane 19 0.0178 0.0249 0.0244 Ethylcyclohexane N8 0.1758 0.2155 0.1916 n-Propylcyclopentane N8 0.3321 0.4070 0.3670 1c,3c,5-Trimethylcyclohexane NO 0.0857 0.1182 0.1072 2,5-Dimethylheptane 19 0.0119 0.0167 0.0163 3,3-Dimethylheptane 19 0.0156 0.0219 0.0214 3,5-Dimethylheptane 19 0.0097 0.0136 0.0133 2,6-Dimethylheptane 19 0.0043 0.0060 0.0059 1,1,3-Trimethylcyclohexane N9 0.0287 0.0396 0.0359 Ethylbenzene AS 0.2952 0.3423 0.2757 1c,2t,4t-Trimethylcyclohexane N9 0.0069 0.0095 0.0085 2,3-Dimethylheptane 19 0.0187 0.0262 0.0253 1,3-Dimethylbenzene(m-Xylene) A8 1.7410 2.0190 1.6356 1,4-Dim ethyl benzene(p-Xylene) A8 0.6596 0.7649 0.6216 3,4-Dimethylheptane 9 0.0716 0,1003 0.0960 3,4-Dimethylheptane(2) 9 0.0675 0.0946 0.0906 4-Ethylheptane 9 0.0615 0.0862 0.0844 4-Methyloctane 9 0.2624 0.3676 0.3572 2-Methyloctane 9 0.3496 0.4898 0.4806 1 c,21,4c-Trimethylcyclohexane 9 0.0131 0.0183 0.0177 • 3-Ethylheplane 9 0.0598 0.0838 0.0808 3-Methyloctane 9 0.3301 0.4625 0.4493 3,3-Diethylpentane 9 0.0052 0.0073 0.0068 10,2O-Trimethylcyclohexane N9 0.0196 0.0270 0.0240 • 1,1,2-Trimethylcyclahexane N9 0.0055 0.0076 0.0068 1,2-Dimethylbenzene(o-Xylene) A8 0.3867 0.4484 0.3569 1-Butylcyclopentane N9 0.1368 0.1886 0.1691 UnknownC8s U8 0.0912 0.1138 0.1134 n-Nonane P9 1.0380 1.4542 1.4189 1,1-Methylethylcyclohexane N9 0.1376 0.1928 0.1887 i-Propylbenzene A9 0.0380 0.0499 0.0405 i-Propylcyclohexane N9 0.0267 0.0368 0.0321 2,2-Dimethyloctane 110 0.0142 0.0221 0.0209 2,4-Dimethyloctane 110 0.0650 0.1010 0.0957 2,6-Dimethyloctane 110 0.0122 0.0190 0.0186 2,5-Dimethyloctane 110 0.0082 0.0127 0.0120 n-Butylcydopentane N9 0.1168 0.1790 0.1569 3,3-Dimethyloctane 110 0.0206 0.0320 0.0303 n-Propylbenzene A9 0.1446 0.1898 0.1540 3,6-Dimethyloctane 110 0.0461 0.0716 0.0678 3-Methyl-5-ethylheptane 110 0.0324 0.0454 0.0438 1,3-Methylethylbenzene AO 0.1377 0.1808 0.1454 1,4-Methylethylbenzene A9 0.0529 0.0694 0.0558 1,3,5-Trimethylbenzene A9 0.1865 0.2448 0.1983 2,3-Dimethyloctane 110 0.0421 0.0654 0.0619 5-Methylnonane 110 0.1012 0.1573 0.1504 1,2-Methylethylbenzene A9 0.1372 0.1801 0.1441 2-Methylnonane 110 0.0179 0.0278 0.0268 3-Ethyloctane 110 0.0183 0.0284 0.0269 3-Methylnonane 110 0.0885 0.1375 0.1313 1,2,4-Trimethylbenzene A9 0.0011 0.0014 0.0011 t-Butylbenzene A10 0.2112 0.3096 0.2504 i-Butylcyclohexane N10 0.0489 0.0749 0.0646 lt-Methyl-2-n-propylcydohexane 110 0.0099 0.0139 0.0134 i-Butylbenzene A10 0.0160 0.0235 0.0193 • sec-Butylbenzene A10 0.0111 0.0163 0.0133 UnknownC9s U9 0.4413 0.6182 0.6032 n-Decane P10 0.3955 0.6146 0.5896 1,2,3-Trimethylbenzene A9 0.0294 0.0386 0.0303 1,3-Methyl-i-propylbenzene A10 0.0192 0.0252 0.0202 1,4-Methyl-I-propylbenzene Al0 0.0116 0.0152 0.0122 Sec-Butylcyclohexane N10 0.0622 0.0953 0.0821 1,2-Methyl-I-propylbenzene A10 0.0553 0.0811 0.0648 3-Ethylnonane 110 0.0075 0.0117 0.0113 1,3-Diethylbenzene Al0 0.0114 0.0167 0.0135 1,3-Methyl-n-propylbenzene Al0 0.0164 0.0240 0.0195 1,4-Diethylbenzene A10 0.0392 0.0575 0.0468 1,4-Methyl-n-propylbenzene A10 0.0057 0.0084 0.0089 n-Butylbenzene MO 0.0114 0.0167 0.0136 1,3-Dimethyl-5-ethylbenzene A10 0.0197 0.0289 0.0234 1,2-Diethylbenzene Al0 0.0087 0.0128 0.0102 1,2-Methyl-n-propylbenzene A1D 0.0256 0.0375 0.0301 1,4-Dimethyl-2-ethylbenzene A10 0.0307 0.0450 0.0359 1,3-Dimethyl-4-ethylbenzene A10 0.0031 0.0045 0.0036 1,2-Dimethyl-4-ethylbenzene A10 0.0494 0.0724 0.0580 1,3-Dimethyl-2-ethylbenzene A10 0.0189 0.0277 0.0218 lt,2c,4-Trimethylcyclopentane A10 0.1675 0.2053 0.1923 1,2-Dimethyl-3-ethylbenzene A10 0.0167 0.0245 0.0192 1,2-Ethyl-i-propylbenzene A10 0.0097 0.0142 0.0114 1,4-Methyl-t-butylbenzene All 0.0337 0.0494 0.0395 UnknownC10s U10 0.6136 0.9536 0.9148 n-Undecane P11 0.1878 0.3206 0.3033 1,4-Ethyl-i-propylbenzene All 0.0124 0.0182 0.0146 1,2,4,5-Tetramethylbenzene All 0.0119 O0174 0.0138 1.2-Methyl-n-butylbenzene All 0.0111 0.0163 0.0130 1,2,3,5-Tetramethylbenzene All 0.0149 0.0218 0.0172 1,2-Methyl-t-butylbenzene All 0.0219 0.0321 0.0257 • 5-Methylindan All 0.0080 0.0149 0.0139 4-Methylindan All 0.0055 0.0102 0.0095 1,2-Ethyl-n-propylbenzene All 0.0014 0.0021 0.0017 • 2-Methyllndan All 0.0030 0.0056 0.0052 1,3-Methyl-n-butylbenzene All 0.0041 0.0060 0.0048 1,3-Di-i-propylbenzene All 0,0057 0.0084 0.0067 sec-Pentylbenzene All 0.0151 0.0221 0.0177 n-Pentylbenzene All 0.0069 0.0112 0.0091 lt-M-2-(4MP)cyclopentane P12 0.0138 0.0257 0.0241 1,4-Di-i-propylbenzene All 0.0191 0.0280 0.0224 t-Decahydronaphthalene A10 0.0061 0.0089 0.0071 Naphthalene A10 0,0148 0.0207 0.0165 1-t-Butyl-3,5-dimethylbenzene Al2 0.0042 0.0062 0.0050 1,4-Ethyl-t-butylbenzene All 0.0086 0.0126 0.0101 UnknownClls U I 1 0.2547 0.4349 0.4114 n-Dodecane P12 0.1155 0.2149 0.2011 1,3-Di-n-propylbenzene Al2 0.0064 0.0094 0.0075 1,3,5-Triethylbenzene Al2 0.0081 0.0106 0.0086 1,2,4-Triethylbenzene Al2 0.0340 0.0446 0.0357 1,4-Methyl-n•pentylbenzene Al2 0.0106 0.0155 0.0124 n-Hexylbenzene Al2 0.0131 0.0232 0.0190 1,2,3,4,5-Pentamethylbenzene A13 0.0122 0.0179 0.0143 2-Methylnaphthalene All 0.0172 0.0267 0.0213 1-Methylnaphthalene All 0.0148 0.0230 0.0158 UnknownCl2s U12 • 0.1213 0.2257 0.2112 n-Tridecane P13 0.0600 0.1208 0.1117 UnknownC13s .113 0.0949 0.1911 0.1767 n-Tetradecane P14 0.0290 0.0628 0.0579 UnknownCl4s U14 0.0966 0.2093 0.1931 n-Pentadecane P15 • 0.0164 0.0381 0.0347 UnknownC15s U15 0.0632 0.1466 0.1337 n-Hexadecane P16 0.0038 0.0094 0.0085 UnknownCl6s U16 0.0230 0.0569 0.0516 n-Heptadecane P17 0.0004 0.0010 0.0009 UnknownC17s U17 0.0037 0.0097 0.0088 . n-Octadecane P18 0.0002 0.0006 0.0005 UnknownClBs U18 0.0004 0.0011 0.0010 UnknownCl9s U19 0.0002 0.0006 0.0005 TOTAL 100.0000 100.0000 100.0000 THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT STATE-OF-THE ART ANALYTICAL TECHNIQUES. THE APPLICATIONS OF THIS INFORMATION IS THE RESPONSIBILITY OF THE USER. EMPACT ANALYTICAL SYSTEMS,INC ASSUMES NO RESPONSIBILITY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF ITS APPLICATION • EMPACT A A I PROJECT NO: 201105150 ANALYSIS NO.: 02 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: JUNE 21,2011 SAMPLE DATE: MAY 26,2011 COMMENTS: 1L JAR SAMPLED BY: J.MOSER SPOT Q 67°F;LIGHT BROWN/ORANGE EMPACT TEST PROCEDURE I METHOD: API GRAVITY DESCRIPTION: API GRAVITY t 60/60 ENTERPRISE COMPRESSOR 58.5 PROCUTION TANK Q12:10 • THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT STATE-OF-THE ART ANALYTICAL TECHNIQUES. THE APPLICATIONS OF THIS INFORMATION IS THE RESPONSIBILITY OF THE USER. EMPACT ANALYTICAL SYSTEMS,INC.ASSUMES NO RESPONSIBILITY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF IT'S APPLICATION. I EMPACT Analytical Systems, Inc. 365 South Main St. Brighton, CO. 80601 (303)637-0150 • EMPACT PROJECT NO: 201105160 ANALYSIS NO.: 02 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: JUNE 21,2011 SAMPLE DATE: MAY 26.2011 COMMENTS: 1L JAR SAMPLED BY: J.MOSER SPOT @ 67°F; LIGHT BROWN/ORANGE EMPACT TEST PROCEDURE I METHOD: REID VAPOR PRESSURE{ASTM D-323} DESCRIPTION: REID VAPOR PRESSURE ENTERPRISE COMPRESSOR 6.1 PROCUTION TANK @12:10 • THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT STATE-OF-THE ART ANALYTICAL TECHNIQUES. THE APPLICATIONS OF THIS INFORMATION IS THE RESPONSIBILITY OF THE USER. EMPACT ANALYTICAL SYSTEMS,INC.ASSUMES NO RESPONSIBILITY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF IT'S APPLICATION. • EMPACT Analytical Systems, Inc. 365 South Main St. Brighton, CO. 80601 (303)637-015O • g >," ) \f \ 0 /\O ! r, - m � ■ ! kw { ! 6 15 _ ! CO ,- § / -6 O en \ § ° 00 ! / —m toa ! rt § kt a0 :OEa. rz � � � § ! \ • /j- g3) 76 0606 ce c 0601 k ®� ( ) 2 }$ro 2 \ \ po 0 ° It ',5 � ! a 0 ) / L. � � 2 / \ mri g k /k ° ! � , a � ® . s n77 7 < < . ± ; ! u < « ■ ! } � B wow ! 2 e ) / ! / al k § Fugitive Emissions From Equipment Leaks • Enterprise Compressor station DCP Midstream,LP Process Units Number 'het compression 5 $6Parator5 __`_r VOC Storage Tanks 6 , Dehydrator 1 Component Type Ltght Liquid Gas. . - Total . .,••Light Liquid - Gas Total Connections 256 2914 3170 640 7285 7925 Flares___ 105 _ 337 442 262 843 1104 Opel-Ends 9 C 9 23 0 23 Pumps 5 5 10 13 13 - 25 VBWee 85 473 558 213 1183 1395 • "Others" 5 40 45 '1 100 1'1 TOTALS• •'.••'484 '.• '::,':3769 • 4233 • .:• • 1161 9423 10584 '111rl6slon'' Emisslp0'. •Emission •Emission Emission Emiselon ''',:,Factor(B) Factor(S) Rate •Rate Rate. '''-Rats•:': Light Liquids. Gas` Light Liquid • Gas Light LigWd.. . •Gas,::; Component Type 'Fglhr kgUlr Ibsthr'• IbsU1r tPr py Connections 2.10E-04 2.006.04 0.17 1.28 0.52 5.82 Flanges 1.10E-04 3.90E-04 3.03 629 0.11 1.27 Oaen-Ends 1.40E-03 2.00E.3, 0.03 000 0.12 0.0C P umps 1.30644. 2.40E-03 0.14 0.03 0.63 0.12 Valves 2.50E-03 4.50E-03 0.47 4.68 2.05 20.51 'Otters- 7.50E-03 8.80E-03 0 08 0.77 3.33 3.39 _ 3.76 30.90 Totals .7.91 . 34.66 . On Analria mot.Wt:•• Mole56. .. Weight . Wt b Conacted - osicpiuNiirnt (880m010)• 1Vo1%i' (iiulbmole Gan) 'Mt%) ...- Methane 16.0 73.610 11.78 62.73 55.61% Ethane �..-.. 30.0 13.444 4.03 16.06 19.15% Tot.MethiEth 87.053 15.6 70.8 74.92% Propane 44.0 5.763 2.54 11.35 1202% • i-13ulane 58.0 0.819 0.48 2.'3 2.25% n•Butane 58.0 1.874 1.09 4.87 5.15% i-pentane 720 0.501 0.36 4.61 1.71% n-Pentane 72.0 0.538 _ 0.39 1.74 1.81% Other Nenartes. 86.0 0.350 0.31 1.38 1.46% n•Hexane 86.0 0.112 0.10 043 0.46% Benzene 78.1 0.025 0.02 0.09 0.00% Toluono s 92.1 , 0.020 0.02 0.09 0.09% Ethylbencer,e 106.7 0.000 0.00 0.00 0.00% Xylenes 106.2 0.004 0.00 0.02 0.02% Total VOC 10.016 _ 5.3 23.70 25.0B% Carbon Dioxide 44.0 2.590 1.14 5.10 Mesurn 4.0 0.010 0.00 0.00 Oxygen 32.0 0010 0.03 001 N.N.tiv en 280 0.3'20 309 0.40 10 1t10A{s. 22.33 100.00 ' `' •. Total Hydrocarbon - - _.. 21.1 - . 1.1a'ch 19,2011 Gas 1111 DCP M.dsusam.LP 10121/2011 Gas Service Speclotion Light Liquid Service Speclation • • Emisalon Rale z. EmisMonAato Component WMpht% Ibslhr^. ! Ipy Can,ponenl Weigbt% Ibaanr•y tpy Nitrogen 00000 0.00 Nitrogen 0.00 0.00 Methane 55.81% 3.9370 17.24 Methane 0.00 0.00 Carbon()Made 0.0000 0.0000 Carbon Dioxide 0.00 000 Ethane 19.11% 1.9482 5.9050 Ethane 0.00 0.00 Hydrogen Sulfide 0.00% 00000 0.0000 Hydrogen Sulfide 0.00 080 Propane 12.02% 0.8477 3.7128 Propane 6081% 0.69 3.04 LButane 2.25% 0.1568 0.6955 i-Butane 0.00 0.00 n•Butane 5.15% 0.3633 1.5912 n-Butane 0.00 0.00 I-Pentane 1.71% 0.1205 0.5276 ~Pentane 0.00 0.00 n.Pentane 1.84% 0.1296 0.5676 tePenntane 0.00 0.00 Niel Rezones. 1,46% 0.1032 0.4520 Other Her ones+ 000 000 n-Hexane 046% 0.0323 0.1414 n-Hexane 9.76% 0.08 0.37 penzene 0.09% 0.0066 0.0287 Benzene 1.35% 001 D.05 Toluene 0.09% 0.0063 0.0275 Toluene 4.50% 0.09 D.17 Elhdbenzene 0.00% 0.0001 0.00062 Ethylbenzene 0.34% 0.00 D.01 Xylene(m.p.o) 0.02% 0.0013 0.0059 Xytenes(m,p,o) 3.23% 0.63 0.12 ,. TotaiHM's '.0.0466 0.0628 c TotatHWs ;...0.16 '>0.72 TtotatVOC 1.77 ': 9.75 `-TotalVOC -0A6 -3.76 btai Emkstone 7.05 ::.30.90 Total Emissions 0.86 -:3.76 •Assume 100 v4%VOC to be conservative, HAP v4%from Liquid Ma i iTotal Emissions Total Emissions vd buffer- BuBpi' GrandTotals lbsthr tpy Ibsthr - tpy 2.5 Total HAP's , 031 093 053 2.31 Total VOC 2.63 11.51 6.87 28.77 n-Hezana 0.12 051 0.29 1.27 Benzene 0.02 008 0.05 0.20 Toluene 0.04 020 0.11 049 Ethylbenzone 0.00 0.01 0.01 0.03 Xylenea 0.03 0.13 0.07 0.32 • Al compunM bawl band won API Pwueae.n4819(rape el and API Ptallealien dills(Table 51 m EPA omission factors ablelnedlran e.Ma01 lot EWlpnenl leek Emissions Es Pinnies'EPA Publiaelion No.anR06Ar7 I • DCP Midstream,LP 10121/2011 • Component Number of Emiss.Fact. HC Emiss. Percent Control -Ely Enlist Type Components (1b/comp/hr) (lb/hrI VOC* Factor 1(b/hrl Valves 473 0.00992 4.692 27.67 0 1.298 Relief Valves 35 0.01940 0.679 27.67 0 0.188 Compressors 5 0.01940 0.097 27.67 0 0.027 Flange/Conn 337 0.00086 0.290 27.67 0 0.080 Connectors 2914 0.00044 1.282 27.67 0 0.355 Open-Ended 0 0.00441 0 27.67 0 0.000 Pump Seals 5 0.00529 0.026 27.67 0 0.007 Total All 1.955 * Percent VOC from Gas Analysis = 27.67 Connectors 2914 flanges 337 open ends 0 pumps 5 valves 473 other 40 • 0 • MPACT ANALYTICAL f YSTEMS INC.fsill�•,] 365 S.MAIN SP. �lCil�pp7Fl�f�� BRIGHTON,CO \'��`••IIF'%�j' 80601 303.637.0150 EXTENDED NATURAL GAS ANALYSIS(•OHA1 MAIN PAGE • PROJECT NO. : 201103130 ANALYSIS NO.: 02 COMPANY NAME: OCR MIDSTREAM-LP ANALYSIS DATE: MARCH 19.2011 ACCOUNT NO. : SAMPLE DATE : MARCH 18,2011 PRODUCER : CYLINDER NO.: BBB LEASE NO. : SAMPLED BY : STEPHEN ONDAK NAME/DESCRIP: ENTERPRISE INLET PRE DEHY @14:30 "'FIELD DATA"' SAMPLE TEMP.: 100 SAMPLE PRES.: 900 AMBIENT TEMP.: VAPOR PRES. : GRAVITY . COMMENTS : SPOT;NO PROBE GPM@ GPM® COMPONENT MOLE% MASS Ye 14.650 14.730 ALCOHOLS 0.0006 0.0016 HELIUM 0.01 0.00 HYDROGEN 0.00 0.00 --- -- OXYGEN/ARGON 0.01 0.01 --- -- NITROGEN 0.32 0.40 --- -- CARBON DIOXIDE 2.59 5.09 --- •-- METHANE 73.60980 62.69890 --- -- ETHANE 13.4435 18.0401 3.5886 3.6082 PROPANE 5.7633 11.3416 1.5851 1.5936 I-BUTANE 0.8191 2.1247 02672 0.2686 N-BUTANE 1.8738 4.8604 0.5694 0.6926 I-PENTANE 0.5245 1.6686 0.1001 0.1911 N-PENTANE 0.5144 1.6563 0.1861 0.1871 HEXANES PLUS 0.5210 2.0898 0.2930 0.2940 TOTALS 100.00000 100.00000 6.6995 6.7354 BTEX COMPONENTS DMOLE% WT% BTU® 14.650 14.730 BENZENE 0.0251 0.0876 LOW'NET DRY REAL: 1163.7/scf 1170.1 Isct TOLUENE 0.0204 0.0839 NET WET REAL: 1143.4/et? 1149.7 tact ETHYLBENZENE 0.0004 0.0019 BXGII GROSS DRY REAL: 12808/scf 1287.8/scf XYLENES 0.0038 0.0181 GROSS WET REAL: 1258.4 lief 1265.4/set TOTAL BTEX 0.0497 0.1914 NET DRY REAL: 19719.6 115 19627.3 114 GROSS ORY REAL: 21713.0❑b 21831.5/lb RELATIVE DENSITY(AIR=1): 0.7727 (CRC':G'ASTO JIB tt 7P.11O14.69.1&60k) COMPRESSIBILITY FACTOR : 0.99616 WAILED HYDROCARBON.NALI'SI,&NI 1994);ASTNID69)B TINS DATA HAS BEER ACQUIRED TRADUCE APPLICATION OFCUARENTSTATEOF'.)NE-AATANALIVCAL IECIINIQUES PIE USE OF MIS 1NFOAVATIONISTHERESPDXSIBU))'OF11IF.USER EIIPALTANAL)71('ALSISTFNIS 4SSINESN'O RFSPONS)BLITY FOR ACCURACY OFTHEWOAlED NY'0AWT I0N NOR Aa7CO.I'SEQUEDCL3 OPITS4 Itt ICAT70,V S 11U\\ .1 IMPACT ANALYTICAL t<*` SYSTEMS INC. 365 S. MAIN ST. BRIGHTON, CO �Si��••' ��•Gf//� 80601 303.637.0150 EXTENDED NATURAL GAS ANALYSIS(THAI GLYCALC INFORMATION PROJECT NO. : 201103130 ANALYSIS NO.: 02 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: MARCH 19,2011 ACCOUNT NO. : SAMPLE DATE : MARCH 18,2011 PRODUCER : CYLINDER NO.: 886 LEASE NO. : SAMPLED BY : STEPHEN ONDAK NAMEIDESCRIP: ENTERPRISE INLET PRE DEHY(@4:30 "'FIELD DATA"' SAMPLE TEMP.: 100 SAMPLE PRES.: 900 AMBIENT TEMP.: VAPOR PRES. : GRAVITY . COMMENTS : SPOT; NO PROBE • Componet Mole¶4 WI% Helium 0.01 0.00 Hydrogen 0.00 0.00 Carbon Dioxide 2.59 5.09 Nitrogen 0.32 0.40 Methane 73.60980 52.69890 Ethane 13.4435 18.0401 Propane 5.7633 11.3416 Isobutane 0.8191 2.1247 n-Butane 1.8738 4.8604 Isopentane 0.5005 1.6115 n-Pontane 0.5144 1.6563 Cyclopentane 0.0240 0.0751 n-Hexane 0.1123 0.4319 Cyclohexane 0.0286 0.1074 Other Hexanes 0.2068 0.7920 Heptanes 0.0782 0.3486 Methycyclohexane 0.0227 0.0995 2,2,4 Trimethylpenlane 0.0000 0.0000 Benzene 0.0251 0.0875 Toluene 0.0204 0.0B39 Ethylbenzene 0.0004 0.0019 Xylenes 0.0038 0.0181 08+Heavies 0.0227 0.1190 Subtotal 99.98940 99.98840 Oxygen/Argon 0.01 0.01 Alcohols 0.0006 0.0016 Total 100.00000 100.00000 THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT STATE•OF•THE ART ANALYTICAL TECHNIQUES. THE APPLICATIONS OF THIS INFORMATION IS THE RESPONSIBILITY OF THE USER. EMPACTANALYTICAL SYSTEMS,INC.ASSUMES NO RESPONSIBILITY • FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF ITS APPLICATION. EMPACT Lam'---___ EXTENDED NATURAL GAS ANALYSIS(aDHA1 PHA COMPONENT LIST PROJECT NO. : 201103130 ANALYSIS NO.; 02 COMPANY NAME: DCP MIDSTREAM.LP ANALYSIS DATE: MARCH 19,2011 ACCOUNT NO. : SAMPLE DATE: MARCH 18,2011 PRODUCER : CYLINDER NO.: 886 LEASE NO. : SAMPLED BY : STEPIIENONDAK NAME/DESCRIP: ENTERPRISE INLET PRE DENY @14:30 "'FIELD DATA'" SAMPLE TEMP.: 100 SAMPLE PRES,: 900 AMBIENT TEMP.: VAPOR PRES. : GRAVITY COMMENTS : SPOT;NO PROBE GPM @ GPM@ COMPONENT PIANO II MOLE% MASS% 14.650 14.730 Ilelhwl ... 0.01 0.00 ... ... Hydrogen ••. 0.00 0.00 -.- ... Oaygcn/Argon .-. 0.01 0.01 -- ... Nitrogen ... 0.32 040 --. ... ' Carbon Dioxide ... 259 5.09 ... ... Methane PI 7340980 52.69890 --- .,. Ethane P2 13.4435 18.0401 3.5886 3.6082 Propane P3 5.7633 11.3416 1.5851 1.5938 i-Butanc 14 0.8191 2.1247 0.2672 0.2686 n-Eulant P4 1.8738 4.8604 0.5894 0.5926 2,2-Dimethylpropanc I5 0.0051 0.0164 0.0020 0.0020 • Ethanol X2 0.0001 0.0002 0.0000 0.0000 i•Peniane IS 0.4954 0.5951 0.1811 0.1821 iPropanol X3 0.0004 0.0011 0.0000 0.0000 n-Pentane 115 0.5144 1.6563 0.1861 0.1871 2,2-Dimethylbucane 16 0.0072 0.0277 0,0030 0.0030 n-Psopanol X3 0.0001 0.0003 0.0000 0.000D Cyclopentane N5 0,0240 0.0751 0.0070 0.0070 2,3•Dime004bulane 16 0.0160 0.0615 0,0070 0,0070 2-Methylpemane 16 0.0971 0.3735 0.0400 0.0402 3•Methylpenlane 16 0.0492 0.1892 0.0200 0,0201 n-Hexane P6 0.1123 0.4319 0.0460 0.0463 2,2-Dimnhylpenuno 17 0.0022 0.0098 0.0010 0.0010 h4thylcyclopentane 146 0,0373 0.1401 0.0130 0.0131 2,4•Dimed04penlanc 17 00011 0.0183 0.0020 0.0020 2,2,3.Trime004bulane 17 0.0004 0.0018 0.0000 0.0000 Benunc A6 0.0251 0.0875 00070 0.0070 3,3-Dimdhylpcntane 17 0.0001 0.0036 0.0000 0.0000 Cyclohcxane NG 0.0286 0.1074 0.0100 0.0101 2.Mrlhylhexane I? 0.01.16 0.0653 00070 0.0070 2,3-Dimethylpentane 17 0.0076 0.0161 0.0020 0.0020 I,1-Dimtlhylcyclopmlano N7 0.0033 0.0145 0.0010 0.0010 3.Methylhuane 17 0.0129 0.0577 0.0060 0.0060 Ie,3-Dimethyleycloptmmne N7 0.0035 0.0154 0.0020 0.0020 10,3.Dirnethylcyclopeniano N7 0.0031 0.0136 0.0010 0.0010 3•Ethylpetuane I7 0.0003 0.0013 0.0000 0.0000 lh2-Dlmethylcyclopnnane N7 0.0051 0.0224 0.0020 0.0020 n.Heptane P7 00233 0.1042 0.0110 0.0111 Ic,2-Dimedylcyclopenune N7 0.0001 0.0005 0.0000 0.0000 • Pogo 1 EMPACT MoyVwl Systems,Inc 385 S.1.teln Street,0n0hlon,CO 80601 303637-0160 • Methyleyelobexane N7 0.0227 00995 0.0090 0.0091 2,2-Dimcaylhcxane 18 0.0009 0,0046 0.0000 0.0000 1,1,3-Tdmclhyloyelopentene N7 0.0003 0.0015 0.0000 0.0000 Ethyleyclopenlaa N7 0.0006 0.0026 0.0000 0.0000 2,5-Dimelhylhoxane IS 0.0007 0,0036 0.0000 0,0000 2,4•Dimethylhexane IS 00008 00041 0.0000 0.0000 1e,21,4-Trimeilrylcyclopenlane N8 0.0007 0.0035 0.0000 00000 3,3-Dimeihylhexvm IS 00002 0.0000 0.0000 00000 11,20,4-hintelhy leyclopentane N8 0.0005 0.0025 0.0000 0.0000 Toluene A7 0,0204 0.0839 0.0070 00070 23-Dimobylhcxane IS 0.0004 0.0021 0.0000 0.0000 2.hlethylheplane 18 0.0028 0.0143 0.0010 0,0010 4.5kIIlyIhepNno IS 0.0009 0.0016 0.0000 0.0000 3.51e1hy1.3•elhylpeniane 18 0,0001 0,0005 0.0000 0.0000 3-hlclhylheplano 18 0.0001 0.0005 0,0000 0.0000 fo,2L3-Trimelhyleyelopenlanc NS 0.0035 0.0175 0.0020 0.0020 3-Ethylhexane 18 0.0002 0,0010 0,0000 0.0000 I I,4•Dimelhylcyelohexone NC 0.0009 0.0015 0.0000 0.0000 1,1•DimeOrylcy'elollnanc NE 0.0004 0.0020 0,0000 0.0000 3l.Elhyhndhylcyclopenlene NS 0.0001 0.0305 0.0000 0.0000 21-E110•Imethylcyclopenlane NS 0.0001 0.0005 0.0000 0.0000 l,141011y0e,hylcyclopenlane NS 0.0001 0.0005 0.0000 0.0000 11.2-Dimethyleyclohexane N8 0.0006 0.0030 0.0000 0.0000 n-Octane PS 0.0036 0.0183 0.0020 0.0020 In4-Dimell0•lcyclohextne NS 0.0002 0.0010 0.0000 0.0000 2,3,5'mmehylhexane 19 0.0001 0,0006 0.0000 0.0000 2,3;1-TdmethyIltexsne 19 0.0001 0.0006 0.0000 0.0000 IG2•Dimelhyleyelohexane NS 0,0001 0,0005 0.0000 0.0000 . 1,1,4-Tdme0,yIcyelgaxane N9 0.0007 0,0039 0.0000 0.0000 2,2,3•Trimelhylhexane 19 0.0002 0.0012 0.0000 0.0300 Ethylcy'elohneenc NS 0.0002 0.0010 0.0000 0.0000 n.Propylcydopenlane N8 0.0002 0.0010 0.0000 00000 lc,3c,5-Tdlncllgkyclohcxane N9 0.0001 0,0006 0.0000 0.0000 Elhyl6enzenc 18 0.0004 0.0019 0.0000 0.0000 le,21,4thimethylcyelohexane 149 0.0001 0.0006 0.0000 0.0000 • 1,3•Dimethylbenzenc Oa-Xylem) AS 0.0023 0.0109 0.0010 0.0010 1,4-Dimelhylbeniene(p-X19010 A8 0.0007 0.0043 0.0000 0.0000 3,4-DimelhylltepanB 19 0.0002 0.0012 0.0000 0.0000 3,4•Dlmethyll,eplane(2) 19 0,0001 0.0006 0.0000 0,0000 4-Bt1ylheplane 19 0.0001 0.0006 0.0000 0.0000 4-hlchyloetane 19 0.0002 0.0012 0.0000 0.0000 2-A1ohylocane 19 00002 0.0012 0.0000 0.0000 3-xleihy'loctane 19 0.0002 0.0012 0.0000 0.0000 1,2•Dimethylbenamm(n.Xylene) AS 0.0006 0,0029 0.0000 00000 I-Burylcyclopenrano 149 0.0001 0.0006 0.0000 0.0000 UnknownCBs US 0.0002 0.0010 0.0000 0.0000 n-Nonane P9 0.0006 00034 0.0000 0.0000 n•Bnlylcy'clopenlane N9 00001 0.0006 0.0000 00000 n.Prapylbenzene A9 0.0001 0.0005 0,0000 0.0000 1,3•161e00•Iethylbenztne A9 0.0001 0.0005 0.0000 0.0000 13,5-Trimethylbenxene A9 0.0001 00005 0.0000 0.0000 1-Borylbenoene A10 00001 0.0006 0.0000 0.0000 UnknownC9s U9 0,0003 0.0017 0.0000 0.0000 n-Decane PIO 0.0001 0,0006 0.0000 0.0000 UnLnotsnClus U10 0.0001 0.0006 0.0000 0.0000 UntnownCI85 DIE 0.0002 0,0023 0.0000 0.0000 TOTAL 100.00000 100.00000 6,6095 6,6454 BEEXCO\IPONENTS h1OLE51 WM BTU@ 14.850 14.730 BENZENE 0.0251 0.0075 LOW NET DRY REAL: 1163.7 het 1170.1 ha TOLUENE 0.0204 0.0839 NET WET REAL: 1193.9 her 1149.7 hef ETHYLOENZENE 00004 0.0019 111CN GROSS DRY REAL: 1280,5 hef 1287.0 het XYLENE$ 0.0008 0.0181 GROSS WET REAL: 1258.4 hd 1285.4 Act TOTAL BTEX 0.0407 0.1914 NET DRY REAL: 19710.6 Ab 18827.3 he GROSS DRY NEAL: 21713.0 Ab 21831.5 sib RELATNE(DENSITY(NR•1): 0.7127 AAMOMMETOD0 A INI Ci44NAC0e) COMPRESSIBILITY FACTOR: 0.99616 iOLTAILEDID 'ARWA•A1'ALIxiS.YI Ins,);AMTD1%Ile MISn?A IL s$ELYAeQZMIL VIMOLMIAPPLICATIO.N &e'PNV:TSTAILOYMIEARTAYALI7MAL ILY1IYl1W2 MC la"OF n its s1'IYM,NTIONIS MEEESIVA7AU1nOFMtMit IMPACTAN'LLITJCAL a13701S AIImleS.5U RLV'0.5NBUIT*VA ACCCR,CrOF TICE REFORM NIVAILITIOYhoaAATcO14QtIEWISOE ITS APPIMAlpx'. • Papo 2 EMPACT Analytical Syslems,Inc 305 S.Main Street.B6phlon,0080001 303337.0150 1 . . t 1 . / ! \ii id SS in k �� \ $ ii EEEE � cis 0 % k \\C. 08 f _ »! . o `- - MA w • &I)C !o / /e $»!{ • o , |}|� o 2 •'` [ 0 | � !� � -}3 I-% k / oU5 ! • 4.1§ \ /}/ U') f pi . !$` / . y ;� }-r �y fi0orrof � +g\/ w si .§; ( kP{ /� w/ ®` 3 \ |f , \k j/\ k�• . § !!k� iin 0 • C 0 E.. .. . . . . . . . 7 . . 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O Combustion Device(Tank Control) • Enterprise Compressor Station DCP Midstream,LP Source ID Combustor 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 958 Btu/scf Longitude deg Pilot Flow Rate 25 scf/hr or Pilot Heat Input 0.02 MMBtu/hr UTM Zone Pilot Potential Ope 8760 hr/yr UTM Northing m Pilot Potential Fuel 0.22 MMscf/yr UTM Easting m Destruction Efticiei 95% Datum Emissions from Pilot Combustion Emission Source of CAS Factor Emission Pollutant Number (Ib/MMscf) (lb/hr) (Ib/yr) lton/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-422 SO2 0.6 0.01 87.60 0.05 AP-422 PM 7.8 0.01 87.60 0.05 AP-422 2-Methylnaphthalene , 91-57.6 2.40E-05 0.0001 0.8760 0.0005 AP-423 3•Methylchloranthrene 56-49-5 1.80E-06 0.0001 0.8760 , 0.0005 AP-423 7,12-Dimethylbenz(a)anthra 1.60E-05 0.0001 0.8760 0.0005 AP-423 Acenaphthene 83-32.9 1.80E-06 0.0001 0.8760 0.0005 AP-423 Acenaphthytene 208-96-8 1.80E-06 0.0001 0.8760 _ 0.0005 AP-423 Anthracene 120-12-7 2.40E-06 0.0001 0.8760 0 0905 AP-423 Benz(a)enthracene 56-55-3 1.80E-06 0.0001 0.8760 0.0005 AP-421 • Benzene 71-43-2 2.10E-03 0.0001 0.8760 0.0005 AP-423 Benzo(a)pyrene 50-32-8 1.20E-06 , 0.0001 0.8760 0.0005 AP-423 Benzo(b)fluoranthene 205.99-2 1.80E-06_. 0.0001 0.8760 0.0005 AP-423 Benzo(g,h,i)perylene 191-24-2 - 1.20E-06 0.0001 0.8760 0.0005 AP-423 Benzo�k)fluoranthene 205-82-3 1.80E-06 0.0001 0.8760 0.0005 -AP-423 Chrysene 218-01-9 1-BOE-06 0.0001 , 0.8760 0.0005 AP-423 Dibenzo(a,h)anthracene 53-70-3 1.20E-06 0.0001 0.8760 0.0005 AP-423 Dichlorobenzene 25321-22-6 1.20E-03 0.0001 0.8760 0.0005 AP-423 Fiuoranthene 206.44.0 3.00E-06 0.0001 - 0.8760 0.0005 AP-423 Fluorene 86-73-7 2.80E-06 _ 0.0001 0.8760 0.0005 AP-423 Formaldehyde 50-00-0 7.50E-02 0.0001 0.8760 0.0005 AP-423 n-Hexane 110-54-3 1.80E+00 0.0001 0.8760 , 0.0005 AP-423 lndeno(1,2,3-c,d)pyrene 193-39-5 1.80E-08 0.0001 0.8760 0.0005 AP-423 Naphthalene 91-20-3 6.10E-04 0.0001 0.8760 0.0005 AP-423 Phenanthrene 85-01-8 1.70E-05 0.00Q1 0.8760 0.0005 AP-423 Pyrene 129-00-0 5.00E-06 0 0001 0 8760 0.0005 AP-423 Toluene 108-88-3 _ 3.40E-03 0O001 0.8760 0.0005,_ AP-423 Arsenic 7440-36-2 2.00E-04 0.0001 0.8760 0.0005 AP-424 Beryllium 7440-41-7 , 1.20E-05 0.0001 0.8760 0.0005 , AP-424 Cadmium 7440-43-9 1.10E-Q3- 0.0001 , 0.8760 0.0005 w 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 08760 0.0005 AP-424 Mercury 7439-97-6 2.60E-04 0.0001 , 0.8760 0.0005 AP-424 Nickel 7440-02-0 , 2.10E-03 0.0001 , 0.8760 0.0005 ,AP-424 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 2 EPA AP-42,Volume I,Fifth Edition,July 1998,Table 1.4.2 • 3 EPA AP-42,Volume I,Fifth Edition,July 1998,Table 1.4-3 4 EPA AP-42,Volume 1.Fifth Edition,July 1998,Table 1.4-4 Enterprise Compressor Station • DCP Midstream,LP Continued Vents to Combustion Device Flow Rate Operation Flow Rate Heat Value Heat Rate Vent Stream (scf/hr) (hr/yr) (MMscf/yr) (Btulscf) (MMBtulyr), Condensate Tank 18.81 8760 0.16 3397 559.9 Emissions from Combusting Vent Gas NOx NOx CO CO Vent Stream (lb/hr) (tpy) (lb/hr) (tpy) Condensate Tank Vents 0.009 0.040 0.036 0.158 Total 0.01 0.04 0.04 0.16 Note:NOx emission factor,0.136 Ib/MMtltu,and CO emission factor,0.5496 ib/MMBtu,from TNRCC Flares and Vapor Oxidizers,Table 4 Flare Factors Total Emissions NOx NOx CO GO VOC VOC Vent Stream (lb/hr) (fpy) (Iblhr) (tpy) , ib/hr) (tpy) Condensate Tank Vents 0.009 0.040 0.036 0.158 , SeeTank Coles Picot Emissions 0.010 0.050 0.010 0.050 87.60 , 0.05 Total 0.02 0.04 0.04 0.16 , 0 I C N C a) a D O t QI C O O. N Z Q w l0 2 .O O a `o n N .O O1) Q O N- O N E N Y 2 f a - 0 d0 `coog2Q2 o (fN0 • O N w r M V N a N O O 2; o Or 2 'E a 0 O w a8000 °- w d n m 048 2-:‘ ,23 C C 0 t a > CO • • • Flow rate of each skimmer 10 acfm 5.26 MMACF/yr 4788 Elevation 12.2 psia 4.36 MMSCF/yr Hydrocarbon Concentration 100 ppb Assume Benzene 78.118 MW Total mol flow 11498.66 Ibmol/yr 0.001 Ibmol hydrocarbon (benzene)/yr 0.09 lb hydrocarbon(benzene)/yr • • IllHeater Emissions DCP Midstream,LP Enterprise Compressor Station Dehy Reboller Und Relei 2.51MM81umr . Fuel usage: 0.003 MMsdAY 22.86 MMedlyr OFere ing hours: 8760 hours Fuel Heating Value 958 Btu/WI Criteria Pollutant Emission Calcuations Emissions Criteria Pollutant Emission Factor Data Source (1PYl NO, 100 Ib1MMscl AP-42 Section 1.4.Table 1.4-1(Jul!'1998 revsior-) 1.14 SO, 0.6 IbWMMsd AP-42 Section 1.4.Table 1.4.2(July 1998 revision) 0.01 PM 7.8 lo/MMsd AP-42 Section 1.4,Table t 4.21July 1998 revision) 0.00 CO 8-4 lo/MMscf AP-42 Section 1.4,Table 1.4-1(July 1998 revision) 0.98 VOC 5 5 Io/MMscf AP-42 SeCt1on 1.4,Table 1.4.2(July 1998 revision) 0.06 Non-reportable Criteria Pollutant Emission Calculations Emission DeMlnimua' Hsrardous Air Pollutant(HAP) Emisalan Factor Data Source (ton/yr) (lblyr) $emend 2.1E-03 io1MMSU AP-42 Section 1.4 2.40E-05 50 O;czllorobenzene 1.2E-03 b1MMscf AP-42 Section 1.4 1 37E-05 -- Formaldehyde 7.5E-02 b/MMsd AP-42 Section 1.4 8.57E-04 50 Naphthalene Cif-a4 ISIMMsd AP-42 Section 1.4 6.97E-06 600 n-Merane 1.85.00 IbIMMsd AP-42 Section 1.4 0.0 1000 Polycyaic Orpent Molter TOM): _ 2-Methyinaphtlralene <2 4E-05 i lMMsd P_42 iA Section 1.4 21.74E-07 — 3-Alerhylchloranlhrene <1.0E-00 WMMscf AP-42 Section 1.4 7.08E-08 - 7.12-O nethy10007?8)anrhracene <1.8E-05 b/MMsd AP-42 Section 1.4 1.83E-07 — AcenaphMene 0 1 95.08 DltoiMsd AP-42 SBGioq 1.4 2.- -oa • Acertephfh - ___ yle.ne - <1 85.06 b/MMsd AP-42 Section 1.4 2.065.08 Anlhraoene <2.4E-06 b/MMsd AP-42 Sudan 1.4 2.70E-08 Bertz(e)enfhracene <1.8E-C6 9r MMrd AP-42 Section 1.4 2.055-08 Benro(e)8yrene <1.2E-06 dMMsd AP-42 Section 1.4 1.37E-08 - Berrzo(5)8uorenlhene <1.8E-08 Er/MMscf AP-42 Section 1.4 2.06E-08 — Benzo(9.h,i)peryfene <1.2E-08 IblMMec( AP-4-2 Section 1.4 1.99E-08 Benzo(k)8rr0ranlhene <1.8E-06 lblMMsci AP-42 Section 1.4 206E-08 — Chryserre <1.8E-08 Ib1MMscf AP-42 Section 1.4 2.08E-08 -- OrOertz(a,h)ertMreoene <1.2E-06 Ib/MMacf A-4 Soct,on 1.4 1.37E-08 -- Flvortinfher* <3.0E-06 1WMMecf AP-42 Sed.on 1.4 3.43E-08 -- Fluon'na <2.8E-08 lb/MMsct AP-42 Section 1.4 3.208_-00 -- rrroeno(f,2.3c.o)pyrene <1.8E-08 lb/M1.4.41 AP-42 Section 1.4 2.05E-08 Pherlanlhrene <1.7E-05 OLMMacf AP-42 Section 1.4 1.94E-07 - Pyrene _ <5.0E-08 8IMMacf AP-42 Section 1 4 5.72E-08 - TOTAL POM 1.01E-05 50 Toluene 3.4E-03 2/MMad AP-42 Section 1.4 3 89E-05 1000 TOTAL <1.085.00 1 0.0 -- •Colored°RetoRie,Kkvnbff,3.De MN.,nnsleuels!co Noe-Cool Reoo4uble ociut.10 • DCP Mldalrearn,LP 1 0/24 7201 1 III Heater Emissions DCP Midstream,LP Enterprise Compressor Station Heater Unit Baling. _ 0 BLMMBtu4tr Fuel usage• 0.001 MMedmr 8.86 MMscf ,rr Operating hours: 8780 ho.ira Fuel Heating Value - 958 Blu/scf Criteria Pollutant Emission Calcuations - Emleelons Criteria Pollutant Emission Factor Data Source (tPY► NOx 100 b/MMscf AP-42 Section 1.4,Table 1.4-1(July 1998 revision) 0.34 SO1 0.6 b/MMscf AP-42 Section 1 4.Table 1.4-2(July 1998 revision) 000 PM 7.6 ID/MMsci AP-42 Section 1.4,Table 1.4.2(July 1998 revision) 0.03 CO 84 b/MMscf AP-42 Section 1.4,Table 1.4-1(Jury 1998 revision) C.28 VOC 5.5 lb/MMsof AP-42 Section 1.4,Table 1.4.2(July 1998 revision) C 02 Non-reportable Criteria Pollutant Emission Calculations Ernlsslel5 De Minlmus' Hazardous Air Pollutant(HAP) Emission Factor Dela Source (tonlyr) (lblyr) Benzene 2.1E-03 I5!MM.acf AP-42 Section 1.4 7.20E-013 50 Diddorobenzena 1.2E-03 Ib1MMacf AP-42 Section 1.4 4.11E-06 — Formaldehyde 7.5E-02 IoIMMscf AP-42 Section 14 2.57E-04 50 Naphthalene 6.1E-04 IbiMMaci AP-42 Section 1.4 2.09E-06 500 n-Hexane _ 1.8E+00 lb/MMscf AP-42 Section 1.4 0.0 '•000 Polycydic Organic Matter(POMI: 2-Mefhyinaphlhaletie <24E-05 Ib1MMscf AP-42 Section 1 4 8.23E-08 — 3-Melhytchfo7enthrene <1.8E-06 lb/MI-Aso( AP-42 Section 1.4 5.17E-09 — 7 i2-Dimefhylbenz(e)anlhracane <1.6E-0S blMMscf AP-42 Section 5.4 6.49E-08 — Acenaphtherre <1.8E-06 b/M.Msc1 AP-41 Section 1 4 6.17E-09 , — • ACBneph7nyrene <1.8E-0t3 b/M.Mscf AP-42 Section 1.4 6.17E-09 AMhrecene <2.4E-06 bIMMSCr AP-42 section 1 4 8.23E-08 — Benz{a)anfn/scene <t 6E-06 b/MMscf AP-41 Section 1.4 6.17E-08 — Benzo(a)pyrene <1.2E-08 biMMad AP-42 Section 1.4 4.11E-09 •- - Benzo{b)liuorenlhene <1.8E-06 Ib/MMscf ''AP-42 Section 1.4 8.17E-0D -- Benzo(gh,iiperylene c 1.2E-06 biMMMsd AP-42 Seam 1.4 4.11E-09 -- BertzO(ll)lrlOrenfheoe <1.8E-06 1b/MMcd AP-42 Section 1 4 6.17E-09 .• Chryserre <1.8E-06 IbIMMscf AP-42 Section 1.4 6.17E-09 - F Dibenz(a,h)enthreceria <1.2E-08 Ib/MMscf AP-42 Sedaan 1 4 4.11E-09 — Fiuoranynene <3.0E-06 IbiMMscf AP-42 Section 1.4 1.03E-08 -- _ Flvorene <2.8E-08Ib1MMscf AP-42 Section 14 9.60E-09 — lndeno(1.2.3-c•d)pyrene <1.8E-06IbiMMscf AP42 Section 1.4 8.17E-09 — Phenantniene <1.7E-05 Ib/MMsc1 AP-42 Section 1.4 5.89E-ea — Pyrune <6.0E-08 Ib/MMscf AP-42 Section 1 4 1.71E-0e -- TOTAL POM 3.02E-07 50 Toluene 340-03 IbIMMscf 'AP-42 Section 14 1.17E-05 1000 1rOTAt. <1.88E000 _ 0.0 -- r Colorado RegJalon Number 3.N MNNwa levels fps Non-Cmeal Reportable Pol4snts ID DCP Midatree'n.LP 10/21/2011 • Heater Emissions DCP Midstream,LP Enterprise Compressor Station Heater Unit Rioting: 0.008(MMBlulh' Fual usage: 0.000 MMedfir 005 MMscttyr Operating hours: 8760 hours Fuel Heating Vatue 958 Btulsd - Criteria Pollutant Emission Calcuations Emissions Criteria Pollutant Emission Factor Data Source (tpy) NOx 100 lb/MMscf AP-42 Section 1.4.Table 1.4.1(Duty 1898 revision) 0.003 SO2 0.6 Ib/MMscf AP-42 Section 1.4,Table 1.4.2(July 1998 revision) 0000 PM 7.6 eiMMsct AP-42 Sedibn 1.4,Table 1.4-2(July 1998 revision) 0.000 CO 84 6/MMecf .AP-42 Section 1.4,Table 1.4.1(July 190 revision) 0.002 _ VOC 5.5 SIMMsct AP•42 Section 1.4,Table 1.4.2(JO 1998 revision) 0.000 Non-reportable Criteria Pollutant Emission Calculations r -- Emissions 1 De Mlnimus a Hazardous Air Pollutant(HAP) Emisalon Factor Data Source (tor} JIl r} Benzene 2.1E-03 Ib/MMsc1 AP-42 Searon 1 4 5.672 Dich'wobenzene 1.2E-03 Ib/MMscf AP-42 Section 1.4 3.29E-08 - Forrnaldehyde 7.5E-02 Ib1MMsc1 AP-42 Sefton 1.4 2.08E-06 50 Naphthalene 6.10-04 lb/MMsct AP-42 Section 1.4 1.87E-08 500 n.Hexae 1.8E+00ItIMMsct AP-42 Section 1.4 0.0 1000 Potycydic Organic Matter(PCM} - _ 2-Methylnaphthalene <2.4E-05 lb/MMccf AP-42 Section 1.4 _ 6.58E-10 •• 3-Melhylcboranthrene <1.8E-0O Ib/MMsci AP-42 Section IA 1.94E-11 -- T,12•tJrmethrybenz(a}emhracone <1.8E-05 Ib(MMscr AP-42 Section 1.4 4.39E-10 Ill -- Accnaphfhene <1.80.06 Ib1MMscf AP-42 Section 1 4 4.94E-11 ` Arelaephlnylere <1.9E A6 ID/MMacf AP-42 Section 1.4 1.94E-11 Avthmcene <2.4E-06 Ib/MMsci AP-42 Section 1.4 8.58E-11 — Brnz(e)an(hracgne <1.88 6 Ib/MMcc( AD-02 Section 1.1 4.94E-11 8enz0(a)pyIene <1.2E-06 Ib/MMsct AP-42 Section 1.4 3.29E-11 -- Benzo(b)9uoranlhene <1.8E-08 Ib/M41act AP-42 Section 1.4 4.94E-11 -- Benzo(g,h,Qperylene <1.2E-06 Ib/MlAsd AP-42 Section 1.4 3299.11 -- Benzo(kyluoranthene <1.8£-06 Ible4Msc1 AP-42 Section 1.4 4.94E-11 - - Chrysene <1.6E-06 Ib/MM{CI AP-42 SecliOn 1.4 4.94E-11 -. Otenz(a,h)anfhracene <1.2E-06 Ib/MMsd1 AP-42 Section 1.4 3.29E-11 -- Fluoranfhene <3.0E-O6 Ib/MMSM AP-42 Section 1.4 8.23E-11 -- Flu orene <2.8E-06 Ib/MMecf AP-42 Section 1.4 7.68E-11 -- lndeno(1.2,3-c,d)pyrene <1.8£-08 Ib/MMsd AP-42 Section 1.4 4.94E-11 - Pbenanthrens <1.7E-0S tbfMMsc1 _ AP-42 Section 1.4 4.68E-10 -- Pyrene <5 0E-05 ib/MMsci AP-42 Section 1.4 1.37E-10 _ - ' TOTAL POM 2.42E-0D 50 Toluene 3.4E-03 Ib/)rtisd AP-42 Section 1.4 1 -Oe 10% TOTAL <198E+00 t 0.0 — 'Colorado Rapids:ion Number 3.De Minima levels fm won-CrIena Repotsak Po clar4S • DCP Midstream.LP 1012412011 I• Heater Emissions DCP Midstream,LP Enterprise Compressor Station Heater .V lit Rating: 0 0061MM:thi7M 0 000 MMacf/hr Fuel wage: 0.05 MMsct/yr Operating hours 6780 Pours Fuel Heeling Vak e 958 Btulect Criteria Pollutant Emission Calcuetiona Emissions Criteria Pollutant Emission Factor Dale Source (tPY) NOx 100 IhrMMsd AP-42 Section 1.4,Table 1.4-1(Jlsy 1998 revision) 0.003 SO2 0 8 Ib/MMsd AP-42 Section 1.4,Table 1 4.2(J.4y 1998 revision) 0 000 PM 7-6 b/MMsd AP-42 Sect r1 1 4,Table 1 4-y().sly 1988 tevifi0n) 0.000 CO 84 Ih/MMad AP-42 Section 1 A,Table 1 4.1(July 1998 revision) 0002 VOC 5.5 b/MMsd AP-42 Section 1.4,Table 1 4-2(J-ry 1998 revision) 0.000 Non-reportable Criteria Pollutant Emission Calculations Emiselons Ds!Animus' Hazardous Alr Pollutant(HAP) Emission Factor Data Source (tonlyr) (Iblyr) Benzene 2.1E-03 InlMMscl AP-42 Section 1.4 5.76E.06 , 50 Oichlorobenzene 1.2E-03 10/MMsct AP-42 Section 1.4 3.29E-00 - Formel0ehyde 7.50•02'O/MNIsd AP-42 Sedron 1.4 2.06E-08 — 50 Naphthalene 6.1E-04 Ib/MMscl AP-42 Section 1.4 1.87E-08 500 n-Hexane 1.8E+00 Ib/MMacl AP-42 Section 1.4 0.6 1000 Polycyclic Organic Matter(POM): 2-Msi�phthelone <2.4E-05 blMMact AP-42 Section 1.4 8.58E-10 •- 3-I.MthykbloraMhrene 41.8E-08 6IMMtct AP-42 Section 1.4 4.94E-11 -. 7,12-Dimerhylben2afanlhracehe 41.8E-05 I lMMsd AP-42 Section 1.4 4.39E-10 - _ Acenaphlnene <1.8E-08 blMMacl AP-42 Section 1.4 4.449-i l -- • — ACenapofhylene 41.8E-06 b/MMsd AP-42 Section 1.4 4.94E-11 Anlhrocene 42.4E-06 bIMMaof AP-42 Section 1.4 8.58E-11 Benz(a)anrhrsCene <1.8E-08 PoJMMscf AP-42 Section 1.4 4.94E-11 8enzo(a)pyrene 4 1.2E-06 lb/MMad AP-42 Section 1.4 3.29E-11 - _ Benzo(b)/luoranthene ^ 41.8E-06 IbIMMed AP-42 Section 1.4 4.94E 11 - Benzo19,h,l)peryfene 4 1.2E-06 IWMMsd AP-42 Section 1.4 3.29E-11 — Benzo(k)8uoranshene <1.8E-06 lb/MMsd AP-42 Section 1.4 4.94E-11 - Chrysene <1.8E-06 HAWKS AP-42 Section 1.4 4.94E-11 -- Llibenz(a,h)anrhrocene <1,2E-0¢IblNTA AP-42 Section 1.4 3.29E-11 — Fluoranrhene 4 3.0E-06 IbIMMsd AP-42 Section 1.4 8.23E-1! - FtuOmre <2.8E-06 Ib/MMsd AP-42 Section 1.4 7.88E-11 •- lndeno(1,2,3c,Opyrene <1.8E-06 Ib/MMad AP-42 Section 1.4 4.94E-11 - Plrener4hene <17E-05 Ib/MMsd AP-42 Section 1 4 4.68E-10 - Fyrene <5.0E-06 Ib/MMsd AP-42 Section 1.4 1.97E-10 - TOTAL POM 2.42E-09 50 Toluene 3.4E-03 IooMMacf 'AP-42 Section 1.4 9.33E-08 1000 TOTAL 4 1.88E+06 0.0 'Cobre4n Repul.11w Number 3.De 4iIw k.4M(Si Nor.Crterie Repairable Pozu,iN1 • DCP Midstream,LP 10/24/2011 Enterprise Compressor Station • Compressor Blowdown Emissions DCP Midstream,LP Carbon Dioxide 44.0 2.647 1.16 5.57 Helium 4.0 0.006 0.00 0.00 Oxygen 32.0 0.000 0.00 0.00 Nitrogen 28.0 0.294 0.08 0.39 Methane 16.0 77.493 12.40 59.33 Ethane 30.0 12.696 3.81 18.23 Propane 44.0 4.621 2.03 9.73 i-Butane 58.0 0.571 0.33 1.58 n-Butane 58.0 1.077 0.62 2.99 i-Pentane 72.0 0.217 0.16 0.75 n-Pentane 72.0 0.203 0.15 0.70 Other Hexanes+ 86.0 0.000 0.00 0.00 n-Hexane 86.0 0.175 0.15 0.72 Benzene 78.1 0.000 0.00 0.00 Toluene 92.1 0.000 0.00 0.00 Ethylbenzene 106.2 0.000 0.00 0.00 Xy�leunhhe� s 4 ff 106.2 y0.0��]00 jyJ0.00 µy 0.00 .�Q1.4110, 5.,, "T+4/` lS ft'�Wi al. �N'Ml a .:Tr fang • VOC wt% 16.47 % Methane Wt% 59.33 % CO2 Wt% 5.57 % Volume @ 60 psi 3425.8 cubic feet/event Vent ton/blowdown #/yr TPY VOC P018 0.094 12 0.19 C235 0.094 12 0.19 C236 0.094 12 0.19 C238 0.094 12 0.19 Total 0.75 T1 Blowdown 0.094 12 0.19 Turbine T1 blows down to a separate vent. • SITE BLOWDOWN • Enterprise Compressor Volume Measurements Unit HP 234 3550 235 3550 236 3550 238 3550 Diameter Length Pressure Volume Qty In Ft psis cft C-234 N (P-018)/2Q6/236/238 Inlet Piping 1 13.0 37 80 219.3 Disch Piping 1 4.6 97.3 80 71.8 1st stg to cooler 1 13.8 63 80 418.6 Cooler to 2nd stg 1 8.6 144.3 80 374.5 2nd stg to cooler 1 6.9 76.3 80 126.7 Cooler to 3rd stg 1 6.9 65.3 80 108.5 IC-1 Tubes 54 1 48 80 91.1 IC-2 Tubes 66 1 48 80 111.3 AC Tubes 53 0.75 48 80 50.3 1st Stage Scrubber 1 48 6.16 80 498.7 2nd Stage Scrubber 1 36 6.8 80 309.6 • 3rd Stage Scrubber 1 30 6.7 80 211.9 1st Stage Suction Bottle 1 30 10 80 316.2 1st Stage Discharge Bottle 1 24 10 80 202.4 2nd Stage Suction Bottle 1 24 6 80 121.4 2nd Stage Discharge Bottle 1 19.2 6 80 77.7 3rd Stage Suction Bottle 1 19.2 4 80 51.8 3rd Stage Discharge Bottle 1 19.2 3.5 80 45.3 1st stg Cylinder 3 14.4 0.6 80 13.1 2nd stg Cylinder 2 10.2 0.6 80 4.4 3rd stg Cylinder 1 7.8 0.6 80 1.3 NOTE: All streams routed to the front end of the plant until they are down to 80 psi. 3425.8 cft 3.43 macf • Monthly Meter Analysis DCP Midstrear January, 2010 • 212950 ENTERPRISE DISCHARGE 10 Total C6 PIS. Component Mole% GPMs Mass % Property Sample Fractic Carbon Dioxide, CO2 2.6470 5.5615 Pressure Base 14.730 Nitrogen, N2 0.2940 0.3932 Temperature Base 60.00 Methane, Cl 77.4930 59.3511 HCDP @ Sample Pressure Ethane, C2 12.6960 3.4061 18.2255 Cricondentherm Propane, C3 4.6210 1.2771 9.7280 HV, Dry @ Base P,T 1210.02 iso-Butane, iC4 0.5710 0.1874 1.5844 HV, Sat @ Base P,T 1188.84 n-Butane, nC4 1.0770 0.3406 2.9885 RV, Sat @ Sample P, T iso-Pentane, iC5 0.2170 0.0796 0.7475 Relative Density 0.7258 n-Pentane, nC5 0.2030 0.0738 0.6992 Fws Factor Hexanes Plus, C6+ 0.1750 0.0766 0.7200 Free Water GPM Water, H2O Stock Tank Condensate Brls/mm Hydrogen Sulfide, H2S 0.0000 26# RVP Gasoline 0.334 •oxygen, O2 0.0000 Testcar Permian 0.562 Carbon Monoxide, CO Testcar Panhandle 0.501 Hydrogen, H2 Testcar Midcon 0.503 Helium, He 0.0060 0.0011 C4 and Lighter ST Cond Argon, Ar C5 and Heavier ST Cond C6/C7 GPM Totals 100.0000 5.4412 100.0000 Sample Date: 12/01/2009 Pressure: 850.9 Type S Temperature: 86.0 *** End of Report*** . • Enterprise Compressor Station Summary of GHG Emissions DCP Midstream, LP Sources . CO2e Combustion Sources 88,682.5 Blowdowns 70.9 Rod Packing Venting 3,266.72 TEG Dehydration System 53.27 Total CO2e PTE 92,020 • • DCP Midstream,LP 10/24/2011 ID § $ § v / § - % / CO Co Co ~ 3 \ \ 3 0 n (/) m 0I. O 2 E L0 CO U a 0 \ CO 2 q a .c \ -J f [ — & / 6 / / / \ / w \ 2 6 co. / 0 § ^ q 0 CA \ § . y i '[ a • / ' m w 3 E 2 / q q / k N 0 CO N § & co N 2 2 E t E / / _t -$ 7 2 C) 0 0 o 7 2 } $ 2 2 % t ± --cr) e 6 6 ® , MC0MMC0M0I OO=M L 3 ? 22222 2 � 2 m = 2222222 I m I . . = o o o o o n o o 0r--co Loco/ F O o 0 o w 10 c o n n e N (N (N (N � ~ � / d $ / \ / \ . + c 2 J I o -cao CIS ,O .4 .4:1 / $1, 0 J 8 w « k ■ �_ / \ k \ \ i ■ ■ 2 2 3 # E C { 0 _ / I LL _ \ / / E a E o k $ \ & % § 5 @ n@ $ $ §ID , k / I \ \ \ / / \ / 7 13 a \ 0 u_ _ [r it « } : o : f .- - - O it. Li_ § / L. .,2 I f m m a 0 t o 0 0 0 c2 § O = t E E C E— $ ~ 0 0 f - O O i a_ IUo u_ a. u & LIRCC $ za. a. 3 , oZ' O § • Enterprise Compressor Station Compressor Blowdown Emissions DCP Midstream,LP �r1aul9 tit �°� 1, 3₹�ey • S*A a?IM b1.ib" OltiV 1 0 D'.1 ?. Carbon Dioxide 44.0 2.647 1.16 5.57 Helium 4.0 0.006 0.00 0.00 Oxygen 32.0 0.000 0.00 0.00 Nitrogen 28.0 0.294 0.08 0.39 Methane 16.0 77.493 12.40 59.33 Ethane 30.0 12.696 3.81 18.23 Propane 44.0 4.621 2.03 9.73 i-Butane 58.0 0.571 0.33 1.58 n-Butane 58.0 1.077 0.62 2.99 i-Pentane 72.0 0.217 0.16 0.75 n-Pentane 72.0 0.203 0.15 0.70 Other Hexanes+ 86.0 0.000 0.00 0.00 n-Hexane 86.0 0.175 0.15 0.72 y75 i^' +5b�2i.,�n` a .��`i''�"�t+�;�i-.,`3'S.mS�:�,'` fau �'�a o negoVek.�' Y�s"'�v, MICS n"^,r' VOC wt% 16.47 % Methane Wt% 59.33 % CO2 Wt% 5.57 • Volume @ 60 psi 3430.0 cubic feet/event Vent ton/blowdown #/yr TPY VOC TPY Methane TPY CO2 TPY CO2e P018 0.094 12 0.19 0.67 0.06 14.2 0235 0.094 12 0.19 0.67 0.06 14.2 C236 0.094 12 0.19 0.67 0.06 14.2 C238 0.094 12 0.19 0.67 0.06 14.2 T1 0.094 12 0.19 0.67 0.06 14.2 Total CO2e 70:9 • DCP Midstream,LP 10/24/2011 III ` ` ~ oi £ cr � �4. \ \ - O CM / � f2 \ « 2 © ) in$ \ 0 - co tai ® N IN ) k \ \ � \ w ) `$ f * 2 - E2 :- 0) fl.12 CU p) % @ ) 2 / O) co 0 cc ) ) ) ; C , \ \co § ct \ \ / 2 > $ & E ,Z3 -E-. a / $ § t = ttt In + / f �kk 000 w aC0 29 ; ; r ea ; # = ef22 4.1 0 • ] a. k00a. all (X 0 n a m o • w S p a e u ' .0 w ti 00 C 7.3 v d ao I- o ID v ✓ ;I- I ' a a S I°- N a LA N m m In N 00 O V o y L a 3 'W N a N Iv 3 T N a O O O O ti • c A N d o f N O N >' M N O P.- (.., - .y C N E ° 3 a 1p a° a O to a >-o a o'. 'a C E I- tai 2 N = r O < • C '^ 0 W N E N i... w 13 °„ • " aa t o. v E aO � cwto T N O 1 E , E = ; co ., S a. U° oi to c E = regl d 9.N E E N L O m • C y w v .. �aa > t N W II-- O vI VV• 2 - u • Appendix C Diagrams • Enterprise Compressor Station Process Description The Enterprise Compressor Station classified as a natural gas compressor station as set forth under Standard Industrial Classification Code 4922. The plant uses four(4) gas-fired internal combustion engines to drive compressors to boost the inlet gas pressure from about 80 PSIG to about 1,050 PSIG to facilitate movement of the gas in the pipeline. All four(4) engines have individual stacks to vent the products of combustion. A 10,142 HP Solar Taurus Turbine will be installed as part of this modification. The turbine will also run a compressor. The station also includes a triethylene glycol (TEG) dehydrator unit which contacts "lean" triethylene glycol with the inlet natural gas stream to remove moisture. The "rich" glycol mixture is regenerated in a still for reuse in the process. The still vent exhaust stream is sent to a flare where it is combusted. The TEG dehydration system operates with a flash tank. The flash tank emissions are routed back to the process. A condensate product is generated when the inlet gas is routed through the inlet scrubber. The condensate is transferred first to a 30,000 gallon pressurized storage tank, then to a stabilizer tank to remove any volatile material, and finally to four(4) 300 barrel atmospheric storage tanks. The atmospheric tanks are controlled by a combustor. A loading system is provided for moving the liquid condensate material from the tanks into a truck for transport offsite. The facility is located one (1) mile north of US Highway 76 on the Gutterson Road between the towns of Keenesburg and Roggen, Weld County, Colorado. • • ENTERPRISE COMPRESSOR STATION • 55 En nkIse GS. 40.1910-104.4877 • ,.,,Tampa 398 57 _ — _ / 55 IL.-.20 - 59 8 20 - I I/, >, - y 1 I I P " 78 ' 96 =18= 18 �I 1-78 Exit 3 1. 5 6 ,. 57 59 53 55 III61 - -I - - _"I - - I• 0 m 0.5 1 1.5 2 2.5 Copyright©1988-2002 Microsoft Corp.and/or its suppliers.All rights reserved http//www.microsoftcom/sheets ©Copyright 2001 by Geographic Data Technology,Inc.All rights reserved.©2001 Navigation Technologies.All rights reserved This data includes infamalion taken with permission from Canadian authorities©Her Majesty the Queen in Right of Canada. ) •_• / N • ) O4 ) §E \ f A Q ■ 3 ) § 01. ( 0 0w J « 7 ) •' • kv r ry « Co ) § oC 2 2 I ) ° I. 4- ) ( U § ) j tto C J ) V) rn\ J - o ► \ 2 / \ \ C \ a ( { 5 0 ; iI a� ii g oil V; bs 4 l 1 • . Ir _ ll!!1iii!'i1i s • I1iii z " 1 Z+.a L ;_ l # d oi H F y N 4F.Fl I t5!r I:ii dial":Hirlig is 4 t� N I . . . hill Illibilillit qy — g i a�e a � °�S '5 1 i II- I i14wfttit gib ok VI _j ,.. oi ii I ,, I � , , , .�. � I�,�>> 9 Si it ' • J 1��' j itz ` is �IJ ,=rnoo� 4 g \,__- c ! . 0 a xz•fla l I ill i ° ., I•x,1, • •�.I. 11131003I V 4 � Y Y • 33ft,0 • V• Z `. /Q/Q ! ,1 ! I : tt�-��--35 S i "V- -- ET WW - i � 31.1:n'' 1 - ' oii�ir::. § I k 5 1 WE!L RRue ] \i a W tz .ii• : ar s t I 1 . • MI i 0 ' L 10 — ' +Nil Pi r Ori1.91108---•----•- '' C i S y — a a 8 . t 1 I'll 9 6 g Als r bi+ ;I° .I.. • Appendix D Regulatory Analysis • ENTERPRISE COMPRESSOR STATION REGULATORY ANALYSIS 1.0 Federal 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 major sources with respect to Non-Attainment New Source Review (NNSR) if emissions of NOR or VOC are in excess of 100 tpy. This facility emits more than 100 tpy of both NOR and VOC and therefore, is a major source under NNSR. However, this modification will not result in an increase in NOR or VOC emissions of more than 40 tpy, therefore, this is a minor modification with respect to NNSR and will not trigger new source review. 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. This facility 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. 75 Fed. Reg. • 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. In this case, the proposed project is not subject to PSD review for any criteria pollutant; therefore, GHG emissions from the project are not subject to PSD review. The emissions of CO2e from the facility (approximately 92,020 tpy), which is less than any Step 2 period GHG permitting threshold. 2.0 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 hazardous air pollutant (HAP), 25 tpy of any group of HAPs in the aggregate, or 100 tpy of any criteria air • pollutant. This facility is a major source for NOR, VOC, and HAPs and currently operates under Operating Permit 95OPWE103. • Regulation No. 3, Part A, Section I.B.44.e specifies that beginning July 1, 2011, GHG emissions shall be "subject to regulation" under Title V operating permit requirements if a new or modified stationary source will emit 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"). This facility, does not emit more than 100,000 tpy of CO2e, Title V does not apply to the GHG emissions from the project. 3.0 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." No steam generating units with a design heat input capacity in excess of 10.0 MMBtuthr are located at this facility; therefore,NSPS Subpart Dc does not apply. NSPS Subpart GG, Standards of Performance Stationary Gas Turbines (40 C.F.R. §§ 60.330 to 60.335) Subpart GG applies to each all stationary gas turbines with a heat input at peak load equal to or greater than 10 MMBTU/hr,based on the lower heating value of the fuel, and constructed, modified or reconstructed after October 3, 1977. Turbines subject to NSPS ICKKK, are not subject to NSPS GG per § 60.4305. This turbine will be subject to NSPS KKKK as explained below. 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 storage • tanks at this facility are either pressurized or have a capacity less than 19,800 gallons; 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]. This facility does not process natural gas and is therefore, not subject to Subpart KKK. 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 engines at this facility were constructed prior to July 1, 2007 and are therefore not subject to Subpart JJJJ. 40 CFR Part 60 Subpart KKKK- Standards of Performance for Stationary Combustion Turbines (40 C.F.R. §§60.4300 to 60.4420) Subpart KKKK applies to stationary combustion turbines with a heat input at peak load equal to or greater than 10 MMBTU/hr that commence construction, reconstruction, or modification after February 18, 2005. The turbine that will be installed at Enterprise Compressor Station will be a new turbine with a peak load greater than 10 MMBTU/hr and will therefore be subject to Subpart KKKK. This will be a new turbine firing natural gas with a heat rate greater than 50 MMBTU/hr and less than 850 MMBTU/hr. Therefore, it will meet a NO„rate of 25 ppm at 15% O2. All of the required testing, recordkeeping and reporting will be completed as specified by Subpart KKICK. • • 4.0 National Emission Standards for Hazardous Mr 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]. This facility is a major source of HAPs. The TEG unit is the only source that is potentially subject to any control requirements. However, the TEG unit at this facility is exempt from all major source requirements as stated in §63.764(e)(1) since the criteria in paragraph §63.764(e)(1)(ii) are met, but DCP does maintain records as required in §63.774(d)(1). 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. As a major source of HAP emissions, the engines at this facility are subject to Subpart ZZZZ and are currently maintaining compliance with all requirements. 5.0 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. Eight APENs are included in this application. All of the heaters are this facility are less than 5 MMBTU/hr and are therefore APEN exempt per Reg 3, Part A, Section II.D.1.k.. Regulation 3, Part B Regulation 3, Part B describes the requirements for Construction Permits. DCP requests one facility-wide construction permit for the proposed changes requested in this application. Regulation 3, Part C Regulation 3, Part C describes the requirements for Title V Operating Permits. The facility is a major source and currently operates under Operating Permit Number 95OPWE103. The changes will be rolled into the operating permit with-in one year of construction permit issuance. Regulation 3, Part D Regulation 3, Part D sets forth PSD and NNSR requirements. The facility is not a PSD major source and this modification will not trigger NNSR as discussed above. 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 XII 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.1.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. 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 natural gas dehydrator at this facility is controlled by greater than 90%. • Section XVI specifies emission control requirements applicable to portable and stationary RICE located in 8-Hour Ozone Control Area. The compressor engines are controlled • with selective oxidation catalysts • 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. • • • Appendix E APENS, Construction Permit Application, AOS and Minor Modification • 1. 0 9 ti v 2 0 O h o o c w Y O O E ....... o. 'p �, p r— a r d z.� j - - - 0 c c _ o O T E O p Mtn Nl 50- v 4' O o Z ` 4E °' e _ C' rna € " a 'c ❑ .) a. 7 - q U O b '0 b O ria 'o O ry 3 d c p N E ° o a W U 0 00o E `o o 10 61 i a. d �DI ° a c y E a c . u ? °-yQ v N W `' ., a j € o LUi E m = a u, m ,o = e d .S oi dS a al a U u v ° ° E y „ S N s ws. °' Q c v x z O M c v a 3 = m € A 0 y L d m C 0 0 U N a ° Y E o m a E v •E c 0 ,. o c N � 0 6 •a b 0 r a+ aui '�- d a ._ .O a e h s C y.. Y s a w N -� 0 o a — C 3 ° Y S E N o 0 p v E u, v w e w U P.t 0 i, o f a s 0 Co v — y a - id u w 444 64 c CO fi z 1 `0 K '6 a d C .o c o E 0. Oy rn £ Na. -0 3 € V1 = d U F ai m o E m m m .- > .o, 3 o e v > v 3 3 o d U- d d o `° d c ` " s° `° .o W o .° v ° e;o u p o p s 3 .. o co r •E I. y ❑ ❑ ,o Y � .3 co .. a cob 2oi .0 eE dv F -20 � � 00 U L 'C ca N ,C v o' Ca a s m u .0 - c 10 s p d > �... Tot U o c o y o o Li O a , d « L y _T CPt) u 0 d Y 9 c W 0 Ea + " T CC O C O y 'al Y Y .� d o D ..+ e z a .. e z `� a E J. La C n '.°- C N i O o .y 00 C 0 0 O 'E . O ° 0 4p1� E •E C 0 o 0 � .0 cc U a a o a° ' s s h 5 d v W F 0 . 0 m , ¢ a c .e U G •`� ,..4 p o a �0 0. m Z .� U U ai w 'rte- .p a .4 U o " d 'o o E co) m 2 's 0 •-- s-. c a o y o 2 o E w a ®® I+ 8 3 m 3 d W v I o o cc >. 0 d v F v :. �" Udvp �. dm d d r W u 0 Z O O 00° 0 E w 0 0 o o ° d o y, a ' 1. `o. a. L L .. d d -a .°E ° co ^c ° v 3 °0�° d _ y a`1 al d U U y - CL 7 d v U 0 o 5 E 0 C = e rg . d d v o v n m o V C E c a s C ❑ ❑ C C ❑ ❑ Z . dS •• c oo ❑ o u A a 'a ° s �° o ° o y o xF y a yODD O ❑ d .c. z el 0 el -2 z Nm ❑® I F ° .. o V v O0 a• o S w0 cc $ d x c m O E z s Cs Tic �. '8 a o r. E o m d o �o., co m 0 EA a ,e o 8 o Y a v) 8-El r C a z a o N 7co C ~ r N c O H9 a o O 0.1 o s el ON 3 a co e $ WI ® 0 P. 8 8 Q col ' 0 'o c o n M W C a. c0 za D U U U _� a �i �i 3 c d 2 @ @� o^ o ft a _ Q O a U .0 .0 w T o co 'D° 's N E a a 'x Z 6'i W z N N N 9 C O C W CO m CO V d o z z O O M L am Y a C C N y CI •F V ❑ ❑ U N C (-) 2 Y en en V 1.16 an V0 09 Fy - O F C N 'Si 0 Q O U C a E O d ,�, s I- o t _ 3 0 > o ° v Z o 3CO N c E oa = 0 a 0Las '� E N N Z N N C L ❑ co e N E C M e m a e co m e r al o v U .a rj O ° e Z N E 'o OL. a. C 5 LLI ` •e �' o `o c 0 0 F W a o m e a ° o m e U c o si d .� e c.G c 'o Z oo ii L U •°- 41 m o E on o• o _c �o w ?, o .E m s e °' h u ` O °u' a to o c c .o c `� U �2 a a c o .c o Oac t a� ° ;? a U 'y N V) '° col A0 CO U C m 'O ~ 0. o 0 .� O O .0..it ti H U o o W C N _ 2 p W m en p 3 3 y o °c.) 6. )- T)i• o f C o ❑ ® E E O ❑® E �' 4 c d Nel co 00 oc ca as Coc i� g u C W A 5 'O u ti 'co ti y F. y 4 ° 3 3 r c E E Q, V d E m v c o n. o v E W c v, rn v c G� 8 ,a c 'a .� o m -t, o c •o I eee°pqq 'C c c •,a u I o •° o E E .y me z W or O °v' J 0 E d y U d e 1 0 0 4 v 0 3 C m o C E 7 co v) s' 0 c' o E x = oc_n E C v c 2 F F .i -3. o c ,c a c v .° � et ad W a :ro •� U vi 0.o "c W y p € v A m d m m c o co .E4 s g p.i w h m a Z O O O 3 " z ui 2 m 2 2 m U 1° C > •C a S c O .c 0 c ca It V, OB aJoi ..I O. P U k% O �tl t �d 6N, pN,, pN..,, O.N x E 4 N o c a o ,g O g Q 6 6 Q a+ = 0 n p odd a q° , E '£ �' � `. w2 on m C7 ¢5 ¢ W u d E` c.=6: li o w c W ,0 U Cc om C7 : 4 - 0 CI)• W o das m 8 d . ° e W r, it Lc co- 0 O _ = 4 00 0 N M V N 0 0 0 4.1 a .C r 0 V a .-. W @ ro U v 0 v _ H "° .a 4 ore d 0 E m H o (Q OD O U O b N a• P L c or O 6-) s a : :: ;7, v o O O r .g s H ' m L E -°. _ d ell oA c .. `o t « N k' O W O 1 O co" O m e in ai b O p Z o a '� aui u o �' o r n oo N o a C ~ j d e a u GO i N N ONO w 0 0 0 n {i C - n E ° F C cli as 40 c R M LI `2 :' i ° a •u • N 4 so a.ice. d eau h , r NU '•_.I ^C d C. C c ow ti ..w A eyJ .o ,a-o 00 '' O 0 cc0 -' « d ^ _" to or C . E ,-,-, 6:-. ''n C C x cn a X36 s o .5 = N w ° °I 3 ro 0 O LL U Fi C E ❑ .°� JW LI .. c d v • v ,c on,= } C g v c m O 2. N I. oa m E L 0o .E C1 0 c a .-. E o a O 0 O C' cc 'a x W ao r °' = `ro ,O, y « a iz Vj x r to o ;? v v .o ONE ee �C t 'i. E u o o Q� O O v 0 0 W m o c 1' O '� O az e B c c F S ? m a h• W 0 z oeo oo ❑ = °�' .E x o O c U U' E L '"O u a 'b . CD N O N al 3 3 J jl L L L L �' v. cc 0! l`d w0 • C .o Q W Sr. U 3 a b. d b. Pal E PI cE m '3 0 Z N M 4 ti `k° d 7 E E E _ � A ,d o s a pa a q v ° c 9 �" ! o c `o tae e� e� boo a a a 'o r a ▪ L E E e z e — a y a b e CO C 'o v Q N O = ti a .<112 C G C 'G N 0 •aEi O .� °' °' c w�. a0 u ® ev T m m o --- ...,c � V) 8 e p U 0 y y u.4 N. V� 0 0 0 0 0 0 p C I� L1 • N N F :i 4 Y� q� O 4Ac o; O `D N O V V' O a C •.: NW _ v H U to 0O in a .` O C i• a'y Z C To' c a C a u y E N m ° E o u e c o ro w • v U v c„,.; } C 0 •` c L. Q a 0,) c'', u 0 N }' 0 m U ti O 41< `. e } •u = ca A U ° e G 0 — « 3 U c a c .o c o f V C ✓• Co 3 w IS 'c c es r• OCT) v e e e o o L ti v: ¢ Q W C U tr..,- a4 oo Vi in N Q c a F� N Z Cl- v y To U— P. QoN y .9 Q ti 0 v • O cc 'S o C v ." u " T m a ,r h o u C Z' m a a .... Cn r/� i° ° ® .. ie o o E o .0 OS 0 a o CA E 'a ° SO I:, y A > > C L oo s m v° a o ° y "" v lao � ._ C N -8 <v O fl .. u C (d m U a �" = u rn c W Sr c & to u C C N . 6 c 0 c .° C Co F�• Z g �•°° ° a y, 0 A � in ° ` 0 � ." - e3 �' = °4 rn N m d E ° co, w LI a m m 3 L .LJ o p t0 C C C C C �v () id L. a LC. C 0 v v g c 3 C o C E C A m m m m m ° 0 - • oo — Co O W C , o U U V U U U 0 y O .-1 Y >,o r o r U 4 'y g U o' K X K X K ,e .� E u C L4 W�- a y a) ' ea ` 0 0 0 0 0 0 E °m VI (c-4 C Q. {L — .] o • V] h E W v C °' W c es c o4 Q Q. Q O m u ° co •E 'n 0 v 'J U O [E ° ' 1 r c x U O t v `2 u n O L O N om � a v z o ii C C c F a a' O O U U € �c' LI c.4 4 m o c X W y C.. 0 W avi 1= a ® u°. 0 v J f ►_ I 13 co > p W .a O �/ O Q • '6' to Q oo aci 0. ti U y U) M CD N I O F.----- O E — Z N U0 w Co N Lii M Si-aTO 6 ❑ N aa)) V t © N a) s Q .. Z co a (n Q L ca r` b " t' I a A W .n ti Lc) Q < C° w �o U O t� V E N4 0 r r C -y � O QJ 7 v_) I F-- Z 0 0 E E O o -0 co co w o c Z TD A A 7-4 iX > CO ch c `o' U 111 a Q c m O a L U) v, `g 0 O (.1) o E E w (a p to H 2 '" z z z u_ ° LL .c c cC p O _� t V :N O ›- I— a A �i a L iii a � 0E I To U E = U 0 w v C J _ -23 Q a- �• o o o Ev cp a o. -, o U Q N W �' > E' N U) J , CO o � z p Ca Cr O H ° a - U cp Ce H E o ? QI n O a 0 (1)) cam O (n CL J C) -O L�L/I E o 7,5 N O LL C'? L c) N V — I o N N _ E c •Q w "0 -0 a) '_' Q I .� Et z c L LI a u) a) _ �a a) o a co I N � > Ce a) p u) 3 73 r m J `°`. CT U C V Cl- Cl)0 Z d a) co r- CO cc O 'n (0 O O a) a) a Co o 0 E z .2 U L 2 � cn o z A U 2 U (n 7 p 0 a) 96 J C .11:t) aai v Z O) I .— =- >' o Q .� 0 ', L cN ( O) O (0 Cl) N E c e E U Q ch o E a O a W < o , ' Cr c z •.� L 0 4 b In v tE 6. _ in ';r o a = Q a 3 d a - v, .r ``-- 'e E ° o a O in E 1.7.1 U MMM cyF 'C 'V .ten lip .".- « o o a. a it . h�v Q g'o to 7 O e' Cp 4�! 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[g NIO z v". h oD aEi v Q m o m $ m c c `� O c a, .O'i u cc�r.V C) G tt P. Y ty `�' z = UO n 5 v ; r a o. e 2p3 ,� a „U •E• c w c a b o o o > ,`, o r '' s c 'o o m "47 .o Q ._ v, o m a E• m �' . c. m r. z X ¢T 'G G deer- DCP Midstream 370 17th Street,Suite 2500 Denver,CO 80202 • Midstream. 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-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 SUBJECT: Enterprise Compressor Station Operating Permit 95OPWE103 Minor Modification Mr.King: DCP Midstream,LP(DCP) is requesting a change to the language in to the Title V Operating Permit 95OPWE103 for the Enterprise Compressor Station(Enterprise). The December 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 G 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. Additionally,DCP is requesting the administrative correction to four compliance emission factors for engine P018. The compliance emission factor of NOX is currently 0.29 lb/MMBtu. DCP is requesting that this compliance factor be changed to 0.2293 lb/MMBtu because using 0.29 lb/MMBtu at 8,760 hours of operation would cause an exceedance of the emission limit. DCP believes that this • factor was a typo in the operating permit. Further, the limits on CO,VOC and formaldehyde are . rounded to two decimal places. By rounding these emission factors to two decimal places,there is a possibility of slightly exceeding the corresponding emission limits at 8,760 hours of operation. DCP is requesting the CO emission factor be changed from 0.06 lb/MMBtu to 0.0587 lb/MMBtu; V0C emission factor be changed from 0.33 lb/MMBtu to 0.3258 lb/MMBtu; and formaldehyde emission factor be changed from 0.03 lb/MMBtu to 0.0261 lb/MMBtu. These numbers will result in the exact emission limits at 8,760 hours of operation. DCP is requesting these changes under a Minor Modification to 95OPWE103. 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). Joseph Kuchinski Vice President,Area Operations North Printed or Typed Name Title Sigtaturbsponsible Official Date • • • .. 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HARCf f, T r, l[[[[[l ySATURDAY PICKUP I E- TRncKIriUNur'eeP 13, F4b}.9;15•37 1 0 D 1 144 7 n d $ , I'll � ONTO Q i SHIPMENT.FROfd _. -- INSURED VALUE $ $ f' inrae c, tl• CGDINT lb OPT ICES: $ SERVICES ❑ e AMOUNT 1S1 v ' ( ; a F 4 6 9 1 5 ❑ C.C.D. $ ��' "EFERENpCE NUMBER a tw!.-%' .._ -___ G ! 3 J i AMWNT r 4 'r", 5 AP JIT'f 1. (-7 Ant------- tt Q₹ ', ( 3; NAME t _. , `T£IFPRbNE 5 '1nlA1BE I I y b1t $ ilk ff��, \\\epL !!1r'PQQ .�. .. f( ('+O-39 Y LHA G6 �' l�Y C� i�i � 'W3'VD III ttAR ��.:N �� sT .Y rt+d Q!5 I MPANY cc; t. O) k._ -- LNAH4W (:: �4 > l( fgxx' 't,$ gin `DUK.ENERbV li b SERVir.§.iNc ripillit:s41h1 .•'- SH�WER RECOVER B PAq IM CCU ATAnP�B tItYCREL'1f 1 STflEEMAbDRESS reErRoo DImhL4b7TH T -2600 T ❑ ❑ Via. ❑ 3701 S. AYr,E i- {y ; cn-Y[p,s . TtTE ZIP CODE La.m".tw..n.J jDENVER CO 80202 1370 °M /T+�PARWSUPsaccr.NO,CRMaDRCRmr.CARDNO. D Rv�ON j r ; I / i 2 .DE LIVE RV TO TELEPHONE t !+� t 1 I / 21P;1 t AME/'�TL •lt ` ' tm 1� set I NI RD PARIY'S COMPANY NAME - hid COMPANY 6.•VVII ,( JtIc. 4- 1'. f a tt STREET ADDRESS ! tilt ! EETADDRESS ?,(PLfj.�^-�Q1 CITY AND STATE YIP CODE til4 �D �7 1 { g k N c'6 rt1 e lC bruit. S. LJ Iiiii f , CITY ANDA ITAATE` ' ( COQZIP,'C�OJD.E /."� 4+JC,' ",e„s;e' +y!CC,:R7$$'„G.r,,.^^+n., /�}�/�,.. -"+n"':!/�1'��Qs2�{( l ! `^'t V e'r 1 V I Vo2- 15�— ()SHIPPER'S �/ / �i /V DATE HI75 Ii llE • l t i.. .IIIlll11' I Illlltfllllll�l l�l II II IIIII�1I III Illali SN3NANRE n � //020191126280®8/DO MW /�I I dC DCP Midstream 370 17h Street,�■ Denver,Co 80202uke 2500 • Midstream. 303-595-3331 January 12,2011 Mr. Jim King Colorado Department of Public Health and Environment APCD-SS-B 1 4300 Cherry Creek Drive South Denver,Colorado 80246-1530 UPS Tracking No: 1ZF469150196371741 Re: Execution of Alternate Operating Scenario(AOS)—Enterprise Compressor Station, Operating Permit No. 95OPWE103 AIRS ID 123/0277/056 Engine C-236 (P006) Dear Mr.King: This letter and the attached revised APEN provide the formal notification required under Operating Permit 95OPWE103 for the replacement of engine C-236(P006)with a like-kind engine at the Enterprise Compressor Station.A $152.90 check is attached for the APEN filing fee. Compressor engine C-236 is identified in the operating permit as a 3,300 hp, Caterpillar G3612 engine. The serial number of the old engine was 1YG00029 and the serial number of the replacement engine is 1YG00027. • The replacement engine commenced operation on January 4,2011 and was tested on January 5,2011 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 for the facility. Both the test results and copy of the field log are provided with this submittal. 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 Enterprise Compressor Station. Sincerely, DCP Midstream,LP Wesley Hill Senior Environmental Specialist Attachments • www.dcpmldstream.com • Check for APEN Filing Fee $152.90 • • DCP Midstream,LP PAYEE NUMBER CHECK NUMBER 37017th Street,Suite 2500 0000074502 00269793 Denver,Colorado 80202 PAYEE NAME CHECK DATE APCustomerservice®dcpmidstream.corn 303 605 2219 COLORADO- 01/07/11 INVOICE NUMBER INVOICE DATE NET AMOUNT DESCRIPTION EnterpriseC-236AOS01 01/04/11 152.90 return check to Wes Hill • TOTAL PAID $152.90 PLEASE RETAIN FOR YOUR RECORDS C.P M1t151(eam, Alorean I�OEanM N A \ j PO P»/21? JP 370 I7th SUcet, he 2300 12enver'"'Y "o8 e25- s' ,f' s. APCiulDmerSemce(�dcpnedaCimn RA.4�E1vl+�U ; c��iC�iclfA'1T':; + ,A:t1k. �IJ � 0000079502„ 0107111 00269793 TOTHEORDEROF r r� - . Y NAY .�0 CItAMO]Cfhl'1` NOT NEGOTLIBLE AFTEH]20 DAYS $152.90� COLORADO DEPT OF PU,$LIC HI TH'&ENVRNMNT AIR POII CNTRL DIV APCp'SSB1 4000 CHERRY CREEK DR SOUTH Denver,CO 80246-1530 AU HORIZEDSIGNATURE One hundred fifty two and 90/100 Dollars r ti � 1 '00269793It' 1:0 21. 309379i: 60 L895196ti' • APEN for Replacement Engine • • 0 a a a vi CD u O r 4 E a F _ V Oto a Q 6 y 6 E e0! a h an V N S - o C N R -74 T vg r- E W m 2 m m n - v h � j 0CIr c ❑ 'sl v ` U CO 'F., ° a E omn o o o u O N v^, a W e fa. °o >., o1 ° '. y e o 0 o j o o w m o v x v F" °� e s e Q w• �=. E " o R a c z a ,a. x 0 E a O. 0 _ in _ CO c `° c .E a c .o c ? .c .c ca a = r c N °, a co N z y ---.= '°-w o_°» if W 'Z b c0 • `v •.0 '„vi' O c T v n y .. N y ° 'i s R W O 6 6 J c y _ 7 2' nn,� • M A c �, 3 E R E h e vr4 ED '' G N c Li -= ¢ a u m n 5 e- y , u EO wi°. L O a d o as, i " ≥ c u N tfi L w �-+ C = E ° $ ? 49 G $ a ° r E v x .c, v LE° 71 a >, >, a }r An, u ., "' u c 00 u m o U ° a 4'c+ a c = o s ≥ o 0.. 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U O 0 ' co N = a o E .r O 'cpLA E „ ti a) 2 o N N Q) cc ate. v a. a w UQ �I o rt z �° i • Emission Calculations • • CAT G3612 3,300-hp Engine Emission Calculations Enterprise Compressor Station DCP Midstream,LP Engine C-236(P006)(4 Stroke,Lean Burn,3,300 HP wl oxidizing catalyst) Unit Rating. 3,300 hp BSFC: 6,570 blu/hp-hr Maximum Heat Input: 21.68 mmblufir Operating Schedule: 8.760 hr>yr FHV 958 blu/scl Maximum Fuel Use: 198.25 mmsd/yr Criteria Pollutant Emission Calculations Emission Factors' Actual Emissions Pollutant (ton/yr) NO,, 1.500 g/bhp-hr 47.8 CO - 1.500 g/bhp-hr 47.8 VOC 1.000 g/bhp-hr 31.9 'Controlled emission factors Non-Criteria Reportable Pollutant Calculations ActuatEmissions Control Efficiency Controlled Emissions De Minimis° Pollutant HAP Emission factors Data Source (Ib/yr) % (Iblyr) Bin lib/yr) 1.1,2,2-Tetrachloroethane <4.00E-05IIb/nlrn8tu EPA 7.60 50% 3.80 A 50 1,1,2-Trichloroethane <3.18E-05IbMvnBtu EPA <6.04 50% 3.02 A 50 1,3-Butadiene 2,67E-04IbMunBtu EPA 50.71 50% 25.36 A 50 1.3-Dichloropropene <2.645-05llbhnmBlu EPA <5.01 50% 2.51 A 50 Acetaldehyde 8.36E-03IbMrmBtu EPA 1587.78 50% 793.89 A 50 Acrolein 5.14E-03 IbhmmBtu EPA 976.22_ 50% 488.11 A 50 _ __ Benzene 4.40E-04IblmrnBtu EPA 83.57 50% 41.78 'A 50 Carbon Tetrachloride <3.67E-05 Ib/mmBlu EPA <6.97 50% 3.49 A 50 Chlorobenzene <3.04E-05lb/mrnBtu EPA <5.77 50% 2.69 A 50 Ill Chloroform <2.85E-05Ib/mrn6tu EPA <5.41 50% 2.71 A 50 Ethylbenzene 3.97E-05 lb/mm EPA <7.54 50% 3.77 C 1000 EthyleneDibromJde <4.43E-05Ib/mmBtu EPA <8.41 50% 4.21 A 50 Formaldehyde 5.28E-02 lblmmBtu EPA 10028.07 76% 2406.74 A 50 Methanol 2.50E-03 IbtmmBtu EPA 474.81 50% 237.41 - C 1000 Methylene Chloride 2.00E-05 IbhnmBtu EPA 3.80 _ 50% 1.90 A 50 Naphthalene 7.44E-05Ib/mmBtu EPA <14.13 50% 7.07 C 50 PAH 2.69E-05Ib/mmBtu EPA 5.11 50% 2.55 A 50 Styrene <2.38E-05 lb/mmBtu EPA <4.48 50% 2.24 C 1000 Toluene 4.08E-04lbhnm0tu EPA 77.49 50% 38.74 C 1000 Vinyl Chloride 1.49E-05 ibImmetu EPA <2.83 50% 1.41 A 50 Xylenes(m,p.o) 1.84E-04 ib/mmetu EPA 34.95 50% 17.47 C 1000 TOTAL 0.0705366 Ib/mmBtu — _ <13397 _ — -- °Uncontrolled emission factors for HAP from 4-stroke,lean-bum(4SIB)engines from AP-42,Chapter3,Table 3.2-2.(7100). °Demirtimis levels for reportable non-criteria pollutants.per Colorado Regoal.on No.3. • Cordileran Compliance Services,Inc. 1/50011 • Engine AOS Applicability Report (with back-up data to confirm engine manufacturer date) • • • Air Pollution Control Division Colorado Operating Permit AOS Applicability Report Page 1 Engine AOS Applicability Report Certification Language All information for the Applicability Reports must be certified by either 1) for Operating Permits, a Responsible Official as defined in Colorado Regulation No. 3, Part A, Section I.B.33. 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. • Joseph Kuchinski Printed or Typed Name VP Operations North Title ��4<d-eL / - 7 - Sign�tlire Date Signed • Air Pollution Control Division Colorado Operating Permit AOS Applicability Report Page 2 Colorado Regulation No. 7 Sections XVI and XVILE Company: DCP Midstream, LP Source ID: 123/0277/056 Permit#: 95OPWE103 Date: 1/6/11 Determination of compliance and reporting requirements for a Manufacturer: Caterpillar Model: G3612 Nameplate HP: 3,300 Construction date: 5/19/93 (Previously located at the same Enterprise Compressor Station location) Note: If the engine is exempt from a requirement due to construction date or was relocated from within Colorado, supporting documentation must be provided. • Determination of Regulation No. 7 requirements: Regulation No.7, §XVI ❑ Does not apply to this engine. Engine is not located in the ozone nonattainment area or does not have a manufacturer's design rate greater than 500 horsepower or did not commence operation on or after June 1, 2004. ® Does apply to this engine and applicable emissions controls have been installed. Regulation No. 7, § XVII.E ® Does not apply to this engine. Engine does not have a maximum horsepower greater than 100 or the construction or relocation date precedes the applicability dates. ❑ Does apply to this engine. The following emission limits apply to the engine: NOx (g/hp-hr): 1.0 CO(g/hp-hr): 2.0 VOC (g/hp-hr): 0.7 • • Air Pollution Control Division Colorado Operating Permit AOS Applicability Report Page 3 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 • . Air Pollution Control Division Colorado Operating Permit AOS Applicability Report Page 4 NSPS JJJJ Example Report Format Note that as of September 1, 2008 that the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § I.B (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. NSPS Subpart JJJJ: Standards of Performance for Stationary Spark Ignition Internal Combustion Engines Company: DCP Midstream, LP Source ID: 123/0277/056 Permit#: 95OPWE103 Date: 1/6/11 • Manufacturer: Caterpillar Model: G3612 • Nameplate HP: 3,300 Engine Type: 4 Stroke, Lean Burn Manufacture Date: 11/30/92 (See attached email verification from vendor) Date Engine Ordered: Prior to 11/30/92 (See attached email verification from vendor) 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. n NSPS JJJJ does apply to this engine. Note: Using the format below, the source must submit to the Division an analysis of all of the NSPS JJJJ applicable requirements that apply to this specific engine. S • Air Pollution Control Division Colorado Operating Permit AOS Applicability Report Page 5 Determination of NSPS JJJJ requirements: 60.4230 Applicability (a)(4)(i) Does not apply to this engine since it is a lean burn engine, greater than 500 HP, with a manufacture date prior to July I, 2007. CONCLUSION OF FINDINGS DCP Midstream's Caterpillar G3612 engine is not subject to the requirements of NSPS JJJJ. • • • Air Pollution Control Division Colorado Operating Permit AOS Applicability Report Page 6 MACT ZZZZ Area Source Example Report Format MACT Subpart, ZZZZ: National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Company: DCP Midstream, LP Source ID: 123/0277/056 Permit#: 95OPWE103 Date: 1/6/11 Manufacturer: Caterpillar Model: G3612 Nameplate HP: 3,300 Engine Type: 4 Stroke, Lean Burn Manufacture Date: 11/30/92 (See attached email verification from vendor) Date Engine Ordered: Prior to 11/30/92 (See attached email verification from vendor) • 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 area source MACT ZZZZ applicable requirements that apply to this specific engine. Determination of MACT ZZZZ requirements: 63.6585 Applicability This subpart is applicable to DCP's engine since they are going to be operating an existing stationary reciprocating internal combustion engine (RICE) at a major source of HAP emissions. 63.6590 What Parts of My Plant Does This Subpart Cover? (i) For stationary RICE with a site rating of more than 500 brake horsepower (HP) located at a major source of HAP emissions, a stationary RICE is existing if you commenced construction or reconstruction of the stationary RICE before December 19, 2002. i • Air Pollution Control Division Colorado Operating Permit AOS Applicability Report Page 7 (3)The following stationary RICE do not have to meet the requirements of this subpart and of subpart A of this part,including initial notification requirements: (ii) Existing spark ignition 4 stroke lean burn (4SLB) stationary RICE with a site rating of more than 500 brake HP located at a major source of 1-lAP emissions; CONCLUSION OF FINDINGS Since the initial construction date is prior December 19, 2002 and the engine is an existing 4SLB stationary RICE with a site rating of more than 500 brake HP located at a major source of HAP emissions, this engine is exempt from the requirements of MACT ZZZZ under Section 63.6590(b)(3). S i • 17.t r 0 l ►,i 1 Sales and Service Detail ...,Ik...,:-'-..::: 1 YG00027: Arrangement No: 7C-4112 Suiid Date: 30Nov1992 Engine Information Mfg Model 8 Year:G3612 1993 Ship Date: 09Feb1993 Specifications I I Prod Family: ZP Gas Engines Sales Date: 09Feb1993 ;2T-5502 Sims Prod Family:68 Gas Engines Delivery Date: 19May1993 ;Application Source Facility: 88 Lafayette Plant Selling Dlr: E75A C Compressor j Principle Work: B40 Compression Owner cis: E • • Page 1 of 3.Created Mon Jan 03 12:26:20 CST 2011 for Don Armijo CAT CONFIDENTIAL:YELLOW • • -!'-'v 3 0 8 qJ U OD T M I .s 0 ,� e N.Z a G }v9 O 0.IA." .o 01 t Y tl rte,r.'0 a y 'C, y TA yN m o c2 o aQ. - 0� g O" 11 0 n 7, .. p ro N^ $ M O _d �Q _ C I N •Q a W y tt j S i g a — I .6 U ° of 4� Gt] F 7 - g 1 .0 0 .a u. n i o ti w f,, u A g a 1 .- � u o . :� o . M n 8 = > �' f¢� Ai eo w O o S >-,13 p w'.L' O S. 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B I; > ❑A. r426 a c�po .� .e _d , in 6' C .S }• o G er, c, o 5 K. 0 ii 9 3 p 1 d O co *a r, a t g sa . � N 'C gY .5e u .7 T 1 io 0 $ U sip .i ii H g A Y Iq a \ $ e5 t v1 7 y a !kr z 3 S 1 w c st'�- :e C a) g`� ol h wFc w i i O, � 0— � 3 F( ,(O� o �� ° o o @ g , @ i v o 3 d ae °' ry o° u d 143,8 : d ° ° i a O 8 ♦"e t7 E ,al g, �.4 a • yy° ,1 'z.. U 'n o .Q.W., o'Y o kuk i' .d. V al o y tf o -i' uto 5 o. e' y" x N ! N N 0 `�' U] !-. • AOS Portable Engine Test Data I • 14rlaUlo Ana3lyzek'Test JUMilts AOS 2 6 slat t 1 d 11 otd.stt tVG,U3RZ 11959 Ell Y#rc tlUD27 -. )}llgi}f t se CRntptes*ot 8tatialt:. . . ... Exhaust Flow Rate scUitr=8710 scf/MM&u•Fuel Consumption MMDt Jltr•20.95%r(20.95%-O2%) Fuel Consumption MMDIu/hr = Fuel Consumption(scf/hr)•Fuel Heating Value(Dtu/scf K 1,000,000(Bto/MMBM) Emissions(lb/br)=measured ppmv/1,000,000•Exhaust Flow(sefihr)•mot.nt.(lbnbmol)•1(Ibmol)/385.33(sct) where: molecular weight CO = 28.00 molecular weight NOx = 46.07 Test Data Results(see attached): Source ID No. P-003 P-005 P-006 P-018 Site ID No. C-238 C-235 -136 C-234N Engine Stack Test Date 1/5/2011 Meas.Conti O2% = 0 0 11.95 0 Meas.Post-Converter CO ppmv= 0 0 10.04 0 Meas.Post-Convert.NOx ppmv= 0 0 1.02 0 Normal Fuel Heat Value DDJsef= 958 958 958 958 Mex.Fuel Consumption(sefihr) = 20708 29281 29281 25052.2 Max.Fuel Cotsump.(MMDItt/hr)= 19.8 28.1 28.1 24.0 Moe.Exhaust Flow Rate(scfihr) = 172791.3 244325.9 568736.5 209040.0 Max.Meas.CO Etniss.Rate(lb/In')= 0.00 0.00 0.41 0.00 - Permitted'COEmits,Limit(1b/hr) = 10.91 10.91 10.91 '1.41 Compliance with tidy CO Limit YES YES YES YES Max.Meat.CO Emits.Rate(tpy) = 0.00 0.00 1.82 0.00 • Permitted CO Emits.Limit(tpy) = 47.80 47.50 47.80 6.17 Compliance with Yrly CO Limit YES YES YES Max.Meas.NOx Emits.Rate(Ib/ht)= 0.00 0.00 0.07 0.00 Permitted NOs Emits,Limit(Ib/hr)= 10.91 10,91 10.91 5.48 Compliance with tidy NOx Limit YES YES YES YES . Max.Meas.NOx Emits.Rate(tpy)= 0.00 0.00 030 0.00 Permitted NOx Emits.Limit(My) = 47.80 47.80 47.89 24,00 Compliance with Yrly NOx Limit YES YES YES YES • Colorado Emissions AFR Test Data Log • Midstream. Plant Location: ENTERPRISE Converter Manufacturer: Inspection Date: 1/5/2011 Converter Model: Plant Permit: 95OPWE103 Flange Sizes: Engine Manufacturer: CATERPILLER AFR Manufacturer: Engine Serial Number: 1YG00027 AFR Serial Number: Engine Model: 3612 AFR Model: Unit Number: C-236 • Engine RPM 904 ENERAC .3+�00E: Or. COMM1 Suction Pressure 92 EMI SS 10NS TEST RECORD 04:35:54-14:56:55 01/05/11 Discharge Pressure 700 PARAMETER AVG OXYGEN 11 .95 Engine Timing 18 CARBON MONOXIDE 19.04 NITR:C OXIDE 1 .02 Main Fuel Pressure 9 _ NITROGEN DIOXIDE 9. OXIDES OF lqiTROG _ .92 Cony.D1tf.Pressure 3.8 • • Left Bank Manilla(' Pressure 21 Right Bank Manifold Pressure 21 Lambda Settings 02 Sensor Target 02 Sensor Voltage Pre-Converter Exhaust Temp. 774 Post-Converter Exhaust • Temp. 788 Left Bank Exhaust Temp. 923 Right Bank Exhaust Temp. 921 Post-Converter CO PPM: 10.0 Post-Converter NOX PPM: 1.0 02 Percent: 11.9% Remarks W ENtINP START-UP Remarks • State of Colorado Portable Analyzer Monitorin9.Protocol • Form A Linearity Cheek Data Sheet Date: I/5//2011 Analyst: Jim Miller Analyzer Manufacturer/Model#:Enerac-3000E Analyzer Serial#:3E001183 LINEARITY CHECK I Absolute Calibration Gas Analyzer Analyzer Analyzer Analyzer Linearity Difference Percent of Pollutant Concentration Response Response Response Response Valid (Indicate Span (Indicate Units) ppm NO ppm NO2 ppm CO %O2 (Yes or No) Units) NO Zero 0 0 0 0 Yes Mid 99.1 100 ". .9 .1 Yes Span 204 202 { 2 .1 Yes 4111 NO2 Zero 0 0 0 0 Yes Mid 25.5 26 ..5 .01 Yes •Span 52.4 53 .6 .01 Yes CO Zero 0 0 0 0 Yes Mid 201 '3 201 0 Yes t s -;` Span 397 400 3 1 Yes O2 Zero 0 _ 0 0 0 Yes Mid 10.0 t 0 10 0 0 Yes Span 20.9 20.9 0 0 Yes • January 25,2006 • State of Colorado Portable Analyzer Monitoring Protocol Form B Stability Check Data Sheet Date: 115/2011 Analyst: Jim Miller , Analyzer Manufacturer/Model it:Enerac-3000E Analyzer Serial N:3E001183 Pollutant:NO,NOR,CO(Circle One) Span Gas Concentration(ppm): 204 STABILITY CHECK Elapsed Elapsed Elapsed Time Analyzer Time Time Time Analyzer Response Response Response (Minutes) , (Continued) , (Continued) 1 101 I7 33 2 161 18 34 3 199 19 35 4 204 20 36 5 203 21 37 6 203 22 38 7 204 23 39 8 204 24 40 • 9 204 25 41 10 204 26 42 11 204 27 43 12 204 28 44 13 204 29 45 14 204 30 46 15 204 31 47 16 32 48 For 30-minute Stability Cheek Period: Maximum Concentration(ppm): Minimum Concentration(ppm): For 1S-minute Stability Check Period: Maximum Concentration(ppm): 204 Minimum Concentration(ppm) 199 Maximum Deviation=100*(Max.Conc.-Min.Conc.)/Span Gas Conc.= percent Stability Time(minutes): 3 • • State of Colorado Portable Analyzer Monitoring Protocol Form B Stability Check Data Sheet Date: 1/5/2011 Analyst: Jim Miller Analyzer Manufacturer/Model#:Enerac-3000E Analyzer Serial#:3E001183 Pollutant:NO,iNo2.CO(Circle One) Span Gas Concentration(ppm): 52.4 STABILITY CHECK Elapsed Elapsed Anal per Elapsed Analyzer Analyzer Time Time Time __Minutes) Response (Continued) Response (Continued) Response 1 24 17 33 2 45 18 34 3 50 19 35 4 52 20 36' 5 52 21 37 6 52 22 38 . 7 52 ' 23 39 g 52 24 40 IIII 9 52 25 41 10 52 26 42 11 52 27 43 12 52 28 44 13 52 29 45 14 52 30 46 15 52 31 47 16 32 48 For 30-minute Stability Check Period: Maximum Concentration(ppm): Minimum Concentration(ppm): For 15-minute Stability Check Period: Minimum Concentration(ppm) Maximum Concentration(ppm): 52 50 Maximum Deviation=100*(Mar.Conc.-Min.Conc.)/Span Gas Conc.= percent Stability Time(minutes): 3 • • State of Colorado Portable Analyzer Monitoring Protocol Form B Stability Check Data Sheet Date: 1/5/2011 Analyst: Jim Miller Analyzer Manufacturer/Model/1:Enerac-3000E Analyzer Serial#:3E001183 Pollutant:NO,NO2,c(Circle One) Span Gas Concentration(ppm): 397 STABILITY CHECK - Elapsed Elapsed Elapsed Analyzer Time Analyzer Time Analyzer Time Response Response Continued) Response (Minutes)(Continued) 1 85 17 33 2 157 18 34 3 255 19 35 4 300 20 36 5 395 21 37 6 400 22 38 7 400 23 39 8 400 24 40 IIID 9 400 25 41 10 400 26 42 11 400 27 43 12 400 28 44 13 400 29 45 14 400 30 46 _ 15 400 31 47 16 32 48 For 30-minute Stability Check Period: Maximum Concentration(ppm): Minhntum Concentration(ppm): For 15-minute Stability Check Period: Minimum Concentration(ppm) 395 Maximum Concentration(ppm): 400 Maximum Deviation=100*(Max,Conc.-Min.Conc.)/Span Gas Cone.= percent Stability Time(minutes): 5 • Form C Calibration Error Check Data Sheet Company: DCP MIDSTREAM Facility: ENTERPRISE BOOSTER Source Tested:C-236 Date: 1/5/2011 Analyst;Jim Miller Analyzer Serial It: 3E001183 Analyzer Manufacturer/Model I: Ettcrac 3000E PRETEST CALIBRATION ERROR CHECK A B IA-nl lA-I1IISG'100 Pump Flow Analyzer Calibration Gas Absolute Calibration Response Time Rate(Indicate Reading Concentration Difference Percent ofSpan Valid Units) (Indicate Units) (Indicate Units) (Indicate Units) Note 1 (Yes or No) (Alinutes) NO Zero Ippm 0 0 . 0 0 YES 0 Span Ippm 204 204 0 0 YES 3 NO2 Zero Ippm 0 0 0 0 YES 0 Spa: Ippnn 50 52.4 2.4 .1 YES 2 CO Zero Ippm 0 0 0 0 YES 0 Span Ippm 400 397 3 2 YES 3 / O: Zero !ppm 0 0 0 YtiS 0 Span Ippm IC 10.0 0 YES I Pretest Calibration NO Cell Temperature(°F) IS • SO=Span Gas POST TEST CALIBRATION ERROR CHECK A B IA-BI IA-D1/SC*100 Interference Check Pump Flow Analyzer Absolute Acerngc of Calibration Gas Difference ofSPan Callbradon Pretest and Poll NO Monitor CO Monitor Rate Rending Concentration Valid Test Analyzer Response Response (Indicate (Indicate (Indicate Note 1 P Units) Units) (Indicate Units) Units) (Yes or No) Headings (PPP') (PPM (Indicate Units) NO Zero Ippm 0 0 0 0 YES 0 :'; , , • .-._.�`.;--..... Span 1ppun 200 204 4 2 YES 202 NO2 Zero Ippm 0 0 0 0 YES 0 •^ _ _ Span 1ppm SO 52.4 2.4 .1 YES 50 CO Zero Ippm 0 0 0 0 YES 0 ,.,,,..-,i.:..:,1.--:-.:,=;,.,. .;-:-..-,,,,,',:.:..‘i-,,-' Span Ippm 400 397 3 2 YES 400 Os LCIO Ippm 0 0 0 YES 0 Span Ippm 10 too o — YES 10 Post Test Calibration NO Celt Temperature(OF) 19 CO Interference Response(Ico,%): NO Interference Response(ho,%): SG=Span Gas Note 1: The percent of span calculation is applicable to the NO,NO2 and CO channels only. 0 • / j @ \ / \ J @ � ® � 0 ® ( ? ( 9 © // m . / . . CO ( \ l 114 CO 01 � III } :\ / : c ( z 0. } G 21 m , G 9 ^ - :0g w «p® - /0 G&\J7w&§ 12 '! \M}\• w al(\} 01 %/s? /aDI m\ }/\ •/\ . CO /j \ , F! 6 W U / \ G0 : v O \ @ / n0 \ a § k fit u / - & 01 D01 i . ! / Z 0. - CO ( f , Q e ` ' p G ® eee 2 .t Zee in- ~ \ r- i ial et : k , : »a = 99I . </O m © - • • AOS Engine Replacement Log • • • L d • � _�, A ▪ 4 U G C R N -. C V Q F v N w O O c L G ri F V w inA = 3 7 w 4 Z o a' — o v U C) 0 V) F ^ 0 s C C o c a t. o m = O G m L '4 M C N C) M m b O A a) E a R O G ., . N al 44 it. 04 V N d N H O C N 5 on O as R cu °' 04V0 a U v c 4 o + N y.� m C , CU 47, ti O • N s. m L". .�". Ca.try 0 Z o al 4 el d ti O E ` • F d -50 Q ' I. 3 en a .q, 0.I c v .. a y O q CI 0. o Y J.. 1. A. Cil T O •Q a Y C) H M aas .^. W O L 'ctd F O 9 0 co,.17_ W m 7, .0 1 c O M U _• Z ° R • A G " o '° 3 M .F E.. $ O._. WC T N U G O O tC .5 .r.: aJ 0.0 C d O O F., or Z o i V) x m G• 4) d G G m C A 0 C C 3 0. 'awa V V r x o o0 ct 0 . � N , E• 'efii G CC m A S.41 o v v c ✓ py 4 v ,7 Q? 4.0 E- :Q a o C • 'O M y N t t • w U N CIC DCP Midstream 370 17th Street,Suite 2500 Denver,CO 80202 • Midstream. 303-595-333] June 21,2010 Send Via UPS T rackin.g No:1Z F46 915 01 9203 5880 Ms.Jennifer Morse Colorado Department of Public Health and Environment APCD-SS-BI 4300 Cherry Creek Drive South Denver,Colorado 80246-1530 Re: Emission Permit/APEN Cancellation Request DCP Midstream,LP Shut down Emission Sources Dear Ms.Morse: DCP Midstream,LP(DCP)is requesting the cancellation of the following APENs only: Emission Source Facility Name APEN Number P004(C-234) Enterprise Compressor Station 123/0277/054 Engine P120(C-121) Greeley Natural Gas Processing Plant 123/0099/101 • Engine P-167(C-150) Spindle Natural Gas Processing Plant 123/0015/023 _ ANGI-SOCO Drip Tank ANGI-SOCO Drip Station 123/1361/001 DCP is requesting the cancellation of the following APENs and construction permits: Emission Source Facility Name APEN Number Pennit Number SVE-01 (Soil Vent wl Air Enterprise Compressor 123/0531/069 98WE0015 Sparge) Station Duchant Booster Duchant Booster 017/0220/001 00CY0438 (Dechant Wellhead C.S.) Mayfield Delivery Tank Mayfield Delivery 017/0233/001 03CY0022 Weld To Spindle Drip Tank Weld to Spindle Drip 123/1359/001 03WE0018 The attached Emission Permit/APEN Cancellation forms have been completed for the above-referenced facilities. If you have any questions, please contact me at wdhill@dcpmidstream.com or by phone at 303-605-1716. Sincerely, DCP Midstream,LP X01&'"7 Wesley Hill Senior Environmental Specialist • Attachments www.dcpmidstream.com • Colorado Air Pollution Control Division EMISSION PERMIT/APEN CANCELLATION REQUEST Air Emission Permit Number/ / APEN Number: )2-3/42a:17/- 0 9 q Source Name: PO G Li / C - 3 1 II G c - Source Address: ,? ACAS�-r vH. f�L4cOri Co. ,,v?EtSS r 5-41; sw //y Sw 1A4 zsc. 3o 1I T-.7 Ali ZO3 fa . & J4 .C'o. This cancellation request is based on the following: Please circle the apjfropriate item. 01. The facility and/or source addressed by the permit o �C► not longer exists. 2. The facility has been sold to another party and I do not wish to transfer the permit. New owners name: New owners address: New owners phone number: 3. The emissions from the permitted source no longer is above the threshold required for • maintaining an ADEN or permit with the Division and the source does not want to maintain an active APEN or permit with the Division. Date Equipment or Operations Ceased/Sold or Below Reporting Thresholds: 9/300 it Print Name: /O-E 5 lei b(( ( ( Title: Cr. ck v. to ist A( 3 ``r'5 7- Signature: ` G� L. Date: O ¶/lO Company Name: C P /44-c S T pea"-t. L Company Address: .? 70 17 -1--ft S-La c+c- zCo D City: ✓C r— 2 c' a / State: CO Zip: Po Phone number: 30 ? — (9 OS (7( ' 0 . Colorado Air Pollution Control Division EMISSION PERMIT/ADEN CANCELLATION REQUEST Air Emission Permit Number APEN Number: /23/06 9 Via lB / Source Name:1{ e e(1 EIn ,, fru I p i a,O (c - ea 0 Source Address: CrCLjt1 (j sWs. Sec -2c 7N RG4 O ;K i� g & This cancellation request is based on the following:S Please circle the appropriate item. The facility and/or source addressed by the permit o it longer exists. 2. The facility has been sold to another party and I do not wish to transfer the permit. New owners name: New owners address: New owners phone number: 3. The emissions from the permitted source no longer is above the threshold required for • maintaining an ADEN or permit with the Division and the source does not want to maintain an active APEN or permit with the Division. Date Equipment or Operations Ceased/Sold or Below Reporting Thresholds: S/i 1 7/O Print Name: Goes 14; 1( Title: Sr-. Signature: Date: 6/2-0b L Company Name: t/G/ /`(ij t/S.fret/2 z 7 LP Company Address: 37n / 7 +kSk 02 S City:l rt vier State: C6 Zip: gO .Ld Phone number: 30-3— 6 6 s— / 7 (6 • • Colorado Air Pollution Control Division EMISSION PERMIT/APEN CANCELLATION REQUEST r/� Air Emission Permit Numbef , APEN Number: /2 3/00(5 // p a.3 Source Name: Se� vj/ p C l "/6 7 (re- is-0) p r! Source Address: 511):,...„Me to , itit,.� S /6c I}/r'a'sS:wr 4.4_4- Ste. 3K fVb'7la-", T-2 Al ;.. to Vci Co. This cancellation request is Wised on the following: Please circle the appropriate item. 1. he facility and/or source addressed by the permit o C it longer exists. 2. The facility has been sold to another party and I do not wish to transfer the permit. New owners name: New owners address: New owners phone number: 3. The emissions from the permitted source no longer is above the threshold required for • maintaining an APEN or permit with the Division and the source does not want to maintain an active MEN or permit with the Division. Date Equipment or Operations Ceased/Sold or Below Reporting Thresholds: VM// C Print Name: WPS I-e, 161/ Title: Sly, r k/. ?e f 5'c Signature: ..,,/,-/I4/-, Date: 67 i el !10 Company Name: MC /k4dsJ-1 4 on_ / L`P 4-4 Company Address: no / 7 ` d J, , S42. S t3O City:Thp vt trot- State: C C.) Zip: go 2-6) n_. Phone number: 7o3— ‘,loc — /7(6 • • Colorado Air Pollution Control Division EMISSION PERMrFIAPEN CANCELLATION REQUEST Air Emission Permit /Number /APEN Number: (.Z3/f re Source Name: AA/G j ` So C c 6c. " / Source Address: A-/VG"/VG"4- - SOcO 'Iry -f�'a `� SF- :e•. 31 -r-q!/° R 6 ( w This cancellation request is based on the following: Please circle the appropriate item. 1.Ohe facility and/or source addressed by ti i r N E of longer exists. 2. The facility has been sold to another party and I do not wish to transfer the permit. New owners name: New owners address: New owners phone number: 3. The emissions from the permitted source no longer is above the threshold required for • maintaining an APEN or permit with the Division and the source does not want to maintain an active APEN or permit with the Division. Date Equipment or Operations Ceased/Sold or Below Reporting Thresholds: 1 // /0 t Print Name: I €S 4:Ii Title:5r, !LL °S i Signature: . /� a __ Date: (o/2t//O T Company Name: V C I ,S t�f S'I n?4 yin ` Ltd Company Address: ?70 / 7-f tt S4-- ck . _2C-90 / City: —Devi_tie t^ State: CO Zip: 00 2-O Phone number: ?n3 — 605-- 177& i • Colorado Air Pollution Control Division EMISSION PERMIT/APEN CANCELLATION REQUEST Air Emission Permit Number 9 0 jf f D o( S APEN Number: 1134,3-? 1/o G 9 Source Name: S V r O( — So; Ve.w'1- iJ Ek Ai(' S�G. � il Source Address: at e -no 1,-- SIP SO . e 30 A), le63GO, toel Co, This cancellation request is based on de ollowing: Please ciccie the appropriate item. 1. ,e facility and/or source addressed by th rmi of ot longer exists. 2. The facility has been sold to another party and I do not wish to transfer the permit. New owners name: New owners address: New owners phone number: 3. The emissions from the permitted source no longer is above the threshold required for • maintaining an APEN or permit with the Division and the source does not want to maintain an active APEN or permit with the Division. Date Equipment or Operations Ceased/Sold or Below Reporting Thresholds: 'Y/ 3 a/o 9 Print Name: tADeSic-l1 p1 /1 Tide: Sr. FK✓,. �lLe.e-('S Signature: /1,4---L—i72/11-4Date: ‘/l , p D an P Y Com Name:0C jC) It- c w P Company Address: 3 70 / 7 -e S� I STS a c ot / City: �esnu'e State: Co Zip: go a- c 2 Phone number: 'gel Z ` 6 O i " ( 7/a • • Colorado Air Pollution Control Division EMISSION PERMIT/APEN CANCELLATION REQUEST Air Emission Permit Number 0'O C ti 0 14 3 a APEN Number: 01 7/02'LA Source Name: -1��14A""""C 4+ IIa(00S'k ph 'b e C wt tok d tua, Ceny(essr ��/rl Source Address: C''L`^# I,a5� a r -"Dee k 4..C - Litt I ro Pd ceS5o1`9/ ESE Sec ag,Ti3S , Rce7to j., eke 2nt a . 1 This cancellation request is based on the following. Please circle the appropriate item. 1. The facility and/or source addressed by th. permi.o ADEN t longer exists. 2. The facility has been sold to another party and I do not wish to transfer the permit. New owners name: New owners address: New owners phone number: 3. The emissions from the permitted source no longer is above the threshold required for • maintaining an APEN or permit with the Division and the source does not want to maintain an active ADEN or permit with the Division. Date Equipment or Operations Ceased/Sold or Below Reporting Thresholds: .'///v/io [0.Print Name: //tom. S ft(1/ Title:5N. F✓i.✓. si es (i S t Signature: ' 7 � i99 /I( Date: 6�( g/l Company Name:t0 12 Al:0(dre4.v`•. / L. ro Company Address: T70 / 73/4 C-1--• 1 S I- -' c-oo City: 7 Ave c State: C O Zip: TO 0- C ?- Phone number: 303-‘,.05-- - 17 (h Ill Colorado Mr Pollution Control Division EMISSION PERMIT/APEN CANCELLATION REQUEST Air Emission Permit AAL�� Number 0 3 C 'I 00 2 2 APEN Number: o 1 7/oa 3 3 /re.Source Name: t�� ci 0:-De is��ll We r 7 -a ".. Source Address: /1/11P:e ( e l^ vi se it . 2o , TO-1S /kg- t/t) This cancellation request is based on the following: Please circle the appropriate item. 1. he facility and/or source addressed by theemior 4,of longer exists. 2. The facility has been sold to another party and I do not wish to transfer the permit. New owners name: New owners address: New owners phone number: 3. The emissions from the permitted source no longer is above the threshold required for • maintaining an APEN or permit with the Division and the source does not want to maintain an active APEN or permit with the Division. �y Date Equipment or Operations Ceased/Sold or Below Reporting Thresholds: 0 l//Q 7 Print Name: Wes 1,---7'"7 4. II Title: Sr. C✓l-ve sip,A 3 I Signature: ( Date: 6//C/l d Comas Name: .f,._ wr L/� Companyt� �� Company Address: ?7D /7 ` SA / Ste g- o-0 City: "--\IC(' State: CC) Zip: ' O -m 2 Phone number: 3o3— & e, 5 —(7 ( .6 , • Colorado Air Pollution Control Division EMISSION PERMIT/APEN CANCELLATION REQUEST Air Emission Permit Number £2'3 W E D U 1 t APEN Number: P- 3/ l 3 5-9, Source Name: W t `t+ /to )0, u.)le /)r.ID T c o t Woo bh( Co u�t KSa�e Ti 4-rSource Address:pO'21/,1' I 57,0• it •e —At.? £WSt 2(v Yyp 126-7 W stw Weida_ This cancellation request is based'on the following: Please circle the appropriate item. 1. i he facility and/or source addressed by th permit o • 'EN ' .t longer exists. 2. The facility has been sold to another party and I do not wish to transfer the permit. New owners name: New owners address: New owners phone number: 3. The emissions from the permitted source no longer is above the threshold required for • maintaining an APEN or permit with the Division and the source does not want to maintain an active APEN or permit with the Division. Date Equipment or Operations Ceased/Sold or Below Reporting Thresholds: 2/ 23/0 E Print Name: //Ve.S 1 fig-, gel/ Title: Sr. ��t/. ,1 S� Signature: / Date: 6121 l i a Company Name: -pep IL Company` d Address: 3 70 ` 7 1414-1414- Ste—. / 51-e, .2 S� t City: -e tA-U€(- State: C d Zip: 02-0 Phone number: 2C God--(/ 7//h • UPS CampusShip: Label/Receipt Page 1 of 2 UPS CampusShip: View/Print Label • 1. Print the label(s): Select the Print button on the print dialog box that appears.Note:If your browser does not support this function select Print from the File menu to print the label. 2. Fold the printed label at the solid line below. Place the label in a UPS Shipping Pouch. If you do not have a pouch,affix the folded label using clear plastic shipping tape over the entire label. 3. GETTING YOUR SHIPMENT TO UPS Customers without a Daily Pickup o Schedule a same day or future day Pickup to have a UPS driver pickup all your CampusShip Packages. o Hand the package to any UPS driver in your area. o Take your package to any location of The UPS Store®, UPS Drop Box,UPS Customer Center,UPS Alliances(Office Depot®or Staples®)or Authorized Shipping Outlet near you.hems sent via UPS Return SeMces5(including via Ground)are also accepted at Drop Boxes. o To find the location nearest you,please visit the Resources area of CampusShip and select UPS Locations. Customers with a Daily Pickup o Your driver will pickup your shipment(s)as usual. FOLD HERE • W 4 o O el IN3/44 riot Vh dia— isia. t. M N i • eq =II VI g CO V � " IIMINIIMIlall O a. v. sisolgamisesis $ 2 a o pit >4 tg inisi lig ?I AvQaA i. A VVV V z zi b- • https://www.campusship.ups.corn/cship/create?ActionOriginPair—priut_PrinterPage&P... 6/21/2010 UPS CampusShip: Label/Receipt Page 2 of 2 Shipment Receipt (Keep this for your records.) • Transaction Date 21 Jun 2010 Address krformation Ship To: Shipper: CC)Dept of PH&E DCP Midstream Jennifer Morse Wes Hill 303.6923240 370 17th Street-Ste 2500 APCDSS-B1 Denver CO 80202 4300 Cherry Creek Drive South DENVER CO 80246-1523 . Shipment Information Service: UPS Next Day Air *Guaranteed By: 10:30 AM.,Tues.22 Jun.2010 Fuel Surcharge: "1.58 Shipping: "15.80 Package Information Package 1 of t Tracking Number. 1ZF469150192035880 .11 Package Type: UPS Letter Actual Weight: Letter Billable Weight Letter RC Code: G936 Billing Information Bill Shipping Charges to: Shipper's Account F46915 Total: All Shipping Charges in USD 17.38 Negotiated Total: 7.55 Note:Your invoice may vary from the displayed reference rates. For delivery and guarantee information,see the UPS Service Guide.To speak to a customer service representative,call 1-800-PICK- UPS for domestic services and 1-800-782-7892 for international services. "Detailed information on fuel surcharges is also available. • hops://www.campusship.ups.corn/cship/create7ActionOriginPair=print_PrinterPage&P... 6/21/2010 DCP Midstream LP CleaP Midstream Enterprise Compressor Station Construction Permit Modification Application Submitted To: Colorado Department of Public Health and Environment • Air Pollution Control Division 4300 Cheny Creek Drive South APCD-SS-Bl Denver, CO 80246-1530 October 2011 Prepared By: Olsson Associates 4690 Table Mountain Drive,Suite 200 Golden,CO 80403 OISS( N AUSO Ci.AItS • clop DCP Midstream 370 17th Street,Suite 2500 De Midstream_ Denver,CO80 r, 202 303.595-3333 8031 October 24,2011 Colorado Department of Public Health and Environment Air Pollution Control Division !,RIVED 4300 Cherry Creek Drive South,APCD-SS-BI Denver, CO 80246-1530 25 an 33� i Re: Enterprise Compressor Station Kaizen Permit Modification Application Dear Sir or Madam: DCi'M4dslzeam,LP (DCP)is submitting.the attached construction permit modification application for the Enterprise Compressor Station located in Section 30,Township 3N,Range 63W, Weld County,Colorado. This is a natural gas compressor station which is permitted under Title V Operating Permit95OPWE103. DCP has four Caterpillar G3612 SI engines operating at this facility: Engine P018 is rated at 3,550 HP, The other engines(P005,P006,and P003)are rated at 3,300 HP. DCP would like to replace the turbo packages on these engines • which will increase the engine efficiency. This change will also increase the horsepower of the engines to 3,550 HP. These engines are all equipped with AFRCs and NSCR and will match the emissions P018,resulting in an overall reduction in emission in spite of the bump in horsepower,. These engines currently meet and will continue to meet the requirements of Regulation Number 7,Section XVI.B.2. With this application, DCP is also going to add a 10,142 hp,Solar Taurus 70 turbine powering a compressor;:and will increase the TEG dehydrator throughput to 120 MMSCPD and the condensate throughput to 5.6 MMgal/yr.The fugitive and loadout emissions have also been updated in this application to account for these changes. A combustor has been added to the stabilized condensate tanks. Also,please note that Engine O234 and the SVE unit have been removed from that facility. DCP previously submitted cancellation notices for these two sources and requessts,that these sources be removed from the permit during this permit modification: The project modification will provide an overall net reduction in NOx(-52.01 TPY)and CO - 105.18 TPY). There will be an increase in VOC (21.81TPY)and formaldehyde(0.81TPY)(See attached table). October 24,2011 Page 2 • The application includes the following attachments: A. APEN Filing Fees B. APENs C. Emission Calculations and Supporting Documentation D. Company Contact Information Sheet E. Ambient Air Impact Analysis F. Facility Emissions Inventory G. Process Description,Flow Diagram,and Plot Plan H. Operation and Maintenance Plans I. Regulatory Analysis J. CDPHE Construction Permit Completeness Checklist If you have any questions or require any additional information about the project,please feel free to contact me at(303)605-1716 or WDHill@dcpmidstream.com. Sincerely, DCP Midstream,LP ,� • Wesley Hill Senior Environmental Specialist Enclosures • www.dcpmidstream.com Emissions Comparison • Enterprise Compressor Station DCP Midstream, LP Current Permit Limits S,.. ' NOx CO ' •VOC CHOH : C234: _ -F ai361z$I .3t,.471J0 +?47$0' . ',v.41 87 ?_4_: 25... R Revmbived. C235 G3612 SI 47.80 47.80 _ 31.87 2.55 C236 G3612 SI 47.80 47.80 31.87 2.55 C238 G3612 SI 47.80 47.80 31.87 2.55 P018 G3812 SI 24.00 6.17 34.28 2.74 P012 FUG - - 26.91 P013 Cond Tanks - 4.30 P016 LO - 4MMgaUyr D2 Dehy - 5.00 11.52 - 4MMgel/yr SUE', ' SUE_ ° x u r 'x0v₹ nt X > ,r, w u ' 85 a mbe : Total 214.68 _ ,. Ret(m edg Total` — 215.20 197.37 12.94 167.40 149.57 177.62 10.39 *Not including removed equipment New Confl uration --NOx' CO voc `CHOH Source . toy . tpy tin.- : 9 tpy Notes C235 03612 SI 24.00 6.17 34.28 2.74 • C236 G3612 SI 24.00 6.17 34.28 2.74 _ C238 G3612 SI 24.00 6.17 34.28 2.74 P018 03612 SI 24.00 6.17 34.28 2.74 ' T1 Taurus 70 19.41 19.70 11.28 0.23 New P012 FUG - 28.77 P013 Cond Tanks 0.72 _ P016 LO - 5.6 MM b2 LO - - 12.38 - 5.6 MMpal/yr Dehy - - 9.16 120 MMSCF/yr Total 115.39 44.39 199.43 11.20 . I "5 01 f -1 518 21 8 0 y Project Change` t .81 Not including removed equipment • Attachment A APEN Filing Fees($1,223.20) Enterprise Compressor Station S DCP Midstream,LP 2 PAYEE NUMBER' CHECK NUMBER °r D0279938 Denver,Ccbrado:60202 APCustom€senSioeedepmidyYreRm.00m PAYEE NAME 303.605.2219IP CHECK DATE COlAFiADO- 03/19111 INVOICE NUMBER INVOICE DATE NETAMOUNT DESCRIPTION i Enterprlse3TurboUpgr 03121/11 458.70 'return Check to Wes Hill , r • • TOTAL PAID 5458.70 , .-, PLEASERETAN FOR YOUR RECORDS xa7HC ACE •FT7IS DOCUI76fJT HAS CO'OR[D EACV "NOUN. RJ WIIrTF q E W'TH VISI LC FI ERS 4r ,AI'HUEI TE7D,7g9F.ONTHE REVERSE b" srns�7Y4 JlrJo uP b4l LYC S-Jct a\�� Y� x 1 1 "LF f 4 A �.i ''z t N 1 ,,z,, Q I v` '+l�y'YaN I r;do nP''' ' r (663=19\g ,I i, � ' A<+a ,: M �,`• p f \ i I t f -O' 19RFp.-n'F W1 ,c- /yam �� g W. ti r a , y�g� " .C99GS$' • \!\i��trd �l 1� � � r - i '�> I-+ lr ?, ��fY4�� -.� 'r sy' $� t }k ms`s�e { { _ T -uJ t�' %1 FI _ t 7 yy ' li t \?, � •� > y i...x ' � ; �� ; ; I f '�'! 1 HO� �lattA J -'y:: :.4!r��g4$$r.7D 'ai4>yyr /; 1,, °� u* 4y�, ,CD„.4§ti</W\FIJ1T r1 -' y \ c 1 # • i. 4, £tCflR bU5'H r J �' �e.-ot r AAY R „ , • , iii �t�� t\ff,r�(.,,'lr r Sl t �C'[\' \,,P i�it , Q�ii4 RUT;,;.: `.SIGMA?URE HOLC 6ET1 ECIJ THUf.'R ANA FUH▪ EFINGER PRE THE OIJ CULO9E0 tOX,COI OH 1t ILL CISA•pE P THEN REAPVE•9- 11'00 2 7963811' t:021309379x: 60189519611' DCP Midstream,LP i PAYEE NUMBER CHECK NUMBER 370 17th Street,Suite 2500 0000074502 00302845 Denver,Colorado 80202 APCustomerServiceedcpmidstream.corn PAYEE NAME CHECK DATE 303.6052219 COLORADO 09/14/11 al � INVOICE NUMBER INVOICE DATE NET AMOUNT DESCRIPTION ENTERPRISECAT3616APE08/13/11 152.90 return check to Wes Hill I / r i i • j TOTAL PAID $152.90 I I PLEASE RETAIN FOR YOU RECORDS f THEr•CE •FTHIS IX) UfiEIJT HASAC•LORE sACKG •UH• IMVJITII\9SI LE FIRFF4 IJUAIRUE L7gTERP:IARY•WTHE RE\ RSE SI,E. f[�,,vl)T lam.• � � .- O;EP MaHs1.�m,LP ' ' / ' jFNP�aanrl.•.iimr G,x . :� ,0:17th8oeead,ouiie?COQ �. slp'.wr•NhV�o1k -an vsv/us eni•F g detreatten% itlett ki.I*741, ,140XitC4iliti AtkCiektENSi 1.O THE ORDER:DF 0000074502 : 09/14/1X loo3o2845 . ! . 000 o o 4 .t$! ' Yf OpI RAD{J NO1'N6CO'17AELEA1!rERi20DAYS ***"°A•S152.90 D,EPTOFPUBLICCHLTH&€NYRNIVINT f Ain?Oil CN D:IL giv APCD:SSB7 4300 CH ERRY:CREEKDR,SOUTH penYer O-80246-1530 One;waked Aft),Aivo and 90/100 Dollars ��n�ZEosbNaTURB HOLU RETP✓EEI THULIH •IJD FOREFITGE •R =•E THE ON COLORC'1 R0% COLON V'JELL PISA•PEAR.THEN REA•PFAR. � s•M�_ tt'00302845ti' I:0213093791: 60LB95196tt' DCP Midstream,LP PAYEE NUMBER CHECK NUMBER 370 17th Street,Suite 2500 0000074502 00288876 Denver,Colorado 80202 APCuetomerServiceedcymidstream.00m PAYEE NAME i CHECK DATE 303.6052219 \ ` i COL 0RADO- 05/31/11 IIP .INVOICE NUMBER INVOICE DATE NET AMOUNT DESCRIPTION EnterpriseFugTanlcAPE 05/24/11 305.80 CDPHE APEN Fees for Enter ( I / I 1 + \ i i \ TOTAL PAID , $305.80 PLEASE RETAIN FOR YOUR'RBCOROS 1 �}� IREIFACE OFTIII •OCUl9FNTi.KSACOLORED ACKG ODUp�N Y.HIIE PAPER 1'JITIIUSL LE FI6C S WHAT OF IJATE 1h7ARKU IRE•[VERSES1 'rr7r+ .'0141 \t < + ;JPAbr9M4fi®eO+iS NA ;y 93f t y -- NAusWNau YogO , fi}Y}` p r I x�`� r xsa a YtiYftEJ��Y� 310 8 00 14502; M&31/11, 00288876 . - noT7VEr Anit,-*.rStO01)AYt; aAt►'t"S305.80 cO DRAO(k CEPf FRI LIC1 L ENVIdNM 1T /*3R oubN3•JRL 151VArct $SB1' y130G1 CH�RRY:Cq�F�I[DFI SOUTH" ; Den er;CO8D246.1530 Three Au-Weld Pie mrd Sal 00Doflard n+oR zEo steruTuyE HILl .ETWEENTHUMI ANr FOREFINGER •• R•F•THF sNCr�OREo sux COLORWJLL r15 PEAR,THEN Rte•+PEA • ue002888'76u■ I:0 21, 309379i:1, 3093 79ii: '60 189 5 196k° DCP Midstrea/m,LP PAYEE NUMBER CHECK NUMBER 370 17th Street,9uIe 2500 0000074502 00303006 Denver,Cobrado 20202 I APCustomerServiea®dcpmiJstream.com PAYEE NAME CHECK DATE 303.605.2219 COLORADO 09/15/11 • INVOICE NUMBER INVOICE DATE NET AMOUNT DESCRIPTION EnterprlseDehyAPEN09 09/13/11 152.90 return check to Wes Hill I, I / 1 N. I l • i 1 TOTAL PAID ! $162.90 \i PLEASE RETAIN FOR YOUR RECORDS 1)(`.1�1YI1415tman Lp S '°-'937/213 37&171M Midstream, ese3500 _ •'f[Wi1001 d 111 CURT t 6; a� ?g� 4 �7' C:E '303,GOS.ZT19 �. -' zc+e ��,TS„n, x .: $ � '%„�; bROEItOF 000004502 09/15/11 J03THE 90303006 pQpAy gg 9 hw : 0NLS( � 1.�� 90 l�www�"�, �� Yt�`.e> a •_ I but s.r uP3.rs". 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"77.7I�ik..irjU r-:s�?7-�tT_t:>••fAli'ti0 :TSi1-"1•ii""L30"—':��371• �0, O PP pb0 i r^-773•'Ite 'L .±ra>>> -MNI '1.5•:P raIN .'°""r;l ion nll '1��=y>.>f�;'=?•;>•iy<%F:f•�-,:.,f• [1�p>>f it 1L.^`_�.!•�'T r-s '1I' •OOP 51110 f"^"�^>_ilf'1�31"•.�^'.r3�r =L1•iz'.3'� o „>•11110 MW-F- _ I OOP OP O 0 OT:p•PPM =NO>f<43'_-"I=-P >>C r I a�f• Q P,vp EE aan>>>> 4'r•p'.�:>• Eff 0O �i tppt.p fl t7 __ r711flE fiaj_>ftiI1Z:17�>>>>R�tili p'.'..—aria PO pn=nn>>fEEEli lSt�U:IA��ttsdi�O rte! 'UnwlMed MOnon twNn tens Halt..Nabbum(IYB)njrin Imm EPA AP-42 Cowart;Tabs 12.1 monks,welt Nr nMnawenenaiMe rd311M.per CWWG P%PVMn Nat • CCPNPoMaa'.LP 10a4/2011 i • Gas G3612 CATERPILLAR. Petroleum bhp 2383-2647 bkW Engine 900-1000 rpm •;;;;o; ';5 ,, ; 1 .t -c..2- C_ CATERPILLAR° ENGINE SPECIFICATIONS et > e4M V-12, 4-Stroke-Cycle j'K• Jt x Bore—in (mm) 1t8(300) :•s. ,...4-4 ,�.,li. .tryt, _ Stroke—in (mm) 11.8 (300) ? Displacement—cu in (L) 15,528(254.4) y , F _._:•,f•.r Aspiration Turbocharged and Aftercooled EL Capacity for Liquids—U.S.gal(1.1s1 .' Joacket Water Circuit' 177(669) i "" }}Ltit , _ Aftercooler Circuit 17 (64) . r Lube Oil System(refill) 272 (1030) ,,•� i ". - - Shown with Package Shipping Weight Optional Equipment (Dry) —lb(kg) 55,300(25 084) 'Engine Only FEATURES ■ FULL RANGE OF ATTACHMENTS ■ G3612 • Wide range of bolt-on system expansion • Low emissions attachments,factory designed end tested • Broad operating speed range and • UNMATCHED PRODUCT SUPPORT ability to burn a wide spectrum of OFFERED THROUGH WORLDWIDE gaseous fuels CATERPILLAR DEALER NETWORK • Caterpillar Advanced Digital Engine • • More than 1,500 dealer outlets Management(ADEM Ill)control system • Caterpillar factory trained dealer with detonation-sensitive timing control technicians service every aspect of your for individual cylinders petroleum engine - Robust diesel strength design provides • 99.7% of parts orders filled within 24 prolonged life and lower owning and hours—worldwide operating costs. • Caterpillar parts and labor warranty M TESTING • Preventive maintenance agreements • Prototype testing on every model: available for"repair before failure" — proves computer design options — verifies system torsional stability • Scheduled Oil Sampling(S•O•S°'') -functionality tests every model program matches your oil sample • Every Caterpillar engine is dynamometer against Caterpillar set standards to tested under full load to ensure proper determine: engine performance. - internal engine component condition • WEB SITE - presence of unwanted fluids • For additional information on all your - presence of combustion by-products " petroleum power requirements,visit • SINGLE-SOURCE SUPPLIER www.cat-oilendgas,com. • • Caterpillar: —casts engine blocks, heads, cylinder liners,and flywheel housings — machines critical components — assembles complete engine •v • �� Ownership of these manufacturing Q D processes enables Caterpillar to produce u A OW highquality,dependable product. IS CERTIFIED • Factory-designed systems built at • Caterpillar ISO certified facilities rEHWO814-01 • CATERPILLAR' G3612 GAS PETROLEUM ENGINE FACTORY INSTALLED STANDARD & OPTIONAL EQUIPMENT SYSTEM STANDARD OPTIONAL Air Inlet Air cleaner—standard-duty Heavy-duty air cleaner with precleaners Inlet air adapter Heavy-duly air cleaner with rain protection Charging System Charging alternators Control System Caterpillar ADEM Iii control system Custom control system software is available provides electronic governing integrated for non-standard ratings.Software is field with air/fuel ratio control and individual programmable using flash memory. cylinder ignition timing control Cooling System Jacket water pump Expansion tank Jacket water thermostats end housing Flexible connections Afterceoler pump Jacket water heater Aftercooler water thermostats end housing Single-stage aftercooler Exhaust System Dry wrapped exhaust manifolds Flexible bellows adapters Vertical cutlet adapter Exhaust expander Weld flanges Flywheel/ SAE No.00 flywheel Flywheel Housing SAE No.00 flywheel housing SAE standard rotation • Fuel System Gas admission valves with electronically Fuel filter centrofled fuel supply pressure Gas pressure regulator Flexible connection Low energy fuel system Corrosive gas fuel system Ignition System ADEM III control system senses iddIvidual CSA certification cylinder detonation and controls Individual cylinder timing Instrumentation LCD display panel monitors engine Remote data monitoring and speed control parameters and displays diagnostic codes Compatible with Cat Electronic Technician IET) and Data View Customer Communication Module(CCM) Display panel deletion is optional tube System Crankcase breathers Imp mounted) Air or electric motor-driven prelube Oil cooler Duplex oil filter Oil filter LH or RH service OII pen drain valve Lube oil makeup system Mounting System Engine mounting feet(six total) Mounting plates(set of six) Power Take-Offs From stub shafts Protection Electronic shutoff system with purge cycle Crankcase explosion relief valves Gas shutoff valve Starting System Air starting system Air pressure reducing valve Natural gas starting system General Paint,Caterpillar yellow Engine barring device • Vibration dampers Damper guard • 1EHW0e14-01 • G3612 GAS PETROLEUM ENGINE CATERPILLAR' TECHNICAL DATA G3612 Gas Petroleum Engine—900-1000 rpm DM5312410 DM5310A0 Engine Power @ 100%Load bhp(bkW) 3195(2383) 3550(2847) @ 76%Load bhp(bkW) 2397(1787) 2662(1985) Engine Speed rpm 900 101)0 SCAC Temperature °F re 130(54) 130(54) Compression Ratio 9.0:1 9.0:1 Emissions* NO, g/bhp-hr 0.70 0.70 CO g/bhp-hr 2.60 2.50 Total Hydrocarbons g/bhp-hr 6.65 6.15 Fuel Consumption @ 100%Load Btwbhp-hr(114J/bkW-hr) 6,570(9.30) 6,760 19.57) @ 76%Load Btu/bhp-hr(MJ/bkW-hr) 6,805(9.63) 7,050(9.981 Haat Balance Heat Rejection to Jacket Water @ 100%Load Btu/mn IbkW) 32,168(566) 38,195(536) @ 75%Load Btu/mn(bkW) 26,721 1505) 31,271(550) 41, Heat Rejection to Aftercooler @ 100%Load Btu/mn(bkW) 21,222(3731 26,6091468) @ 75%Load Btu/mn(him) 9,333(164) 14,526 1255) Heat Rejection to Exhaust @ 100%Load Btu/mn(bkW) 134,721 (2389) 154,673(2720) @ 75%Load Btu/ran(bkW) 107,091(1883) 123,769(21781 Exhaust System Exhaust Gas Flow Rate @ 100%Load elm(m'/min) 20,634(584) 23,461 (864) @ 75%Load dm Im'/min) 16,100(456) 18,554(525) Exhaust Stack Temperature @ 100%Load °F(°C) 846(462) 858(459) @ 75%Load •F(°C) 867(484) 878(4701 Intake System Air Inlet Flow Rate @ 100%Load cfm Imyminl 8,527(241) 9,5981272) @ 75%Load cfm(m'/min) 8,642(185) 7.477(212) Gas Pressure psi(kPa) 43(298) 43(2951 'hat 100%load and speed • LEHW0e14-01 • CATERPILLAR' G3612 GAS PETROLEUM ENGINE GAS PETROLEUM ENGINE 186.42 93.68 1x735.11 r 12379.51 art, t I 6218 12- I l •�1 •F 1a / a ATE F a �y s►• 1_•', F� /=^lS��r tai lc:� ' —� , �� 126.77 �'� 1e,' kt ylil�+� "7�11Sj.I ^J �i". 13219.91 Ic '� (, 1 • , f1l�r0 • (C.)0 ?i'4 1 •.\ ■e'feria • 1 DIMENSIONS Note: General configuration not to be used Length in Imm) 186.42(4735.1) for installation. See general dimension drawings for detail. Width inlmm) 93.68(2379.5) Height in(mm) 126.77 43219,91 Shipping Weight lb(kg) 55,300(26 0841 RATING DEFINITIONS AND CONDITIONS Engine performance is obtained in accordance Conditions:Power for gas engines is based on with SAE J1995, ISO3046/1, BS5514/1, and fuel having an LHV of 905 Btu/cu ft 133.74 kJ/L) DIN6271/1 standards. at 29.91 in. Hg(101 kPa)and 59°F (15°C). Fuel Transient response data is acquired from an rata is based on a cubic meter at 29.61 in. Hg engine/generator combination at normal 1100 kPa) and 60.1° F(15.6°C).Air flow Is • based on a cubic foot at 29.61 in. Hg (100 temperature and in accordance with .4 kPa) 19O3046/1 standard ambient conditions.Also in and 77°F (25°Cl. Exhaust flow is based on 8 accordance with SAE J1995, BS5514/1,and cubic foot at 29.61 in. Hg (100 kPa)and stack DIN6271/1 standard reference conditions. temperature. M TMI Reference No.:DM5512-00,DM5310.00 Materials and specifications ere subject to chenille without notice. The Imernationel System of Units 181)is used in this publication.LEFIWO8740118•01) Printed in U.S.A. 102001 Caterpillar MI rights reserved. Ape? 14:51 DCP MIDSTREAM 4 913036651959 N0.689 p0.3 ._.,. n.. ,e ,-�.•v.e� c nv_anvunrunn Icv euud1oua A • v EAS, Incorporated 685 Saddle Ridge Crystal Lake, IL 60012 January 25, 2005 Duke Energy Field Services Duke Energy Field Service* Mr.David Stultz Mr. Frank Watson Greeley CO Denver,CO SENT VIA EMAIL ••Subject: Slide in Silencer Design for Weld County G3612 MS Proposal 050125.3 ....ii . Gentlemen, The haltense: To find a combination silencer that can be lowered into an existing framework at the jobsite. The framework sketch shows an inside area that is 45"square. The diagonal measurement of this is 63.6". The combination unit we offer will fit into tht rack. The best perfonnance we can provide in this diameter is industrial grads. Based on the information,we are honored to offer the following proposal: Engine Under CAT 3912TAL.O I HAP 3550 All engine date used from Caterpiuer Data Set DM5320 RPM 900' 04 April 8,2004 Exhaust Flow ACM 23,809 Temperature(F) 858 This information is the sole basis for sizing and Calculated SCFM 9500 pesformance$uarantees. • Post Catalyst Emissions Pro-Catalye111ntreated Emissions from Engine Ingnbhpor. . (grrph}ry or ea staled) aMp a nr ORE%(Reduction from FyCataest Vain) My Nox na CO 2.5 CO 83% •NMHC 0.92 •NMHC am% NANNEHC (L61 NMNEHC '80% HCHO• D.4 HCHO >ea% CATALYST DESCRIPTION . Catalyst ADCAT All SS Metal Monolith Yes Catalyst Type CO. HCHO Oxidation And Telescoping draping Yes Catalyst Sin 4 ea 21"sq. x a6 dp Precious Metals by Weight Yes CPSI 280 Outer SS Band for Frame) Yes Handle nfa —Procoated Material NONE ' . COMBINATION SILENCER DESCRIPTION Nominal Outside Diameter '81" Qenemml Divide Designation Industriar Approximate Length •200" cbA reduction 18-Dec Material C3 Backpressure tbd High Temp Paint (not for 55) yes Double Wall Construction 1st chamber blot Flange Size 18" Drain Plug yes outlet Flange Size 28" End in-End Out Style yes Total Test Ports 6 Mounting 4 hertz.Adj. lugs •• 1 neataeh 599,942 . A C Lead Time: 8 weeks after prints approved or about 12 weeks total ARO. 1>H° Taluphane 815-144-0201 Foe 015-444.ODUC £mail! Indlan@me.net Wabdle: sans n k,G.mn Alr Pallulbn Control Systems ana Cencultine Services OM wept Recovery PTO's.VOC.CO.DlaOel S NSCR Catalysto • Precious MI MI Recovery,System Upgrades.Va4eh a Silence:S.Catalytic Oxlbzere , Exhaust Silencer Concept • Weld County G3612LE Project Ladderless Catalyst A 01-10-05 EAS, Inc. No Scale 450 I' Frei Insert'n 0Q Band Loss 98" lc Type 2 Test Ports 31.5 Hz 16 dBA 6" 63 31 125 38 V 250 36 r I Flexible Design 500 32 28"-p. Inlet Location to ----- Minimize Backpressure 1K 30 from Pipe Bends 2K 29 ' - + 4K 28 A. 28"dia. 8K 28 - 't' Fomposite Reduction-35d6 Flexible • -- to 216" Notes: Delta P: 57 Imo.total . 72' Weight:-9,800 pound Carbon Steel w/ 1200F rated 362" Aluminized Paint Catalyst location.... —LA behind access doors near grade Base Skirt with holes on Ring • Drain V) I 78" ► EAS, Inc. 685 Saddle Ridge Crystal Lake, IL 60012 815-444-0291 Indian iimc.net Dennis Kosirzewski Natural Gas Turbine Enterprise Compressor Station DCP Midstream, LP iSource ID T1 Stack Height ft Description Turbine 1 - Stack Temp. deg F Manufacturer Solar Stack Flow acfm Model Taurus 70 Stack Velocity ft/min Serial# TBD Stack Base ft AMSL Operation Date TBD Emission Control None Latitude deg Longitude deg Fuel Heat Value 958 Btu/scf or Design Output 10,142 HP UTM Zone Site Output 10,142 HP UTM Northing m Potential Operation 8760 hr/yr UTM Easting m Potential Heat Rate 7272 Btu/hp-hi Datum Potential Heat Rate 73.75 MMBtu/hr Potential Fuel Use 76983 scf/hr Potential Fuel Use 674.37 kilAscf/yr Potential to Emit Emission Emission Source of CAS Factor Factor Emission Pollutant Number (lb/MMBtu) (g/hp-hr) (lb/hr) (lblyr) (ton/yr) Factor NOx — 0.1982 4.43 38820.90 19.41 Mani Spec CO — 0.2012 , 4.50 39408.50 19.70 Manf Spec VOC — 0.1152 2.58 22563.91 11.28 Manf Spec SO2 0.0034 0.25 2196.57 1.10 AP-42 PM 0.0066 0.49 4263.93 2.13 AP-42 1,3-Butadiene 106-99-0 4.3E-07 3.17E-05 2.78E-01 1.39E-04 AP-42 Acetaldehyde 75-07-0 4.0E-05 2.95E-03 258E+01 1.29E-02 AP-42 Acrolein 107-02-8 6.4E-06 4.72E-04 4.13E+00 2.07E-03 AP-42 Benzene 71-43-2 1.2E-05 8.85E-04 7.75E+00 3.88E-03 AP-42 • Ethylbenzene 100-414 3.2E-05 2.36E-03 2.07E+01 1.03E-02 AP-42 Formaldehyde 50-0D-0 7.1E-04 5.24E-02 4.59E+02 2.29E-01 AP-42 Naphthalene 91-20-3 1.3E-06 9.59E-05 8.40E-01 4.20E-04 AP-42 PAH 2.2E-06 1.62E-04 1.42E+00 7.11E-04 AP-42 Propylene Oxide 75-58-9 2.9E-05 2.14E-03 1.87E+01 9.37E-03 AP-42 Toluene 108-88-3 1.3E04 9.59E-03 8.40E+01 4.20E-02 AP-42 Xylenes 1330-20-7 6.4E-05 4.72E-03 4.13E+01 2.07E-02 AP-42 Total HAPs 7.58E-02 6.64E+02 3.32E-01 AP-42: NOx&CO:EPA AP-42,Volume I,Fifth Edition,April 2000,Table 3.1-1. VOC,S02,PM:EPA AP-42,Volume I,Fifth Edition,April 2000,Table 3.1-2a. HAPs:EPA AP-42,Volume I,Fifth Edition,April 2000,Table 3.1-3. Solar Turbines PREDICTED EMISSION PERFORMANCE • A Caterpillar Company Customer Engine Model DCP-Midstream TAURUS 70-10302S Job ID CS/MD 59F MATCH Weld County Compression Inquiry Number Fuel Type Water Infection DN11-0028 SD NATURAL GAS NO Run By Date Run Eghe Emissions Data Michael E Clay 26-Sep-11 REV.0.1 NOx EMISSIONS CO EMISSIONS UHC EMISSIONS 1 101212 -;5000 ft ReLsHumidity 60,0%1Temperature . 0 Deg.F' PPMvd at 15%O2 15.00 25.00 25.00 ton/yr 19.41 19.70 11.28 lbm/hr 4.43 4.50 2.58 gl(Hp-hr) 0.20 0.20 0.12 (gas turbine shaft pwr) • -0485,142.::' ''100014 Load ?EieV: "8000 ftl Re] Humidity:'60.0% •Temperature'. 20,0 Deg,:F PPMvd at 15%O2 15.00 25.00 25.00 ton/yr 18.41 18.68 10.70 Ibmlhr 4.20 4.27 2.44 g/(Hp-hr) 0.20 0.20 0.12 • (gas turbine shaft pwr) a l=tat 008.ft° .Re)Humidity ?. 80 ed�a emperalpt4 aiO gDeg:F; PPMvd at 15% O2 15.00 25.00 25.00 ton/yr 17.36 17.61 10.09 Ibm/hr 3.96 4.02 2.30 g!(Hp-hr) 0.20 0.21 0.12 (gas turbine shaft pwr) Nolen 1. For short-term emission limits such as lbs/hr., Solar recommends using"worst case"anticipated operating conditions specific to the application and the site conditions. Worst case for one pollutant Is not necessarily the same for another. 2. Solar's typical SoLoNOx warranty,for ppm values,is available for greater than 0 deg F, and between 50%and 100% load for gas fuel,and between 65% and 100%load for liquid fuel(except for the Centaur 40). An emission warranty for non-SoLoNOx equipment is available for greater than 0 deg F and between 80%and 100%load. 3. Fuel must meet Solar standard fuel specification ES 9-98. Emissions are based on the attached fuel composition,or,San Diego natural gas or equivalent. 4. If needed,Solar can provide Product Information Letters to address turbine operation outside typical warranty ranges,as well as non-warranted emissions of SO2,PM10/2.5,VOC,and formaldehyde. 5. Solar can provide factory testing in San Diego to ensure the actual unit(s)meet the above values within the tolerances quoted. Pricing and schedule impact will be provided upon request. 6. Any emissions warranty is applicable only for steady-state conditions and does not apply during start-up, shut-down,malfunction, or transient event • Solar Turbines PREDICTED EMISSION PERFORMANCE • A Caterpillar Company Customer Engine Model DCP-Midstream TAURUS 70.10302S Job D CS/MD 59F MATCH Weld County Compression Inquiry Number Fuel Type Water Injection DN11-0028 SD NATURAL GAS NO Run By Date Run Engine Emissions Data Michael E Clay 26-Sep-11 REV.0.1 NOx EMISSIONS CO EMISSIONS UHC EMISSIONS ' 4 ,$qf0,;Npt ,.EI*Y. ,s50o0'ft `Re1:Humidity 60.0%'r Tenlperati(re 89 0„peg:F PPMvd at 15%O2 15.00 25.00 25.00 ton/yr 16.14 16.37 9.38 Ibm/hr 3.68 3.74 2.14 g/(Hp-hr) 0.21 0.21 0.12 (gas turbine shaft pwr) 5"_ 7.279'HA , . -19tl.(1%Load. .Elev. 5p00ff{ ;Rat: Humidity: "lo.ileh Temperitufp 80itD 0'F PPMvd at 15%O2 15.00 25.00 25.00 ton/yr 14.88. 15.09 8.64 Ibm/hr 3.40 3.45 1.97 M g/(Hp-hr) 0.21 0.21 0.12 (gas turbine shaft pwr) 6=- S,5g iSta ✓rtz'Sa . Etevi sgoo fttsgi Humidity 60 D"{,r Tempetatu eti100 :O11 `F. PPMvd at 15%O2 15.00 25.00 25.00 ton/yr 13.70 13.90 7.96 Ibm/hr 3.13 3.17 1.82 g/(Hp-hr) 0.22 0.22 0.13 (gas turbine shaft pwr) Notes 1. For short-term emission limits such as lbs/hr.,Solar recommends using"worst case"anticipated operating conditions specific to the application and the site conditions. Worst case for one pollutant is not necessarily the same for another. 2. Solar's typical SoLoNOx warranty,for ppm values,Is available for greater than 0 deg F,and between 50% and 100%load for gas fuel,and between 65%and 100%load for liquid fuel(except for the Centaur 40). An emission warranty for non-SoLoNOx equipment is available for greater than 0 deg F and between 80% and 100% load. 3. Fuel must meet Solar standard fuel specification ES 9-95. Emissions are based on the attached fuel composition, or, San Diego natural gas or equivalent. 4. If needed, Solar can provide Product Information Letters to address turbine operation outside typical warranty ranges,as well as non-warranted emissions of SO2, PM10/2.5,VOC,and formaldehyde. 5. Solar can provide factory testing in San Diego to ensure the actual unit(s) meet the above values within the tolerances quoted. Pricing and schedule impact will be provided upon request. 6. Any emissions warranty is applicable only for steady-state conditions and does not apply during start-up, shut-down, malfunction,or transient event. I Sear Turbines PREDICTED ENGINE PERFORMANCE • A Caterpillar Company Customer Model TAURUS 70-10302S DCP-Midstream Package Type CS/MD Job ID Match Weld County Compression 59F MATCH Run By Date Run Fuel System Michael E Clay 26-Sep-11 GAS Engine Performance Code Engine PerImmense Data Fuel Type REV.3.53 REV.0.6 SD NATURAL GAS DATA FOR MINIMUM PERFORMANCE Elevation feet 5000 Inlet Loss in H2O 4.0 Exhaust Loss in H2O 4.0 Accessory on GP Shaft HP 26.0 Engine Inlet Temperature deg F 0 20.0 40.0 60.0 80.0 100.0 Relative Humidity % 60.0 60.0 60.0 60.0 60.0 60.0 Driven Equipment Speed RPM 11267 11193 11086 10950 10786 10575 Specified Load HP FULL FULL FULL FULL FULL FULL • Net Output Power HP 10142 9485 8811 8060 7279 6512 Fuel Flow mmBtu/hr 73.75 70.01 66.13 61.73 57.36 53.56 Heat Rate Btu/HP-hr 7272 7381 7506 7660 7879 8224 Therm Eff % 34.992 34.473 33.900 33.219 32.292 30.938 Engine Exhaust Flow ibm/hr 205291 194310 183473 172525 160381 148996 PT Exit Temperature deg F 860 886 909 929 953 982 Exhaust Temperature deg F 860 886 909 929 953 982 Fuel Gas Composition Methane(CH4) 92.79 (Volume Percent) Ethane(C2H6) 4.16 Propane(C3H8) 0.84 N-Butane(C4H10) 0.18 N-Pentane(C5H12) 0.04 - Hexane(C6H14) 0.04 Carbon Dioxide(CO2) 0.44 Hydrogen Sulfide(H2S) 0.0001 Nitrogen(N2) 1.51 Fuel Gas Properties LHV Btu/Scf) 939.2 Specific Gravity 0.5970 Wobbe Index at 60F 1215.6 This performance was calculated with a basic inlet and exhaust system. Special equipment such as low noise silencers, special filters, heat recovery systems or cooling devices will affect engine performance. Performance shown is"Expected"performance at the pressure drops stated, not guaranteed. Natural Gas Dehydration Enterprise Compressor Station DCP Midstream,LP • Sauce ID 0-2(D•1 no longer n operation) SayingGas? N YINDesalptbn Dehydration Unit Whet a Shipping Gas? Manufacturer TBD Shpgng Gas Flow Rate NIA scfm Model TBD Condenser? Y Yet Serial* TBD Condenser Temperate 120 deg F Operation Date TBD Conde ear Pressure 12.5 pee Operation 8760 tele Flare? Y YIN Wet Gas Temperature 120 deg F Flare Amblert AS Temp deg Wet Gas Pressure 1000 pa0 Flare Excess Oxygen % Wet Gas Water Content Saturated IbH2D/MMser Reboaerr Destruction Efficiency 95% Dry Gee Flow Rate 120 MMscfd Dry Gas Water Content 7.0 Ibh12O/Mdsd Lean Gyod Water Content 1.5 wl%H2O Lean Glycol Flow Rate 35 gpm Cold Separator? N YIN Cold Separator Temperature N/A deg F Cold Separator Pressure WA psig Glycol Pump Make 8 Model TBD Glyod Pump Type Eleclrip Sec.or Gas Glycol Pump Gas Flow Rate WA acfmrgpm Flash Tent,? Y YIN Flash Tarts Temperature 160 deg F Flash Tents Pressure 30 psig Flash Tank Control recycled wNRU Total Emissions from GWGLYCalc Un onhaled Corboled CAS Emissions Emissions Paaulenl Number (IoM) (Ib/r) 09Y) (lb/hr) (Ib/yr) (toy) VOC 183.35 1693724.00 846.88 3.47 1831020 9.16 n-hexane 110-54-3 3.81 33354.60 16.68 0.20 413.80 0.21 Benzene 71-43-2 28.76 234391.80 117.20 0.63 4778.80 2.39 • Toluene 108-88-3 91.71 277820.20 138.91 0.79 2798.20 1.40 E86dbur¢ans 100-414 O.83 7282.00 3.09 0,03 27.40 0.01 ?Wiens 10.52 92144.80 46.07 0.40 283.20 0.14 Total HAP 73.63 644973.40 322.49 2.06 8301.20 4.15 Note: The uncontrolled values Studs both flesh and overhead sell veal streams. The flesh stream I eontrdled vAlh a VRU O100%control. The eh yen steam at sent toe condenser and then uncondensed overheads tee combusted @ 95%cared.accounted for watt the condenser. • DCP Midstream,LP 10/21/2011 Natural Gas Dehydration Flash Tank Off Gas Stream Detail from GRI GLYCalo • Description Deity Flash Task Vent Flash Tank Vent Recycled Vent Flow Rate 0.0 so9hr Hours of operation 8760 Myr Annual Flow Rate 0.000 MMscflyr . Pure Component Pin Component Component Fraction Corn pored Component Fraction , Component Vol% Md Fraction Mol Weight Mol Weight !.lees Fraction Heat Value Heat Value Dialb-md) (bib-md) (Bkdacf) (BMW) Methane 0.000 0.0000 16.04 000 8044/0! 1010.0 0.0 Ethane 0.000 0.0000 30.07 0.00 ADN70f 1769.6 0.0 Propane 0.000 0.0000 44.10 0.00 9DM0! 2516.1 0.0 LButene 0.000 0.0000 58.12 0.00 *DIVAN 3251.9 0.0 n-Butane 0.000 0.0000 58.12 0.00 *DN/01 3262.3 0.0 LPemane 0.000 0.0000 72.15 0.00 *DIV/01 4000.9 0.0 *Pentane 0.000 0.0000 72.15 0.00 POMOI 4006.9 0.0 Cycloperlene 0.000 0.0300 70.13 0.00 *DIVAN 3763.6 0.D n#iezene 0.000 0.0030 86.18 0.00 SIDIV/01 4755.9 0.0 Cyolo mene 0.000 0.0000 84.16 0.00 *DN/OI 4481.6 0.0 Other Hexans 0.000 0.0000 66.18 0.00 *DIVAtt 4755.9 0.0 Hedanea 0.000 0.0000 10020 0.00 *DIV/0! 5502.5 0.0 Memykyolohexare 0.000 0.0000 96.19 0.00 *GIV10I 5215.7 0.0 2.2,4-Tdme1Mpentene 0.000 0.0000 114.23 0.00 *DMOI 6231.7 0.0 Benzene 0.000 0.0000 78.11 0.00 *DIVN! 3741.8 0.0 Tduere 0.000 0.0000 92.14 0.00 , *ONTO! 4475.0 0.0 Ethy@anzene 0.000 0.0000 108.17 000 IlDN/Ol 5222.2 0.0 XNesles 0.000 0.0000 318.50 0.00 *DIV/Ol 5208.8 0.0 Octanes+ 0.000 0.0000 11423 0.00 *DIVA)! 6248.9 0.0 0.00 0.0000 .0.00 1101V/0 0 Condenser Vent Stream Detail from GRI-GLYCeto • Description Derry Condenser Vent Vent Flow Rate 475 softhr Hours of opamdon 8760 hale Arrival Row Rate 4.181 MMad/yr Pure Component Pure Component Component Fraction Component Component Frames Cannoned Vol% Md Fraction Mol Weight Md Weight Mass Fraction Heat Value Hest Value (lWMnwl) (bibmd) (BWWsct) (Btdac) Methane 6.86 0.0688 16.04 1.10 0.0243 1010.0 69.3 Ethane 9.90 0.0990 30.07 2.98 0.0657 1769.6 176.2 Propene 11.10 0.1110 44.10 4.89 0.1080 2516.1 279.3 i46,Aare 2.44 0.0244 5612 1.42 .0.0313 3251.9 79.3 n-Bulane 8.37 0.0837 5612 4.88 0.1073 3262.3 273.1 IPertare 1.88 0.0188 72.15 1.36 0.0299 40001 75.2 *Pentane 2.67 0.0267 72.15 1.93 0.0425 4006.9 107.0 Cydopedere 1.03 0.0103 7013 0.72 0.0159 3783,9 38.8 nn--Hexane 8.75 0.0875 88.18 7.54 0.1664 4755.9 416.1 Cycbhwne 1.48 0.0148 84.16 1,25 0.0276 4481.5 68.3 aher Hexane& 1.24 0.0124 86.18 1.07 0.0236 4755.9 59.0 Heplanes 075 0.0076 10020 0.76 0.0167 55025 41.7 Mel ticWldm'aM 0.00 0.0000 9619 0.00 0.0000 52155.7 0.0 2,2.4-TrimeMPedare 0.000 0.0000 114.23 000 0.0000 6231,7 0.0 Benzene 11.20 0.1120 78.11 675 0.1930 3741.8 410A Toluene 5.54 0.0554 92.14 5.10 0.1128 4475.0 247.9 Ethyihe zene 0.047 0.0005 106,17 0.05 0.0011 5222.2 2.6 Xyleres 0A9 0.0049 318.50 1.55 0.0341 5208.8 25.3 Octanes+ 0.003 0.0000 11423 0.00 0.0001 6248.9 D.2 73.75 0.7375 45.33 1.00 2375 DCP Midstream.LP 1021/2011 • Dehydrator Flare Emissions Enterprise Compressor Station DCP Midstream, LP Supplimental Fuel for Flare 2009 MMBTU/hr Days/mo MMBTWrno Jan 0.355 31 264.3 Feb 0.250 28 168.0 Mar 0.344 31 256.1 Apr 0.261 30 188.0 May 0.125 31 92.9 Jun 0.117 30 84.6 Jul 0.146 31 108.7 Aug 0.146 31 108.8 Sep 0.140 30 1002 Oct 0.172 31 128.0 Nov 0.159 30 114.4 Dec 0.139 31 103.5 1718.0 MMBTWyT from assist gas/pilot(2009 throughput Mgest of last three years) 2000.0 MMBTUAT Round up to be conservative. 9,883 MMEITU/yr from dehy condenser overhead strewn from Oct 19,2011 GyCaic 11883.5 MMBTWyr "EF ; .Emisslops - Iphnmtnu 'i rlpn/r • NOa 0.068 0.40 CO 0.37 2.20 AP-42 Table 13.5-1 • Page: 1 GRI-GLYCalc VERSION 4.0 - AGGREGATE fAT CULATIONS REPORT • Case Name: Enterprise 120 MMSCFD File Name: H:\DCP\Enterprise\Enterprise 120 Modification and Engine Addition Sept 2011\120 MMSCFD Glycalc.ddf Date: September 14, 2011 DESCRIPTION: Description: Enterprise 120 MMSCFD 35 gpm Glycol Recirc Rate Annual Hours of Operation: 8760.0 hours/yr EMISSIONS REPORTS: CONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.0689 1.654 0.3018 Ethane 0.1864 4.473 0.8164 Propane 0.3057 7.337 1.3391 Isobutane 0.0889 2.133 0.3893 n-Butane 0.3046 7.311 1.3343 Isopentane 0.0851 2.042 0.3727 n-Pentane 0.1205 2.892 0.5278 • Cyclopentane 0.0450 1.081 0.1972 n-Hexane 0.0472 1.133 0.2068 Cyclohexane 0.0778 1.866 0.3406 Other Hexanes 0.0671 1.610 0.2938 Heptanes 0.0475 1.140 0.2080 Benzene 0.5455 13-092 2.3894 Toluene 0-3194 7.667 1.3991 Ethylbenzene 0.0031 0.075 0.0137 Xylenes 0.0323 0.776 0.1416 C8+ Heavies 0.0004 0.009 0.0016 Total Emissions 2.3455 56.292 10.2733 Total Hydrocarbon Emissions 2.3455 56.292 10.2733 Total VOC Emissions 2.0902 50.165 9.1551 Total HAP Emissions 0.9476 22.743 4.1506 Total BTEX Emissions 0.9004 21.610 3.9438 UNCONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 1.3800 33.119 6.0443 Ethane 3.7530 90.073 16.4383 Propane 6.3120 151.487 27.6465 Isobutane 1.8929 45.430 8.2911 n-Butane 6.6663 159.991 29.1984 Isopentane 2.1265 51.035 9.3139 n-Pentane 3.1181 74.835 13.6574 • Cyclopentane 1.2681 30.436 5.5545 n-Hexane 1.5873 38.095 6.9523 Page: 2 • Cyclohexane 3.1338 75.211 13.7261 Other Hexanes 1.9681 47.714 8.7078 Heptanes 2.8243 67.782 12.3703 Benzene 25.2901 606.962 110.7706 Toluene 30.4904 731.770 133.5480 Ethylbenzene 0.8090 19.415 3.5433 Xylenes 10.3376 248.103 45.2789 C8+ Heavies 5.5805 133.933 24.4428 Total Emissions 108.5581 2605.394 475.4843 Total Hydrocarbon Emissions 108.5581 2605.394 475.4843 Total VOC Emissions 103.4250 2482.201 453.0017 Total HAP Emissions 68.5144 1644.345 300.0930 Total BTEX Emissions 66.9271 1606.251 293.1407 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 50.4403 1210.568 220.9287 Ethane 43.2880 1038.912 189.6014 • Propane 34.8826 837.182 152.7857 Isobutane 7.4308 178.340 32.5471 n-Butane 20.6099 494.636 90.2712 Isopentane 6.0630 145.511 26.5558 n-Pentane 7.3251 175.801 32.0837 Cyclopentane 0.7704 18.490 3.3745 n-Hexane 2.2203 53.288 9.7250 Cyclohexane 1.1347 27.233 4.9699 Other Hexanes 3.5992 86.381 15.7645 Heptanes 2.0841 50.018 9.1282 Benzene 1.4670 35.207 6.4253 Toluene 1.2242 29.381 5.3621 Ethylbenzene 0.0200 0.481 0.0877 '" Xylenes 0.1812 4.348 0.7935 C8+ Heavies 0.9100 21.841 3.9860 Total Emissions 183.6508 4407.618 804.3903 Total Hydrocarbon Emissions 183.6508 4407.618 804.3903 Total VOC Emissions 89.9224 2158.138 393.8603 Total HAP Emissions 5.1127 122.705 22.3937 Total BTEX Emissions 2.8924 69.418 12.6687 COMBINED REGENERATOR VENT/FLASH GAS EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.0689 1.654 0.3018 Ethane 0.1864 4.473 0.8164 • Propane 0.3057 7.337 1.3391 Isobutane 0.0889 2.133 0.3893 Page: 3 • n-Butane 0.3046 7.311 1.3343 Isopentane 0.0851 2.042 0.3727 n-Pentane 0.1205 2.892 0.5278 Cyclopentane 0.0450 1.081 0.1972 n-Hexane 0.0472 1.133 0.2068 Cyclohexane 0.0778 1.866 0.3406 Other Hexanes 0.0671 1.610 0.2938 Heptanes 0.0475 1.140 0.2080 Benzene 0.5455 13.092 2.3894 Toluene 0.3194 7.667 1.3991 Ethylbenzene 0.0031 0.075 0.0137 Xylenes 0.0323 0.776 0.1416 C8+ Heavies 0.0004 0.009 0.0016 Total Emissions 2.3455 56.292 10.2733 Total Hydrocarbon Emissions 2.3455 56.292 10.2733 Total VOC Emissions 2.0902 50.165 9.1551 Total HAP Emissions 0.9476 22.743 4.1506 Total BTEX Emissions 0.9004 21.610 3.9438 COMBINED REGENERATOR VENT/FLASH GAS EMISSION CONTROL REPORT: Component Uncontrolled Controlled % Reduction tons/yr tons/yr Methane 226.9730 0.3018 99.87 • Ethane 206.0397 0.6164 99.60 Propane 180.4322 1.3391 99.26 Isobutane 40.8381 0.3893 99.05 n-Butane 119.4696 1.3343 98.88 Isopentane 35.8696 0.3727 98.96 n-Pentane 45.7412 0.5276 98.05 Cyclopentane 8.9290 0.1972 97.79 n-Hexane 16.6773 0.2068 98.76 Cyclohexane 18.6960 0.3406 98.18 Other Hexanes 24.4723 0.2938 98.80 Heptanes 21.4985 0.2080 99.03 Benzene 117.1960 2.3894 97.96 Toluene 138.9101 1.3991 98.99 Ethylbenzene 3.6310 D.0137 99.62 Xylenes 46.0724 0.1416 99.69 C8+ Heavies 28.4288 0.0016 99.99 Total Emissions 1279.8747 10.2733 99.20 Total Hydrocarbon Emissions 1279.8747 10.2733 99.20 Total VOC Emissions 846.8620 9.1551 98.92 Total HAP Emissions 322.4867 4.1506 98.71 Total BTEX Emissions 305.8094 3.9438 98.71 EQUIPMENT REPORTS: • CONDENSER AND COMBUSTION DEVICE • Page: 4 • Condenser Outlet Temperature: 120.00 deg. F Condenser Pressure: 12.50 psia Condenser Duty: 1.90e-001 MM BTU/hr Hydrocarbon Recovery: 4.94 bbls/day Produced Water: 32.77 bbls/day Ambient Temperature: 0.00 deg. F Excess Oxygen: 0.00 % Combustion Efficiency: 95.00 % Supplemental Fuel Requirement: 1.90e-001 MM BTU/hr Component Emitted Destroyed Methane 4.99% 95.01% Ethane 4.97% 95.03% Propane 4.84% 95.16% Isobutane 4.70% 95.30% n-Butane 4.57% 95.43% Isopentane 4.00% 96.00% n-Pentane 3 .86% 96.14% Cyclopentane 3 .55% 96.45% n-Hexane 2.97% 97.03% Cyclohexane 2.48% 97.52% Other Hexanes 3.37% 96.63% Heptanes 1.68% 98.32% Benzene 2.16% 97.84% Toluene 1.05% 98.95% Ethylbenzene 0.39% 99.61% Xylenes 0.31% 99.69% 08+ Heavies 0.01% 99.99% • 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: 6.28 lbs. H2O/MMSCF Temperature: 120.0 deg. F Pressure: 1000.0 psig Dry Gas Flow Rate: 120.0000 MMSCF/day Glycol Losses with Dry Gas: 7.5902 lb/hr Wet Gas Water Content: Saturated Calculated Wet Gas Water Content: 102.41 lbs. H2O/MMSCF Calculated Lean Glycol Recirc. Ratio: 4.37 gal/lb H2O Remaining Absorbed Component in Dry Gas in Glycol Water 6.12% 93.88% Carbon Dioxide 99.64% 0.36% Nitrogen 99.96% 0.04% Methane 99.97% 0.03% Ethane 99.91% 0.09% Propane 99.88% 0.12% Isobutand 99.85% 0.15% n-Butane 99.81% 0.19% • Isopentane 99.83% 0.17% n-Pentane 99.79% 0.21% Page: 5 • Cyclopentane 99.08% 0.92% n-Hexane 99.70% 0.30% Cyclohexane 98.65% 1.35% Other Hexanes 99.76% 0.24% Heptanes 99.52% 0.46% Benzene 89.65% 10.35% Toluene 87.20% 12.80% Ethylbenzene 85.19% 14.81% Xylenes 80.22% 19.78% C8+ Heavies 98.73% 1.27% FLASH TANK Flash Control: Recycle/recompression Flash Temperature: 160.0 deg. F Flash Pressure: 30.0 psig ' Left in Removed in _ Component Glycol Flash Gas Water 99.83% 0.17% Carbon Dioxide 20.69% 79.31% Nitrogen 2.58% 97.42% Methane 2.66% 97.34% Ethane 7.98% 92.02% Propane 15.32% 84.68% Isobutane 20.30% 79.70% n-Butane 24.44% 75.56₹ • Isopentane 26.34$ 73.66% n-Pentane 30.21% 69.79% Cyclopentane 62.40% 37.60% n-Hexane 41.98% 58.02% Cyclohexane 74.27% 25.73% Other Hexanes 36.23% 63.77% Heptanes 57.75% 42.25% Benzene 94.79% 5.21% Toluene 96.44% 3.56% Ethylbenzene 97.84% 2.16% Xylenes 98.50% 1.50% C8+ Heavies 87.67% 12.33% REGENERATOR No Stripping Gas used in regenerator. Remaining Distilled Component in Glycol Overhead Water 38.07% 61.93% Carbon Dioxide 0,00$ 100.00% Nitrogen 0.00$ 100.00% Methane 0.00% 100.00% Ethane 0.00% 100.00% Propane 0.00% 100.00% Isobutane 0.00% 100.00% n-Butane 0.00% 100.00% • Isopentane 1.90% 98.10% n-Pentane 1.66% 98.34% Page: 6 • Cyclopentane 0.80% 99.20% n-Hexane 1.19% 98.81% Cyclohexane 4.31% 95.69% Other Hexanes 2.76% 97.24% Heptanes 0.87% 99.13% Benzene 5.28% 94.72% Toluene 8.19% 91.81% Ethylbenzene 10.64% 89.36% Xylenes 13.13% 86.87% C8+ Heavies 13.72% 86.28% STREAM REPORTS: WET GAS STREAM Temperature: 120.00 deg. F Pressure: 1014.70 psia Plow Rate: 5.01e+006 scfh Component Conc. Loading (volt) (lb/hr) Water 2.16e-001 5.13e+002 Carbon Dioxide 2.65e+000 1.54e+004 Nitrogen 3.19e-001 1.18e+003 Methane 7.34e+001 1.56e+005 Ethane 1.34e+001 5.33e+004 Propane 5.75e+000 3.35e+004 Isobutane 8.10e-001 6.22e+003 n-Butane 1.87e+000 1.44e+004 Isopentane 4.99e-001 4.76e+003 n-Pentane 5.13e-001 4.89e+003 Cyclopentane 2.39e-002 2.22e+002 n-Hexane 1.12e-001 1.28e+003 Cyclohexane 2.85e-002 3.17e+002 Other Hexanes 2.06e-001 2.35e+003 Heptanes 7.80e-002 1.03e+003 Benzene 2.50e-002 2.58e+002 Toluene 2.04e-002 2.48e+002 Ethylbenzene 3.99e-004 5.60e+000 Xylenes 3.79e-003 5.32e+001 C8+ Heavies 2.26e-002 5.10e+002 Total Components 100.00 2.96e+005 DRY GAS STREAM Temperature: 120.00 deg. F Pressure: 1014.70 psia Flow Rate: 5.00e+006 scfh Component Conc. Loading (volt) (lb/hr) Water 1.32e-002 3.14e+001 • Carbon Dioxide 2.65e+000 1.54e+004 Nitrogen 3.20e-001 1.18e+003 Page: 7 Methane 7.36e+001 1.56e+005 Ethane 1.34e+001 5.32e+004 Propane 5.76e+000 3.35e+004 Isobutane 8.11e-001 6.21e+003 n-Butane 1.87e+000 1.43e+004 Isopentane 5.00e-001 4.75e+003 n-Pentane 5.13e-001 4.88e+003 Cyclopentane 2.38e-002 2.20e+002 n-Hexane 1.12e-001 1.27e+003 Cyclohexane 2.82e-002 3.13e+002 Other Hexanes 2.06e-001 2.34e+003 Heptanes 7.79e-002 1.03e+003 Benzene 2.25e-002 2.32e+002 Toluene 1.78e-002 2.16e+002 Ethylbenzene 3.41e-004 4.77e+000 Xylenes 3.05e-003 4.27e+001 C8+ Heavies 2.24e-002 5.03e+002 Total Components 100.00 2.95e+005 LEAN GLYCOL STREAM Temperature: 120.00 deg. F Plow Rate: 3.50e+001 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9.85e+001 1.94e+004 • Water 1.50e+000 2.95e+002 Carbon Dioxide 2.81e-011 5.52e-009 Nitrogen 2.33e-013 4.59e-011 Methane 8.84e-018 1.74e-015 Ethane 1.13e-007 2.22e-005 Propane 8.51e-009 1.68e-006 Isobutane 1.42e-009 2.80e-007 n-Butane 3.43e-009 6.76e-007 Isopentane 2.09e-004 4.11e-002 n-Pentane 2.66e-004 5.25e-002 Cyclopentane 5.20e-005 1.02e-002 n-Hexane 9.71e-005 1.91e-002 Cyclohexane 7.16e-004 1.41e-001 Other Hexanes 2.87e-004 5.64e-002 Heptanes 1.25e-004 2.47e-002 Benzene 7.15e-003 1.41e+000 Toluene 1.36e-002 2.72e+000 Ethylbenzene 4.89e-004 9.63e-002 Xylenes 7.93e-003 1.56e+000 C8+ Heavies 4.51e-003 8.88e-001 Total Components 100.00 1.97e+004 RICH GLYCOL STREAM Temperature: 120.00 deg. F Pressure: 1014.70 psia Flow Rate: 3.67e+001 gpm • NOTE: Stream has more than one phase. Page: 8 . Component Conc. Loading (wt%) (lb/hr) TEG 9.45e+001 1.94e+004 Water 3.79e+000 7.78e+002 Carbon Dioxide 2.69e-001 5.53e+001 Nitrogen 2.24e-003 4.60e-001 Methane 2.53e-001 5.18e+001 Ethane 2.29e-001 4.70e+001 Propane 2.O1e-001 4.12e+001 Isobutane 4.55e-002 9.32e+000 n-Butane 1.33e-001 2.73e+001 Isopentane 4.O1e-002 8.23e+000 n-Pentane 5.12e-002 1.05e+001 Cyclopentane 9.99e-003 2.05e+000 n-Hexane 1.87e-002 3.83e+000 Cyclohexane 2.15e-002 4.41e+000 Other Hexanes 2.75e-002 5.64e+000 Heptanes 2.40e-002 4.93e+000 Benzene 1.37e-001 2.82e+001 Toluene 1.68e-001 3.44e+001 Ethylbenzene 4.51e-003 9.25e-001 Xylenes 5.89e-002 1.21e+001 C8+ Heavies 3.60e-002 7.38e+000 Total Components 100.00 2.05e+004 FLASH TANK OFF GAS STREAM • Temperature: 160.00 deg. F Pressure: 44.70 pale. Flow Rate: 2.76e+003 scfh Component Conc. Loading (vol%) (lb/hr) Water 1.03e+000 1.35e+000 Carbon Dioxide 1.37e+001 4.38e+001 Nitrogen 2.20e-001 4.48e-001 Methane 4.32e+001 5.04e+001 Ethane 1.98e+001 4.33e+001 Propane 1.09e+001 3.49e+001 Isobutane 1.76e+00D 7.43e+000 n-Butane 4.87e+000 2.06e+001 Isopentane 1.15e+000 6.06e+000 n-Pentane 1.39e+000 7.33e+000 Cyclopentane 1.51e-001 7.70e-001 n-Hexane 3.54e-001 2.22e+000 Cyclohexane 1.85e-001 1.13e+000 Other Hexanes 5.74e-001 3.60e+000 Heptanes 2.86e-001 2.08e+000 Benzene 2.58e-001 1.47e+000 Toluene 1.82e-001 1.22e+000 Ethylbenzene 2.59e-003 2.00e-002 Xylenes 2.34e-002 1.81e-001 C8+ Heavies 7.34e-002 9.10e-001 Total Components 100.00 2.29e+002 Page: 9 • FLASH TANK GLYCOL STREAM Temperature: 160.00 deg. F Flow Rate: 3.62e+001 gpm Component Conc. Loading (wt%) (1b/hr) TEG 9.55e+001 1.94e+004 Water 3.83e+000 7.76e+002 Carbon Dioxide 5.64e-002 1.14e+001 Nitrogen 5.84e-005 1.19e-002 Methane 6.80e-003 1.38e+000 Ethane 1.85e-002 3.75e+000 Propane 3.11e-002 6.31e+000 Isobutane 9.33e-003 1.89e+000 n-Butane 3.29e-002 6.67e+000 Isopentane 1.07e-002 2.17e+000 n-Pentane 1.56e-002 3.17e+000 Cyclopentane 6.30e-003 1.28e+000 n-Hexane 7.92e-003 1.61e+000 Cyclohexane 1.61e-002 3.27e+000 Other Hexanes 1.01e-002 2.04e+000 Heptanes 1.40e-002 2.85e+000 Benzene 1.32e-001 2.67e+001 Toluene 1.64e-001 3.32e+001 Ethylbenzene 4.46e-003 9.05e-001 Xylenes 5.87e-002 1.19e+001 C8+ Heavies 3 .19e-002 6.47e+000 • Total Components 100.00 2.03e+004 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 Pressure: 14.70 psia Flow Rate: 1.08e+004 scfh Component Conc. Loading (volt) (lb/hr) Water 9.38e+001 4.81e+002 Carbon Dioxide 9.13e-001 1.14e+001 Nitrogen 1.49e-003 1.19e-002 Methane 3.02e-001 1.38e+000 Ethane 4.39e-001 3.75e+000 Propane 5.03e-001 6.31e+000 Isobutane 1.1Se-001 1.89e+000 n-Butane 4.03e-001 6.67e+000 Isopentane 1.04e-001 2.13e+000 n-Pentane 1.52e-001 3.12e+000 • Cyclopentane 6.36e-002 1.27e+000 Page: 10 • n-Hexane 6.48e-002 1.59e+000 Cyclohexane 1.31e-001 3.13e+000 Other Hexanes B.11e-002 1.99e+000 Heptanes 9.91e-002 2.82e+000 Benzene 1.14e+000 2.53e+001 Toluene 1.16e+000 3.05e+001 Ethylbenzene 2.68e-002 8.09e-001 Xylenes 3.42e-001 1.03e+001 C8+ Heavies 1.15e-001 5.58e+000 Total Components 100.00 6.01e+002 CONDENSER PRODUCED WATER STREAM Temperature: 120.00 deg. F Flow Rate: 9.56e-001 gpm Component Conc. Loading (wt%) (lb/hr) (ppm) Water 9.99e+001 4.78e+002 998856. Carbon Dioxide 1.53e-002 7.34e-002 153. Nitrogen 4.19e-007 2.OOe-006 0. Methane 9.40e-005 4.50e-004 1. Ethane 2.90e-004 1.39e-003 3. Propane 4.91e-004 2.35e-003 5. Isobutane 7.78e-005 3.72e-004 1. n-Butane 3.54e-004 1.69e-003 4. Isopentane 6.97e-005 3.33e-004 1. n-Pentane 1.06e-004 5.06e-004 1. • Cyclopentane 2.78e-004 1.33e-003 3. n-Hexane 3 .44e-005 1.65e-004 0. Cyclohexane 3 .20e-004 1.53e-003 3. Other Hexanes 3.94e-005 1.88e-004 0. Heptanes 1.92e-005 9.18e-005 0. Benzene 6.31e-002 3.02e-001 631. Toluene 3.04e-002 1.45e-001 304. Ethylbenzene 2.24e-004 1.07e-003 2. Xylenes 3.22e-003 1.54e-002 32. C8+ Heavies 9.54e-008 4.56e-007 0. Total Components 100.00 4.78e+002 1000000. CONDENSER RECOVERED OIL STREAM Temperature: 120.00 deg. F Flow Rate: 1.44e-001 gpm Component Conc. Loading (wt%) (lb/hr) Water 5.75e-002 3.52e-002 Carbon Dioxide 7.OBe-002 4.34e-002 Nitrogen 4.78e-005 2.93e-005 Methane 2.35e-003 1.44e-003 Ethane 3.88e-002 2.38e-002 Propane 3.18e-001 1.95e-001 Isobutane 1.87e-001 1.15e-001 n-Butane 9.34e-001 5.12e-001 IP Isopentane 6.93e-0D1 4.24e-001 n-Pentane 1.16e+000 7.08e-001 Page: 11 Cyclopentane 5.98e-001 3.66e-001 n-Hexane 1.05e+000 6.43e-001 Cyclohexane 2.57e+000 1.5Be+000 Other Hexanes 1.05e+000 6.46e-001 Heptanes 3 .06e+000 1.87e+000 Benzene 2.30e+001 1.41e+001 Toluene 3.91e+001 2.40e+001 Ethylbenzene 1.22e+000 7.45e-001 Xylenes 1.58e+001 9.68e+000 C8+ Heavies 9.10e+000 5.57e+000 Total Components 100.00 6.13e+001 CONDENSER VENT STREAM Temperature: 120.00 deg. F Pressure: 12.50 psia Flow Rate: 4.75e+002 scfh Component Conc. Loading (volt) (lb/hr) Water 1.36e+001 3.07e+000 Carbon Dioxide 2.05e+001 1.13e+001 Nitrogen 3.37e-002 1.18e-002 Methane 6.86e+000 1.38e+000 Ethane 9.90e+000 3.73e+000 Propane 1.11e+001 6.11e+000 Isobutane 2.44e+000 1.78e+000 • n-Butane 8.37e+000 6.09e+000 Isopentane 1.B8e+000 1.70e+000 n-Pentane 2.67e+000 2.41e+000 Cyclopentane 1.03e+000 9.O1e-001 n-Hexane 8.75e-001 9.44e-001 Cyclohexane 1.48e+000 1.56e+000 Other Hexanes 1.24e+000 1.34e+000 Heptanes 7.57e-001 9.50e-001 Benzene 1.12e+001 1.09e+001 Toluene 5.54e+000 6.39e+000 Ethylbenzene 4.70e-002 6.25e-002 Xylenes 4.86e-001 6.47e-001 C8+ Heavies 3.49e-003 7.45e-003 Total Components 100.00 6.13e+001 COMBUSTION DEVICE OFF GAS STREAM Temperature: 1000.00 deg. F Pressure: 14.70 psia Flow Rate: 1.56e+001 scfh Component Conc. Loading (volt) (lb/hr) Methane 1.04e+001 6.89e-002 Ethane 1.50e+001 1.86e-001 Propane 1.68e+001 3.06e-001 Isobutane 3.71e+000 8.89e-002 n-Butane 1.27e+001 3.05e-001 Isopentane 2.B6e+000 8.51e-002 Page: 12 • n-Pentane 4.0se+000 1.21e-001 Cyclopentane 1.56e+000 4.50e-002 n-Hexane 1.33e+000 4.72e-002 Cyclohexane 2.24e+000 7.78e-002 Other Hexanes 1.89e+000 6.71e-002 Heptanes 1.15e+000 4.75e-002 Benzene 1.70e+001 5.46e-001 Toluene 8.41e+000 3.19e-001 Bthylbenzene 7.14e-002 3.13e-003 Xylenes 7.39e-001 3.23e-002 C8+ Heavies 5.31e-003 3.73e-004 Total Components 100.00 2.35e+000 I • . Page: 1 GRI-GLYCalc VERSION 4.0 - SUMMARY OF INPUT VALUES Case Name: Enterprise 120 MMSCFD File Name: H:\DCP\Enterprise\Enterprise 120 Modification and Engine Addition Sept 2011\120 MMSCFD Glycalc.ddf Date: September 14, 2011 DESCRIPTION: Description: Enterprise 120 MMSCFD 35 gpm Glycol Recirc Rate Annual Hours of Operation: 8760.0 hours/yr WET GAS: Temperature: 120.00 deg. F Pressure: 1000.00 psig Wet Gas Water Content: Saturated Component Conc. (vol %) Carbon Dioxide 2.6600 Nitrogen 0.3200 Methane 73.6091 Ethane 13.4435 Propane 5.7633 Isobutane 0.8119 n-Butane 1.8738 • Isopentane 0.5005 n-Pentane 0.5144 Cyclopentane 0.0240 n-Hexane 0.1123 Cyclohexane 0.0286 Other Hexanes 0.2068 Heptanes 0.0782 Benzene 0.0251 Toluene 0.0204 Ethylbenzene 0.0004 Xylenes 0.0038 08+ Heavies 0.0227 DRY GAS: Flow Rate: 120.0 MMSCF/day Water Content: 7.0 lbs. H20/MMSCF LEAN GLYCOL: Glycol Type: TEG Water Content: 1.5 wt% H2O Flow Rate: 35.0 gpm • PUMP: Page: 2 • Glycol Pump Type: Electric/Pneumatic FLASH TANK: Flash Control: Recycle/recompression Temperature: 160.0 deg. F Pressure: 30.0 psig REGENERATOR OVERHEADS CONTROL DEVICE: Control Device: Condenser Temperature: 120.0 deg. F Pressure: 12.5 psia Control Device: Combustion Device Destruction Efficiency: 95.0 % Excess Oxygen: 0.0 % Ambient Air Temperature: 0.0 deg. 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Q x F O F O• 3 0 , O y > a , w 0 r $ n al c j R o W N ' n C N ..0 a 2 O ° w 'Q S. G O M a eg• 0 w o t a ° 0 B C T t a 41 i g r o c y d n - E E e € " W o F4 J-la b.1 c 7 eck Lensk wc& •e. Des\yam — ,cue IC RV? ' ©flS A?IC7 — I . (99q • Io+I.roc(q_ f05,-=aP O. 1-1-61 - as 11* 1 lm 1]0 = 110 - 2 100 1 r 3 3 RV) i b b A — b 1 • Rrto_!----r s so r 2l, —10 IS 12 12 17 —- 14 IS 70 _ 1b 10 0 21 Figure 7.1-13a.True vapor pressure of crude oils with a Reid vapor pressure of 2 to 15 pounds per square inch.' V c o lc'e- ) ht- [z: vt<tiv- RVP 1O 'TvP -4. 2c Ps P(:: (4S-L-1 PeAt, S-ee_ Sales 6.k avv_I ,sts 1OO,ck Orr C S GtvctilicAs, • P1(.2 7.1-54 `S EMISSION FACTORS 11/06 • Extended Liquid Analysis • DCP Midstream, LP Enterprise Compressor Station Carbon Dioxide 0.0667 0.0321 Nitrogen 0.0284 0.0087 Methane 0.2743 0.0481 Ethane 0.8199 0.2893 Propane 3.0885 1.4877 i-Butane 1.5839 1.0055 n-Butane 5.5719 3.5372 I-Pentane 4.1245 3.2503 HAPS Summary Wt% n-Pentane 5.5219 4.3518 Cyclopentane 0.5479 0.4197 n-hexane 9.76 n-Hexane 10.3687 9.7595 Benzene 1.35 Cyclohexane 3.0484 2.8022 Toluene 4.50 Other Hexanes 15.0673 14.114 Ethylbenzene 0.34 Other Heptanes 15.793 17.2287 Xylene 3.23 Mehylcyclohexane 5.1024 5.4723 Total HAP 19.19 224 trimethylpentane 0.5059 0.5426 Benzene 1.5855 1.3527 Toluene 4.472 4.5007 Ethylbenzene 0.2952 0.3423 Xylenes 2.7873 3.2323 • Other Octanes 10.6105 13.2502 Nonanes 4.9634 6.8883 Decanes+ 3.7725 6.104 100 100 • — Ile4 V l"- WI"- �i 4 MPACT ANALYTICAL SYSTEMS INC. ,iL Al ;Mir ,7 �`�.,,>,�IIILIO�I/��r. ` BRIGHTON, CO ;7- // 80601 il`,.� h . ( 303-637-0150 EXTENDED NATURAL GAS LIOUID ANALYSIS(*DEA) MAIN PAGE PROJECT NO. : 201105)50 ANALYSIS NO.: 01 COMPANY NAME: DC?MIDSTREAM-LP ANALYSIS DATE: JUNE 3,2011 ACCOUNT NO. : SAMPLE DATE : MAY 26,2011 PRODUCER : CYLINDER NO.: 2821 LEASE NO. : SAMPLED BY : J.MOSER NAME(DESCRIP: ENTERPRISE COMPRESSOR EMPACT 3 PHASE SEPARATOR @12:00 - •**FIET D DATA*** SAMPLE TEMP.: 106 SAMPLE PRES.: 30 AMBIENT TEMP.: VAPOR PRES. : GRAVITY . COMMENTS : SPOT;NO PROBE COMPONENT MOLE% MASS% VOL% NITROGEN(AIR) 0.0284 0.0087 0.0076 • CARBON DIOXIDE 0.0667 0.0321 0.0276 METHANE 0.0481 0.1130 ETHANE 0.8199 02693 0.5324 PROPANE 3.0885 1.4877 2.0666 I-BUTANE 1.5839 1.0055 1.2581 N-BUTANE 5.5719 3.5372 4.2657 . I-PENTANE 4.1245 32503 3.6658 N-PENTANE 5.5219 43516 4.8559 HEXANES PLUS 78.9200 86.0095 83.2073 TOTALS 100.0000 100.0000 100.0000 BTEX COMPONENTS MOLE% MASS% (CALL: GPA STD 2145-94&TP-17 Qx 14.696&60 F) BENZENE 1.5855 1.3527 TOTAL C6+ TOLUENE 4.4720 4.5007 SAMPLE FRACTION ETHYLBENZENE 0.2952 0.3423 Specific Gravity(1420=1) = 0.7043 0.7274 60/60 XYLENE 2.7873 3.2323 API Gravity - 69.41 63.03 60/60 TOTAL BTF.X 9.1400 9.4280 Molecular Weight = 91.55 99.984 Absolute Density = 5.87 6.07 LBS/GAL Heating Value Liq.Idl Gas= 119555 123799 BTU/GAL Vapor/Liquid = 24.20 23.07 CUFT/GAL Vapor Pressure - 34.02 2.76PSIA@100F ¶(DETAFLED HYDROCARBON ANALYSIS/NJ199J);ASTAID6730 - THIS DATA HAS BEEN ACQUIRED THROUGH APPLICATION OF CURRENT STAT&OF-THEARTANALYTICAL TECHNIQUES THE USE OF THIS INFORMATION IS THE RESPOMTIRU7YOF THE USER. EMPACT ANALYTICAL SYSTEMS,ASSUMES NO RFSPONSIBLIYFOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OFIrS APPLICATION 0 • MPACT ANALYTICAL • SYSTEMS INC. 365 S.MAIN ST. BRIGHTON, CO 80601 L .__.I, i 303.637-0150 EXTENDED NATURAL GAS LIQUID ANALYSIS("DMA) E&P TANK I GLYCAI-C INFORMATION PROJECT NO. : 201105150 ANALYSIS NO.: 01 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: JUNE 3,2011 ACCOUNT NO. : SAMPLE DATE : MAY 26,2011 PRODUCER : CYLINDER NO.: 2821 LEASE NO. : SAMPLED BY : J.MOSER NAME/DESCRIP: ENTERPRISE COMPRESSOR EMPACT 3 PHASE SEPARATOR @12:00 'nFIELD DATA"' SAMPLE TEMP.: 106 SAMPLE PRES.: 30 AMBIENT TEMP: VAPOR PRES. : GRAVITY COMMENTS : SPOT;NO PROBE COMPONENT Mole% Wt% LV% CARBON DIOXIDE 0.0687 0.0321 0.0276 • NITROGEN(AIR) 0.0284 0.0087 0.0076 METHANE 0.2743 0.0481 0.1130 ETHANE 0.8199 0.2693 0.5324 PROPANE 3.0885 1.4877 2.0666 I-BUTANE 1.5839 1.0055 1.2581 N-BUTANE 5.5719 3.5372 4.2657 I-PENTANE 4.1245 3.2503 3.6658 N-PENTANE 5.5219 4.3516 4.8559 • CYCLOPENTANE(N-05) 0.5479 0.4187 0.3888 N-HEXANE 10.3687 9.7595 10.3548 CYCLOHEXANE(OTHER C8) 3.0484 2.8022 2.5190 OTHER HEXANES 15.0873 14.1140 14.6408 OTHER HEPTANES 15.7930 17.2287 17.3737 METHYLCYCLOHEXANE(OTHER C7) 5.1024 5.4723 4.9748 2,2,4 TRIMETHYLPENTANE 0.5059 0.5426 0.5072 BENZENE 1.5855 1.3527 1.0790 TOLUENE 4.4720 4.5007 3.6256 ETHYLBENZENE 0.2952 0.3423 0.2757 XYLENES 2.7873 3.2323 2.6141 OTHER OCTANES 10.6105 13.2502 12.8308 OCTANES PLUS - 22.9348 - 30.3597 - 28.2508 NONANES 4.9634 6.8883 6.4556 , DECANES PLUS 3.7725 6.1040 5.5674 TOTAL 100.0000 100.0000 100.0000 API Gravity = 69.41 60160 Vapor Pressure = 34.02 PSIA&100 F Average Molecular Weight of Decanes plus = 148.14 Average Specific Gravity of Decanes plus = 0.7740 THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT • STATE-OF-THE ART ANALYTICAL TECHNIOUES. THE APPLICATIONS OF THIS INFORMATION IS THE RESPONSIBILITY OF THE USER. EMPACT ANALYTICAL SYSTEMS,INC.ASSUMES NO RESPONSIBILITY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF IT'S APPLICATION. • • MPACT ANALYTICAL YSTEMS INC. 365 S.MAIN ST. BRIGHTON,CO 80607 4 303437.0150 EXTENDED NATURAL GAS LIQUID ANALYSIS(*DHA) pHA COMPONENT LIST PROJECT NO. : 201105150 ANALYSIS NO.: 01 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: JUNE 3,2011 ACCOUNT NO. : SAMPLE DATE : MAY 26,2011 PRODUCER . CYLINDER NO.: 2821 LEASE NO. : SAMPLED BY : J.MOSER NAMEIDESCRIP: ENTERPRISE COMPRESSOR EMPACT 3 PHASE SEPARATOR(012:00 "'FIELD DATA'" SAMPLE TEMP.: 106 SAMPLE PRES_: 30 AMBIENT TEMP.: VAPOR PRES. : GRAVITY . COMMENTS : SPOT;NO PROBE COMPONENT PIANO# MOLE% MASS% VOL% Nitrogen 0.0284 0.0087 0.0076 • Carbon Dioxide 0.0667 0.0321 0.0276 Methane P1 0.2743 0.0481 0.1130 Ethane P2 0.8199 02893 0.5324 Propane P3 3.0885 1.4877 2.0866 I-Butane 14 1.5839 1.0055 1.2581 n-Butane P4 5.5719 3.5372 4.2657 2,2-Dlmethylpropane 15 0.0300 0.0238 0.0278 I-Pentane 15 4.0945 3.2267 3.8380 n-Pentane P5 5.5219 4.3516 4.6559 2,2-Dimethylbutane 16 0.3632 0.3419 0.3682 Cydopentane N5 0.5479 0.4197 0.3888 2,3-Dimethylbutane 16 1.1668 1.0983 1.1597 2-Mctylpentane 16 6.6067 6.2190 6.6586 3-Methylpentane 16 3.8006 3.5776 3.7667 n-Hexane P6 10.3687 9.7595 10.3548 2,2-Dlmethylpentane 17 0.2513 0.2750 0.2840 Methylcydopentane 146 3.1300 2.8772 2.6876 2,4-Dimethylpentane 17 0.5598 0.6127 0.6380 2,2.3-Trimethylbutane 17 0.0840 0.0700 0.0709 Benzene A6 1.5855 1.3527 1.0790 3.3-Dimethylpentane 17 0.1550 0.1696 0.1716 Cydohexane N6 3.0484 2.8022 2.5190 2-Methylhexane 17 2.5078 2.7447 2.8329 2,3-Dlmethylpentane 17 0.8002 0.8758 0.8782 1,1-Dlmethytcydopentane N7 0.4969 0.5329 0.4943 3-Methylhexane 17 2.6113 . 2.8579 2.9053 1c,3-Dimethylcydopentane N7 0.5894 0.6107 0.5738 11,3-Dlmethylcydopentane N7 0.5059 0.5426 0.5072 3-Ethylpentane 17 0.1701 0.1862 0.1862 11,2-Dimethyicyclopentane N7 0.7986 0.8565 0.7978 2,2,4-Trlmethylpentane 18 0.0391 0.0488 0.0492 n-Heptane P7 6.1240 6.7024 6.8586 • 1c,2-Dlmethylcyclopentane N7 0.0341 0.0366 0.0332 Methylcydohexane N7 5.1024 5.4723 4.9748 2,2-Dimelhylhexane IB 0.4695 0.5858 0.5893 Ethylcyclopentane N7 0.1446 0.1551 0.1417 2,6-DlmeUtylhexane IB 0.2747 0.3427 0.3456 2,2,3-Trimethylpentane IB 0.0180 0.0200 0.0196 2,4-Dimethylhexane 18 0.3531 0.4406 0.4422 1c,2t,4-Trlmethylcydopentane N8 0.2139 0.2622 0.2404 3,3-Dimethyhexane 18 0.1006 0,1255 0.1238 2,3,4-Trfinethylpentane 18 0.0151 0.0188 0.0183 2,3,3-Trlmethylpentane 18 0.0160 0.0200 0.0193 Toluene A7 4.4720 4.5007 3.6256 2,3-Dlmethylhexane 18 0.1952 0.2436 0.2396 2-Methyl-3-e8rylpentane 18 0.0384 .0.0479 0.0466 1,1,2-Tnmethylcyclopentane NB 0.0156 0.0191 0.0173 2-Methylheptane 18 1.5176 1.8935 1.8954 4-Methylheptane 18 0.5377 0.6709 0.6554 3-Methyl-3-ethytpentane 18 0.0458 0.0571 0.0550 3,4-Dimethylhexane 18 0.0838 0.1046 0.1017 1c,2c,4-Trimethylcydopentane N8 0.0208 0.0255 0.0231 1c,3-Dimethylcyclohexane N8 0.0167 0.0205 0.0187 3-Methylheptane 18 1.1214 1.3992 1.3885 1x243-Trimethylcyclopentane NB 0.9891 1.2123 1.1017 3-Ethylhexane 18 0.0641 0.0800 0.0786 1t,4-Dimethylcyclohexane NS 0.4727 0.5794 0.5320 1.1-Dlmethylcydohexane N8 0.1686 0.2066 0.1853 2.2,5-Trimethylhexane 19 0.0188 0.0263 0.0259 31-Ethylmethylcycbpentane N8 0.0329 0.0403 0.0368 2t-Ethylmethylcyclopentane N8 0.0293 0.0359 0.0327 1,1-Methylethylcydopentane N8 0.0483 0.0592 0.0531 2,2,4-Trimethypexane 19 0.0134 0.0188 0.0184 1t,2-Dimethylcyclohexane N8 0.3000 0.3877 0.3319 1c,2c,3-Trimethylcyclopentane N8 0.0020 0.0024 0.0022 11,3.01methylcydohexane NB 0.0030 0.0037 0.0033 n-Octane P8 2.6376 3.2909 3.2785 • 1c,4-Dimethylcydohexane N8 0.4566 0.5598 0.5006 I Propylcydopenffine 18 0.0316 0.0387 0.0349 2,4,4-Trimethylhexane 19 0.0142 0.0199 0.0193 2,2,3,4-Tetramethylpentane 19 0.0175 0.0245 0.0239 2,3,4-Trimemylhexane 19 0.0887 0.1243 0.1206 1c,2-DImethylcyclohexane N8 0.1905 0.2335 0.2054 2,3,5-Trimethylhexane 19 0.0162 0.0227 0.0220 2,2-Dimethylheptane 19 0.0061 0.0085 0.0084 1,1,4-Trlmethylcycbhexane N9 0.4337 0.5980 0.5426 2.2,3-Trimethylhexane 19 0.2723 0.3815 0.3663 2,4-Dlmethylheptane 19 0.0127 0.0178 0.0174 4,4-DImethylheptane 19 0.0178 0.0249 0.0244 Ethylcydohexane N8 0.1758 0.2155 0.1916 n-Propylcycbpentane NB 0.3321 0.4070 0.3670 1c,3c,5-Trimethylcydohexane N9 0.0657 0.1182 0.1072 2,5-Dimethylheptane 19 0.0119 0.0167 0.0163 3,3-Otmethylheptane 19 0.0156 0.0219 0.0214 3,5-Dimethylheptane 19 0.0097 0.0136 0.0133 2,6-Dimethylheptane 19 0.0043 0.0060 0.0059 1,1,3-Trlmethylcydohexane N9 0.0287 0.0396 0.0359 Ethylbenzene A8 0.2952 0.3423 02757 1 c,2t,41-Trimethylcydohexane N9 0.0069 0.0095 0.0085 2,3-Dlmethylheptane 19 0.0187 0.0262 0.0253 1,3-Dime4rylbenzene(m-Xylene) A8 1.7410 2.0190 1.6356 1,4-DImethylbenzene(p-Xylene) A8 0.6596 0.7649 0.6216 3,4-Dimethylheptane 19 0.0716 0.1003 0.0960 3.4-DImethylheptane(2) 19 0.0675 0.0946 0.0906 • 4-Ethylheptane 19 0.0615 0.0862 0.0844 4-Methyloctane 19 0.2624 0.3676 0.3572 2-Methyloctane 19 0.3496 0.4898 0.4806 1c,2t,4c-Trimethyicydohexane 19 0.0131 0.0183 0,0177 3-Ethylheptane 19 0.0598 0.0838 0.0808 • 3•Methyloctane 19 0.3301 0.4625 0.4493 3,3-Diethylpentane 19 0.0052 0.0073 0.0068 1 c,2t,3-Trime91y1cycIohexane N9 0.0196 0.0270 0.0240 • 1,1,2-Tdmethylcydohexane N9 0.0055 0.0076 0.0068 1,2-Dimethylbenzene(o-Xylene) A8 0.3867 0.4484 0.3669 i-Buy1cydopenlane NO 0.1368 0.1886 0.1691 UnknownC8s U8 0.0912 0.1138 0.1134 n-Nonane P9 1.0380 14542 1.4189 1,1-Methylethylcyciohexane N9 0.1376 0.1928 0.1887 I-Propylbenzene A9 0.0380 0.0499 0.0405 i-Propylcyclohexane N9 0.0267 0.0368 0.0321 2,2-Dimethyloclane 110 0.0142 0.0221 0.0209 2,4-DImethyloctane 110 0.0650 0.1010 0.0957 2,6-Dimethyloctane t10 0.0122 0.0190 0.0186 2,5-Dimethyloctane 110 0.0082 0.0127 0.0120 n-Butylcyclopentane N9 0.1168 0.1790 0.1569 3.3-Dimethyloctane 110 0.0206 0.0320 0.0303 n-Propylbenzene Ag 01446 0.1898 0.1540 3.6-Dimethyloctane 110 0.0461 0.0716 0.0676 3-Methyl-5-ethylheptane 110 0.0324 0.0454 0.0438 1,3-Methylethylbenzene A9 0.1377 0.1808 0.1454 1,4-Melhyiethylbenzene A9 0.0529 0.0694 0.0558 1.3,5-Trimethylbenzene A9 0.1865 0.2448 0.1983 2,3-Dlmethylactane 110 0.0421 0.0654 0.0619 5-Methylnonane 110 0.1012 0.1573 0.1504 1,2-Methylethytbenzene A9 0.1372 0.1801 0.1441 2t4ethytnonene 110 0.0179 0.0278 0.0268 3-Ethyloctane 110 0.0183 0.0284 0.0269 3-Methylnonane I10 0.0885 0.1375 0.1313 1,2,4-Trimethylbenzene A9 0.0011 0.0014 0.0011 t-Butylbenzene A10 0.2112 0.3096 0.2504 i-Butylcyclohexane N10 0.0489 0.0749 0.0646 lt-Methyl-2-n-propylcydohexane 110 0.0099 0.0139 0.0134 i-Butylbenzene Al 0 0.0160 0.0235 0.0193 secButylbenzene A10 0.0111 0.0163 0.0133 • UnknawnC9s 119 0.4413 0.6182 0.6032 n-Decane P10 0.3955 0.6146 0.5896 1,2,3-Trimeltylbenzene A9 0.0294 0.0386 0.0303 1,3-Methyl+propylbenzene Al0 0.0192 0.0252 0.0202 1,4-Methyl-l-propybenzene A10 0.0116 0.0152 0.0122 Seo-Butylcyclohexane N10 0.0622 0.0953 0.0821 ' 1,2-Methyl-i-propylbenzene A10 0.0553 0.0811 0.0648 3-Ethylnonane 110 0.0075 0.0117 0.0113 1.3-Dlethylbenzene A10 0.0114 0.0167 0.0135 1,3-Methyl-n-propylbenzene A10 0.0164 0.0240 0.0195 1,4-Dlethylbenzene A10 0.0392 0.0575 0.0468 1,4-Methyl-n-propylbenzene Al0 0.0057 0.0084 0.0069 n-Butylbenzene Al0 0.0114 0.0167 0.0136 1.3-DImethyl-5-ethylbenzene A10 0.0197 0.0289 0.0234 1,2-Dlethylbenzene Al0 0.0087 0.0128 0.0102 1,2-Methyl-n-propylbenzene A10 0.0256 0.0375 0.0301 • 1,4-Dimefhyl-2-ethylbenzene Al 0 0.0307 0.0450 0.0359 1,3-Dlmethyl-4-ethylbenzene A10 0.0031 0.0045 0.0036 1,2-DImethyl-4-ethylbenzene Al 0 0.0494 0.0724 0.0580 1,3-Dimethyt-2-ethylbenzene A10 0.0189 0.0277 . 0.0218 11,20,4-Trbnethylcyclopentane A10 0.1675 0.2053 0.1923 1,2-Dimethyl-3-ethylbenzene A10 0.0167 0.0245 0.0192 1,2-Ethyl-1-propylbenzene A10 0.0097 0.0142 0.0114 1,4-Methyl-t-butylbenzene All 0.0337 0.0494 0.0395 UnknownClOs U10 0.6136 0.9536 0.9148 n-Undecane P11 0.1878 0.3206 0.3033 1,4-EthyI4-propylbenzene All 0.0124 0.0182 0.0146 1,2,4,5-Tetramethylbenzene All 0.0119 0.0174 0.0138 1,2-Methyl-n•butylbenzene All 0.0111 0.0183 0.0130 1,2,3,5-Tetramethylbenzene All 0.0149 0.0218 0.0172 1,2-Methyl-t-buiytbenzene All 0.0219 0.0321 0.0257 • • SMethylindan All 0.0080 0.0149 0.0139 4•Metlrylindan All 0.0055 0.0102 0.0095 1,2-Et yl•n-propylbenzene All 0.0014 0.0021 0.0017 2-Methylinden All 0.0030 0.0056 0.0052 • 1,3-Methyl-n-0utylbenzene All 0.0041 0.0060 0.0048 1,3-DI-I-propylbenzene Alt 0.0057 0.0084 0.0067 sec-Penytbenzene All 0,0151 0.0221 0.0177 n-Pentylbenzene All 0.0069 0.0112 0.0091 1t-M-2-(4MP)cyolopentene P12 0.0138 0.0257 0.0241 1,4-Di-l-propylbenzene All 0.0191 0.0280 0.0224 t-Decahydronaphthalene A10 0.0061 0.0089 0.0071 Naphthalene A10 0.0148 0.0207 0.0166 1-t-Butyl35dimethytbenzerre Al2 0.0042 0.0062 0.0050 1,4-Ethyl-t-butylbenzene All 0.0086 0.0126 0.0101 UnknovmClls U 1 1 0.2547 0.4349 0.4114 n-Dodecane P12 0.1155 0.2149 0.2011 1,3-Di-n-propylbenzene Al2 0.0064 0.0094 0.0075 1,3,5-Trlethybe zene Al2 0.0081 0.0106 0.0086 1,2,4-Trlethylbenzene Al2 0.0340 0.0448 0.0357 1,4-Methyl-n-pentylbenzene Al2 0.0106 0.0155 0.0124 n-Hexylbenzene Al2 0.0131 0.0232 0.0190 1,2,3,4,5-Pentamethylbenzene A13 0.0122 0.0179 0.0143 2-Methylnaphthalene All 0.0172 0.0267 0.0213 1-Methylnaphthalene All 0.0148 0.0230 0.0158 UnknownCl2s U12 • 0.1213 0.2257 0.2112 n-Trtdecane P13 0.0600 0.1208 0.1117 UnknownC13s U13 0.0949 0.1911 0.1767 n-Tetradecane P14 0.0290 0.0828 0.0579 Ur*rawnCl4s U14 0.0966 0.2093 0.1931 n-Pentadecane P15 , 0.0164 0.0381 0.0347 UnknownCl5s U15 0.0632 0.1466 0.1337 n-Kexadecane P16 0.0038 0.0094 0.0085 UnknownCl6s U16 0.0230 0.0569 0.0516 n-Heptadecane P17 0.0004 0.0010 0.0009 ' UnkmwnCl7s L117 0.0037 0.0097. 0.0088 n-Octadecane P18 0.0002 0.0006 0.0005 • UnknownC18s U19 0.0004 0.0011 0.0010 UnknownCl9s U19 0.0002 0.0006 0.0005 TOTAL 100.0000 100.0000 100.0000 THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OP CURRENT STATEAF-THE ART ANALYTICAL TECHNIQUES. THE APPLICATIONS OF THIS INFORMATION IS THE RESPONSIBILITY OF THE USER. EMPACTANALYTICAL SYSTEMS,INC ASSUMES NO RESPONSIBILITY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF ITS APPLICATION. • S if /41 • i _ EMPACT � K 911 Hero 7 '& &ABII.11 L 'Y..311Vn VW#Z SIN al PROJECT NO: 201105150 ANALYSIS NO.: 02 COMPANY NAME: DCP MIDSTREAM.LP ANALYSIS DATE: JUNE 21,2011 SAMPLE DATE: MAY 26,2011 COMMENTS: 1L JAR SAMPLED BY: J.MOSER SPOT @ 67°F:LIGHT BROWN/ORANGE EMPACT TEST PROCEDURE/METHOD: API GRAVITY DESCRIPTION: API GRAVITY(5)80/80 ENTERPRISE COMPRESSOR 58.5 PROCUTION TANK @12:10 S THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT STATE-OF-THE ART ANALYTICAL TECHNIQUES. THE APPLICATIONS OF THIS INFORMATION IS THE RESPONSIBILITY OF THE USER. EMPACT ANALYTICAL SYSTEMS,INC.ASSUMES NO RESPONSIBLITY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF ITS APPLICATION. • EMPACT Analytical Systems, Ina 365 South Main St, Brighton, CO. 80601 (303)637-0150 i 9'.F, 1 IdYgh. ir, EMPACT y\\,,Au, If I '`./ PROJECT NO: 201105150 ANALYSIS NO.: 02 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: JUNE 21,2011 SAMPLE DATE: MAY 26,2011 COMMENTS: 1L JAR SAMPLED BY: J.MOSER SPOT©67°F;LIGHT BROWN I ORANGE EMPACT TEST PROCEDURE I METHOD: REID VAPOR PRESSURE(ASTM D-323) DESCRIPTION: REID VAPOR PRESSURE ENTERPRISE COMPRESSOR 6.1 PROCUTION TANK©12:10 S THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT STATE-OF-THE ART ANALYTICAL TECHNIQUES. THE APPLICATIONS OF THIS INFORMATION IS THE RESPONSIBILITY OF THE USER. EMPACT ANALYTICAL SYSTEMS,INC.ASSUMES NO RESPONSIBIUTY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF rrs APPUCATION. • EMPACT Analytical Systems, Inc. 365 South Main St. Brighton, CO. 80601 (303)637-0150 k § 0 , 2 ii i o ■ 2« 3 !� » j cc! 010 � f lol • # ) / i k { ! � ea pc � | o3 ! » 8 fi 05 2e I |J § ! | 3o a ! & 9I [ ere • . ! I to IL co UI Lri en \ k� . . C § %» I 1 e)!E | }& QOO uJw ® !$ , \ k ■ � co ° f | drE k � © Zo . . k! 1 � � ! ! ; _iC a ! ! * k % lib \2 ) §- / • t Fugitive Emissions From Equipment Leaks • Enterprise Compressor station DCP Midstream,LP W1a:JY'vmani sTairraimm cru= immarimi ^nsv+ssr,.� m`;I �,y F "77Mf'_k..u. ..x'. . ,.PT Is�,^7902Kc"rST . _r '.f:AvF G�`t'.n'_ it h �}s I.—n 3''. ,t, ie- c in e.-oMt _ Connections 2.: 17.- nee 7025 67en00e 106 937 442 843 1104 OparnEnds 9 23 Pub 6 13 13 75 Valets 55 479 558 1103 1395 "00w6• 6 40 45 11 100 111 51275579th' y .0057 t a,14LV,00A9, tgia"102Piga,a0tetlfelr c-7 'mtA-4227:5 D-i0214MW&. a �A i Fi, ?yt f to f r a-a•t t M a a t i``_ V J e �4 a« 4 k J i s Y'i.11 O I[°[a,- . - f:s IaL i a.1 utrc:P, f 0 a .�c .LW1 it a7~r,-•d`5,"4 fi 1.m a.,. e - ya 200E-04t : �F:�:i�'Efl� 12'7 alIMIM l NE 'llIMMIIIIIMMEIESEISIIIMMffilatl® 1.41E-03tsl",'.#9an] 0.00®' 0.00 CS`�CEI '1:1tMIIIIMID JISIal1aid irSil 250E-00 550E-03 IMINMILIM Sill1 •8 I®' 1..21. 1 0.00E-03qqa3 a„ i j alI ,{�4 IS al] rat ]�. G1e tE`t i�:=,.cv2,.A� L"JK{_+-,E.-•';.�'f✓."yCai+2 ^"Y'≥liaiMERC32 Gas _" _ Nana :� Methane • 16.0 73.610 1176 5279 55.61% El ant 30.0 13.444 4.03 10.00 1011% Tel.MetNEth 87,053 102 70.0 7592% Propene 440 5.783 2.54 11.36 12.02% I•emne 58.0 0.819 0.48 2.13 2.25% • n.aulsra SOD 1214 1.09 4.67 8.15% H+enlene 72.0 0.601 0.36 1.61 1.71% n-Pone 72A 0.539 0.39 1.74 124% Other Hemmer 86.0 0259 031 1.30 1.40% n.teaene 88.0 0.112 0.10 0.43 0.46% Benzene 78.1 0.025 0.02 0.D9 0.00% Toluene 92.1 0.020 0.02 0.08 0.09% EOMbenZene 1012 0.000 0.00 0.00 0.00% 7t11enes ]062 0.004 0.00 0.02 0.02% Total VOC 10.016 5.3 23.70 2500% Carbon Dbxide 44.0 2590 1.14 5.10 Holum 4.0 0.010 0.00 0.00 Oxlrn 82. 0.010 0.00 001 n 28.0 0.320 0.09 0.40 0 Ma'#-6'.c-sr5 March 19,2011 Gas S DCP Midalreern.LP 1021/2011 GK Semite BpeO aten 11911t Liquid Service 5peclatlon r trice- F , ,. ,-,-..'•a-rrtHra i4 in g, ap x"r`�u r z-. r t .r 1 f $ v '.F"YR" [,.S.: . at ^�I''r.�1 �,{-"' w 74.y 'EF 4,�'K "S nit-lam�4 s.; "V .1!. .i L..r 2S a °c s E_ wl a hRei L2 1 'r 5 I�s'Hi - 0.0000 0.00 �� 0.00 0.00 ! 0.00 0.00 Calton Dodds =MIMI 0.0000 0.0000 t•ro iet:...:.-- 0.00 0.00 0.o0% 0.0000 0.0000 L' • Kt S 0.D0 0.00 _ �� fld : p' '''I E1111INEEME7 IETI10110p',j J 'E!] "D. .�r-IISIMMION3 INC ISM MITTMININ 0.00 ODD MMISILEESNITE fit.?0 0.00 11=MI=IMI 'Miia MIMEE133 6=231fl 000 0.00 Era Illr 10 Ono 000 GrGIINIMSMIIECOPIIIIICEIE1 stun GITI7M! SIMMa 1 •xtl 02-901 Mr= 0.0063 SEgrl 1221713101111•11:11•111=X3f� grari 0.00% 00001 0.00061 Q Er Mira 0mMMEICil sMMal.ai �. -4 ,,r r:I'V1 F s1::,: *..75'v«-.6w 37)-1 goamagainuzi Sr -.':ati ttiA, nt :. A Ia15'L,,, ;3an^,,Raoo^ P 1 F`.�. , 0::. f nttY. t.%: '!: fit::!° v:1I' l R '"illE trit'�=in7 c 3[i`_ 4k?: �.'.!l E��u .Xat 1P;�r-^ ryEja ";7.'. '' _N •Assume 10041%VOC to to Wroervetive. -vA% wn Uquld Ana o'll' 'W-Gttl07tl;aboe4l'LR OY r ".",'!1'R'it'intM1h'n,Et:">�i�'; 4!a� we. E': To tal HAS% 0.21 0.93 0.53 2.31 Total VOC 2.63 1151 639 20.7 rzFleaune 0.12 0.51 022 1.27 Benzene 0.02 006 0.05 0.20 TO9lenO 0.04 026 0.11 0.49 E10yleentene 0.00 0.(1 0.01 0.03 XTlerac 0.03 1 0.07 0.32 - A)Cuiputtt cam)bats upon API Mttoala11EM 6WY 4)sad AN Publlneen Mle(febla E) II)EPA en habit laden GIMESChall instead ler E.*En.M Lath EmMonsadmWC®A WMUEUNu4STR9a017 • • OCR Mioeeeam,LP 101212011 Component Number of Emiss.Fact. HC Emiss. Percent Control illy F.miss Type Components flb/comp/hr) Qb/hr) VOC* Factor flb/hr1 Valves 473 0.00992 4.692 27.67 0 1.298 Relief Valves 35 0.01940 0.679 27.67 0 0.188 Compressors 5 0.01940 0.097 27.67 0 0.027 Flange/Conn 337 0.00086 0.290 27.67 0 0.080 Connectors 2914 0.00044 1.282 27.67 0 0.355 Open-Ended 0 0.00441 0 27.67 0 0.000 Pump Seals 5 0.00529 0.026 27.67 0 0.007 Total All 1.955 *Percent VOC from Gas Analysis= 27.67 Connectors 2914 flanges 337 open ends 0 pumps 5 valves 473 other 40 • • • MPACT ANALYTICAL YSTEMS INC • . 1Ii i7lllr-7365 S.MAIN ST. BRIGHTON,CO �i.�\; 80601 303437.0150 EXTENDED NATURAL GAS ANALYSIS(OHA) DRAIN PAGE • PROJECT NO. : 201103130 ANALYSIS NO.: 02 COMPANY NAME: PCP MIDSTREAM-LP ANALYSIS DATE: MARCH 19.2011 ACCOUNT NO. : SAMPLE DATE : MARCH 18,2011 PRODUCER : CYLINDER NO.: 886 LEASE NO. : SAMPLED BY : STEPHEN ONDAK NAMEJDESCRIP: ENTERPRISE INLET PRE DENY @140 '"FIELD DATA"' SAMPLE TEMP.: 100 SAMPLE PRES.: 900 AMBIENT TEMP: - VAPOR PRES- : GRAVITY . COMMENTS : SPOT;NO PROBE GPM@ GPM@ COMPONENT MOLE% MASS% 14.650 14.730 0 ALCOHOLS 0.0006 0.0018 -.- - HELIUM 0.01 0.00 HYDROGEN 0.00 0.00 OXYGEWARGON 0.01 0.01 --- -- NITROGEN 0.32 0.40 - -- CARBON DIOXIDE 249 509 ..- -- METHANE 73.60860 52.69890 -- --- ETHANE 13.4435 16.0401 3.5886 3.6082 PROPANE 5.7633 11.3418 1.5851 1.5938 I-BUTANE 0.8191 2.1247 0.2672 0.2666 N-BUTANE 1,8738 4.8604 0.6894 0.5926 I-PENTANE 0.5245 1.6866 0.1901 0.1911 N-PENTANE 0.5144 1.6583 0.1881 0.1871 HEXANES PLUS 0.5210 2.0898 02930 0.2940 TOTALS 100.00000 100.00000 6.6995 6.7354 BTEY COMPONENTS MOLE% WF% HMI® 14.650 14.730 BENZENE 0.0251 0.0875 LOW NET DRY REAL: 1183.7 hcf 1170.1 het TOLUENE 0.0204 0,0839 NET WET REAL: 1143.4 hcf 1149.7 hcf ETHYLBENZENE 0.0004 0.0019 HIGH GROSS 01W REAL: 1280.8 lad 1267.6 het XYLENES 0.0038 0.0181 GROSS WET REAL: 1256.4 lad 1265.4 tail TOTAL STEX 0.0497 0.1914 NET DRY REAL: 19719.6 Ab 19827.3 Ab GROSS ORY REAL: 21713.0 Ab 21831.5 Ab RELATIVE DENSITY(AIR=1): - 0.7727 fCALC:OPaaD Zia&W479jL.W&&6037 COMPRESSIBILITY FACTOR : 0.99616 'TOLTAlLSD 17)ROC RDON.04 W93d0 ISP4I;ASDID6730 Man,'TA NASDEIXACQU➢112 MR0VONAPPLICATIONOFCUAR9RaAM-0141X6ARTAN MICLL ILCDNIQVES THE OSEOFHNSRDVPAMITONISIIlERESPOMLDUITOFDIE IAFR EUPACTAX40770ILSYSTINg ASSES163R0 ns'ATN/IPFODACCf1RICYOFIHERFMIRPDI AILJTIONNORAWC181921.1 ra3OFITSAP/4AATION.. 0 Elux` MPACT ANALYTICAL ` SYSTEMS INC. '1`\� �lIi filar--y S.MAIN ST. \\I\\tt,sa salmi/ ,A i -,�\\t%%u1mr./J! BRIGHTON,CO �; 2"'"bi %� 80601 ilrtal/ L . I 303637.0150 EXTENDED NATURAL GAS ANALYSIS(THAI GLYCALC INFORMATION PROJECT NO. : 201103130 ANALYSIS NO.: 02 COMPANY NAME: DCP MIDSTREAM-LP ANALYSIS DATE: MARCH 19,2011 ACCOUNT NO. : SAMPLE DATE : MARCH 18,2011 PRODUCER : CYLINDER NO.: 886 LEASE NO. : SAMPLED BY : STEPHEN ONDAK NAMEIDESCRIP: ENTERPRISE INLET PRE DEHY @14:30 "'FIELD DATA"' SAMPLE TEMP.: 100 SAMPLE PRES.: 900 AMBIENT TEMP.: VAPOR PRES. : GRAVITY : COMMENTS : SPOT;NO PROBE Componet Mole% WI% • Helium 0.01 0.00 Hydrogen 0.00 0.00 Carbon DIoxide 2.69 5.09 Nitrogen 0.32 0.40 Methane 73.60980 52.69890 Ethane 13.4435 1&0401 Propane 5.7633 11.3416 Isobulane 0.8191 2.1247 n-Butane 1.8738 4.8604 Isapentane 0.5005 1.8115 n-Pentane 0.5144 1.8563 Cydopentane 0.0240 0.0751 n+lexane 0.1123 0.4319 Cydohexane 0.0286 0.1074 Other Hennes 0.2088 0.7920 Heptanes 0.0782 0.3488 Methycyclohexane 0.0227 0.0985 2,2,4 Trimethylpentane 0.0000 0.0000 Benzene 0.0251 0.0876 Toluene 0.0204 0.0839 Ethylbenzene 0.0004 0.0019 Xylenes 0.0038 0.0181 C8+Heavies 0.0227 0.1190 Subtotal 99.98940 99.98840 Oxygen/Argon 0.01 0.01 Alcohols 0.0006 0.0018 Total 100.00000 100.00000 THE DATA PRESENTED HEREIN HAS BEEN ACQUIRED THROUGH JUDICIOUS APPLICATION OF CURRENT STATE-OF-THE ART ANALYTICAL TECHNIQUES. THE APPLICATIONS OF THIS INFORMATION IS THE RESPONSIBILITY OF THE USER. EMPACTANALYTICAL SYSTEMS,INC.ASSUMES NO RESPONSIBILITY FOR ACCURACY OF THE REPORTED INFORMATION NOR ANY CONSEQUENCES OF IT'S APPLICATION. • • • EMPACT ur1' 12..eF •a��1Rooiivis EXTENDED NATURAL GAS ANALYSIS',THAI PHA COMPONENT LIST PROJECT NO. : 2 01103 13 0 ANALYSIS NO.: 02 COMPANYNAM.E: DCP AIIDSTREAA5d.P ANALYSIS DATE: MARCH 19,2011 ACCOUNT NO. : SAMPLE DATE: MARCH 18,2011 PRODUCER : CYLINDER NO.: 886 LEASE NO. : SAMPLED BY : STEPHENONDAR NAME/DESCRIP: ENTERPRISE INLET PRE DENY®1490 ei'FIELDDATAeei SAAPLETEAP.: 100 SAMPLE PRES.: 900 AMBIENT TEMP.: VAPOR PRE&: GRAVITY : COMMENTS : SPOT;NO PROBE OPM6 GPM® COMPONENT PIANON MOLE% MASS% 14.650 14.730 Helium -.- 0.01 0.00 ... _. 91.10.445840 ... 0.00 0.00 -- ... Oxygen/Arlon -.. 0.01 0.01 -- -- NIIroBen ... 0.32 0.40 --. -- ' Carbon Dioxide --- 2.59 5.09 -- ... Medmne PI 73.60980 52.69890 ... Elhmle P2 134435 18.0401 3.5886 3.6082 Propane P3 5.7633 11.3416 1.5851 13938 1-Eulene 14 0.8191 2.1247 01672 0.2686 n-Eueae P4 1.8738 4.8604 03894 0.5926 2,2-Dhanhylpropece IS 0.0051 0.0164 0.0020 0.0020 • Ethanol 10 0.0001 0.0002 0.0000 0.0000 • Rama 15 0.4954 1.5951 41811 41821 f-Pmpnol )130.00040.00110.0000 0.0000 o-Patmo P5 0.5144 1.6563 0.1861 0.1873 21-DIme6gltumae 16 0.0072 00277 00030 00070 enhopaed X3 0.0001 00003 0.0000 40000 Cyclopenlme NJ 40240 0.0751 0.0070 0.0070 2,JOhnelhy@utene 16 0.0160 00615 0.0070 0.0070 2-MtPykeelmle 16 0.0971 0.3735 00400 0.0102 3410.1ylpenlane 16 0.0492 0.1892 00200 00201 n-Hr•"• P6 0.1123 0.4319 0.0460 0.0463 2yDietelhyllamene 0 0.0022 0.0098 0.0010 0.0010 Mcdgigciopemeoe 146 0.0373 0.1401 0,0130 00)31 2,4D0uelhylpeamre 17 0.0041 0.0189 0.0020 0.0020 2$yTdmekylbmene 17 0.0004 0.0018 0.0000 0.0000 Beaune A6 0.0251 0.0875 0.0070 0.0070 3,3-DimetyIpeamne 17 0.0008 0.0036 0.0000 0.0000 Cyclamate NS 0.0286 0.1074 0.0100 0.0108 2.Mcdglheaane I7 0.0146 0.0653 0.0070 0.0070 2,3Dim.Il04Mnlene 17 0.0036 00161 0.0020 0.0020 1,1-Dimelhyleyciopmtaae 117 00033 0.0145 0.0010 0.0010 3.Medu4Seaaaaoe 17 00129 0.0577 0.0060 0,0060 103-Dimetbylcyclopemao N7 0.0035 0.0154 0.0020 0.0020 14,3-Dimelhyleydapemano N7 0.0031 0.0136 0.0010 0.0010 3-Edeylpenlme 17 0.0003 00013 0.0000 0.0000 11j47imd11y4Tadopenlame N7 00051 0.0224 0.0020 0.0020 e1•Heplene P7 0.0233 0.1042 0.0110 0.0111 1c,2-Dimcikylcyclop0uane N7 0.0001 0.0005 0.0000 0.0000 • Page I EMPACT AmtIIlniSystems,Inc 3855.Mali Street,Balghtan,CO 60001 303437-0160 S MehyIOctdceeo N7 0.0227 0.0995 0.0090 0009L 2,2AImcdiy b ane 15 0.0009 0.0046 0.0000 0.0000 1,1,3-TNei*4cyclopentene 147 0.0003 0.0015 0.0000 00000 ENylc3olopenlaae N7 0.0006 0.0026 0.0000 00000 2,54Nmety0aez.ne 18 0.0007 0.0036 00000 0.0000 2A4Nme8lylMamo IS 00008 0.0041 00000 0.0000 1521.4-Taimetbylrydopenlme N8 0.0007 0.0035 0.0000 00000 3,34NmehyNexne IS 00002 0.0010 0.0000 01000 11,204-THanakilcyc1cpemaae NB 00005 0.0025 00000 00000 Toluene A7 0.0204 00839 0.0070 00070 2A-Olmeahylhmmne IS 0.0004 00021 0.0000 001100 2-MethylbeNane 08 0.002E 0.0143 0.0010 0.0010 4.Me0tylhepYlm IS 0.0009 00046 0.0000 00000 3-108031.3-e1104pteno 18 0.0001 0.0005 0.0000 00000 3.Mdhylheptno 18 0.0001 0.0005 0.0000 00000 Iert,3-Trimellylrydopmtane NS 0.0035 0,0)75 0.0020 0.0020 3-EOymexane IS 0.0002 00010 0.0000 0.0000 144-Dime10•ILyelohenoe NB 00009 0.0045 00000 0.0000 1,1.OIme001eyelohenne NB 0.0004 00020 0.0000 00000 3EElhylme00kydapaDne NB 00001 0.0005 0.0000 00000 21-EAy1mN0kytlapcewe NB 0.000) 00005 0.0000 0.0000 I,1,\1e101tthyle0'chgalme N8 0.000) 0.0005 0.0000 0.0000 Ii.24linethylcyebhtcane N8 00006 00030 0.0000 0.0000 ' loOtIane PS 00036 0.0153 0.0020 0,0020 144-DOnelhylcyel hexane N8 0.0002 0.0010 00000 0.0000 2,3,5-7Hmtlhylhewne 19 0.0001 0.0006 0.0000 0.0000 2JA-Ttinttlhylhrmne 19 0.0001 0.0006 0.0000 0.0000 1g2-Dimelhyloyclohe.'ne N8 ' 00001 0.0005 0,0000 0.0000 1,1,4-Tdmethylcyddtexene N9 0.0007 0.0039 0.0000 00000 ' 2,2,3-Trimehylhexene 19 0.0002 0.1012 0.0000 0.0000 Ehylcyelo8ronc NS 00002 0.0010 0.0000 00000 0Propylcyclepentene NB 0.0002 00010 00000 0.0000 lo,3e,5-TdmdlO•lcydohmme N9 0.0001 0.0006 00000 0.0000 Et lbenzeae I8 0.0001 0.0019 0.0000 0.0000 IS248-Tdmelhylcyclobtnne 149 0.0001 00006 0,0000 0.0000 Id-1XmNh146nnIe(m-Xylem) AS 0.0023 0.0109 00010 00010 • IA-DimeNylbmaie(p.70•len) AS 0.0009 0.0043 00000 00000 3A•Mmedwllwilne 19 00002 0.0012 0.0000 0.0000 3A•11Imt00WcpWae(2) 19 0.0001 0.0006 00000 00000 4-E80herne 19 00001 0.0006 00000 0.0000 4-hkhylocbne 09 0.0002 0.0012 0.0000 0.0000 2-hkOOlodmc 19 0.0002 0.0012 00000 00000 3.1letyledane 19 0.0002 0.0012 0.0000 00000 1,2-Dime100auune(o-Xyleat) AS 0.0006 0.0029 0.0000 00000 i-BuOlajclopmmm N9 0.0001 0.0006 0.0000 0.0000 Unhtarncts US 0.0002 0.0010 0.0000 0.000D n•Nnne P9 00006 0.0034 0.0000 0.0000 n-Bt104cyclopmtene N9 0.0001 0.0006 00000 0.0000 n•Propylhtarne A9 00001 0,0005 00000 0.0000 1,9A1dhytetylbemene A9 0.0001 00005 0.0000 00000 1,7,5-Tlnethylbenzene A9 0.0001 0,0005 00000 00000 t-Butylbeeeoe AID 0.0001 00006 00000 00000 UdmownC9, U9 00003 00017 0.0000 0.0000 et-Decal PIO 0.0001 0.0006 00000 0.0000 Udmow,Cl0e UI0 0.0001 00006 0.0000 00000 UOIOIownCBe UIS 0.0002 00023 00000 00000 TOTAL 10000000 100.00000 60095 06454 BMEXE:03VONENTS h10LEA WT44 BTU@ 14,650 M-130 BENZENE 00254 00875 LOW NET DRY REAL: 1163,7 her 1170.1 her TOLUENE 0.0204 00639 NET WET REM.: 1143.4 her 1149.7 led ETHYLBENZENE M0004 0.0019 NIGH GROSS DRY REAL: 1280.8 her 1287.0 her XYLENEB 00038 0.0101 GROSS WET REAL: 1288.4 her 1286.4 her TOTN-BTEX 0.0497 0.1014 NET ORYREAL: 10719.0 AL 10827.3 Mu GROSS DRYREAL: 217130 Ab 21631.000 RELATNE DENSITY(MR-1) 0.7727 a'AIbCMMONf A MPelLsx6Aoa GOMPRESSI61LIT'FACTOR: 099816 VELICUDMMOClR0RY.WLMGNIIN5:AMMO 7nsaIr MA4saavlcOUMEDI AOMIA14MA7m''OFC4Me,:1T.1TAMORINNtrAM.LMCALTECHNWQUES II WEOPIIIIMMICUITICLVISIIMRESTGRMLII,OFIVEUSIA LVMLTAMALINC LS7AT5*SAAml6MI Aa4GCeDtMTRlaIccL v[fOe'n rkE onTDINTO WITZMMANMN$mn1CLsOFMYANLCAFMN • Papa 1 EMPACTAiWylical Systems,Its 365 S Melt,SBeeL B69hlon,CO 80601 3034337-0150 a o • 1 N N N t 3 GM br'tea o' o Q1 S ti aria I EEEE w u FFFf 4-- o i A E .§^ 8 g __ a rc il o„o 3EJ M Jill LL X x 0 us0 us•Av f F it —to ti — f Am -`� of , �� u a � ErS ;� ti-e.1 33 r �dv �, 04. iti etl' �z g • `g IN € I'1,� �w��18O No .r�.iani%`has°� � tirr -15.a tie 4 - ,+�. VII \`IJ%,� %intim tour v It 1 ' • • i • ; ii- ar Y IIi ' aaI . . • I431i , . dd.i ddwwwR AAAAAn .011111111111111111111111111 , c0000ddodouv0000dd00000dddi FFFFF`sFFTFjFFFFFFFFFFFFFFFt` d.i d dddddddddddd ddddddddddd Od411 f2Iii44M 211 8211144__ 8 1 II' I LEA • J .. u ? 2 ri8WWi.lk3 6 y(y(,�yy.�yy ycy2 YY ppyp C OO d O d E 0 0 L !O C L C#I C l f t g C G F C F! w, ‘.4.-.00001400013000000000000S; P I- ,5,,,,..0.!00.0.0.0.0.0.0.00„ . F E t F • I i id i hii" h ilIo._ i:III 1C -1}j�1}_o��! ps_S�5Ea�₹[Jpfi�Jayn[Jy�nn'a'aaEJpO�alj�f�> � Wk tk tdiLLLL!fmfllaNWIllNiJflfj • VQ U 0 Combustion Devise(Tank Control) Enterprise Compressor Station • DCP Midstream,LP Source ID Combustor Stack Height fl Desaipdon Combustor Stack Temp. deg F Manufacturer Unknown Stack Flow acfm Model Unknown Stack Velocity 8lmin Serial a Unknown Stack Base ft Manufacture Date Unknown Latitude deg Fuel Heat Value 958 Bhdscf Longitude deg Pilot Flow Rate 25 eddy or Pilot Heat Input 0.02 MMBaulrr UTM Zone Pilot Potential Ope 8760 hrhr UTM Northing m Plat Potential Fuel 0.22 MMsccfNr UTM Fasting m Deeds ction Efbcei 95% Datum Emissions from Pilot Combustion Emission Source of CAS Factor Emission Pollutant Number (11VMMacf) (b5lhr) Obad (tonhr) Factor NOx 100 0.01 87.60 0.05 AP-421 CO 84 0.01 87.60 0.05 AP-42' VOC 5.5 0.01 , 87.80 0.05 AP422 S02 0.6 0.01 87.80 0.05 AP-422 PM 7.6 0.01 87.60 0.05 AP-422 2-Methykraphthalene 91.57.6 2.40E-05 0.0001 0.8760 0.0005 AP-423 3-Methylchlorardhrene 56-49-5 1.60E-06 0.0001 0.8760 - 0.0005 PP-422 7,12-Dimethylbenz(a)en8va , 1.80E-05 0.0001 0.8760 0.0005 AP423 Acenaphtbene 63-32-9 1.80E-06 0.0001 0.8780 0.0005 AP-422 Acenapllttwlene 208-96.8 1.80E-06 0.0001 0.8760 0.0005 AP423 Mthracene 120-12-7 2.40E-0B 0.0001 0.8760 0.0005 AP423 Bende)arahrecene 56-55-3 1.80E-06 0.0001 0.8760 0.0005 AP423 Benzene 71-43-2 2.10E-03 0.0001 0.8760 0.0005 AP-422 Bsnm(alpyrene 5032.8 120E-06 0.0001 0.8760 0.0005 AP422 Benza(b)fluoran here 205-99-2 1.80E-08 0.0001 0.8760 0.0005 AP423 Berrzo(p,hAnehleoe 191-24-2 1.20E-08 0.0001 0.8760 0.0005 AP423 Benzo(Mfluoranthene 205-82-3 1.80E-0B 0.0001 0.8780 0.0005 AP423 Chycene 21847-9 1.80E-06 0.0001 0.8760 0.0005 AP-423 • Dibenzo(a,h)anthracene 53-70-3 120E-06 0.0001 0.8780 0.0005 AP-423 Dldhlorobenzene 25321-22.8 120E-03 0.0001 0.8760 0.0005 AP423 Fkroranthene 208444 3.00E-08 0.0001 0.8760 0.0005 AP-423 Fl orene 86-73-7 2.80E-08 0.0001 0.8760 0.0005 AP-423 Formaldehyde 50-00-0 7.50E-02 0.0001 0.8760 0.0005 AP-422 n-Herren 110543 1.60E00 0.0001 0,8760 0.0005 AP-423 Indeno(1,2,3c,d)pyrene 193-39-5 1.80E-08 0.0001 0.8760 0.0005 AP-422 Naphthalene 91-20-3 6.10E-04 0.0001 0.8760 0.0005 AP-423 Phenanthrene 85-014 1.70E-05 0.0001 0.8760 0.0005 AP-422 Pyrene 129-00-0 5.00E-08 0.0001 0.8780 0.0005 AP423 Toluene 108-88-3 3.40E-03 0.0001 0.8780 0.0005 AP-423 ArseSc 7440-38-2 2.00E-04 0.0001 0.8780 0.0005 AP-424 Beryllium 7440-41-7 120E-05 0.0001 0.8760 0.0005 AP-424 Cadmium 7440-43-9 1.10E-03 0.0001 0.8780 0.0005 AP-42" Chromium 7440-473 1.40E-03 0.0001 0.8780 0.0005 AP-424 Cobalt 7440-48-4 8.40E-05 0.0001 0.8760 0.0005 AP-424 Manganese 7439-96-5 320E-04 0.0001 0.8760 0-0005 AP-424 Mercury 7439-974 2.60E-04 0.0001 0.8760 0.0005 AP-42' Nickel 744042-0 2.10E-03 0.0001 0.8760 0.0005 AP-424 Selenium 7782-49-2 2.40E-05 0.0001 0.8760 0.0005 AP-424 Total HAPs 0.0033 28.9080 0.0185 'EPA AP-42,Volume I,Fifth Edson,July 1998.Table 1.4-1 2 EPA AP-42,Volume I,Filth Wilton,July 1998,Table 1.4-2 3 EPA AP-42,Volume I,Fifth Edition July 1998,Table 1.4-3 • 4 EPA AP-42,Volume I,Fifth Edition,July 1998,Table 1.4-4 Enterprise Compressor Station DCP Midstream,LP Continued • Vents to Combustion Device Flow Rate Operation Flow Rale Neat Value Heat Rate Vent Stream (scrawl (hrryr) (MMscfyr) {Mutaelf (MMBtt) Condensate Tank 18.81 8760 0.16 3397 859.9 Emissions from Combusting Vent Gas NOx NOx CO CO Vent Stream (lbmrj (tpy) abler) (tpy) .. Condensate Tank Vents 0.009 0.040 0.038 0.158 Total 0.01 0.04 0.04 0.16 Note:NOx emission factor,0.138 lb1MMBtu,and CO emission factor,0.5498 IhMMBtu,from TNRCC Flares and Vapor Oxidizers,Table 4 Flare Factors Total Emissions NOx NOx CO CO VOC VOC Vent Stream (Ibfhr) (toy) 0blhr) (toy) (Ibmr) (toy) Condensate Tank Vents 0.008 0.040 0.036 0.158 SeeTank Calcs Pilot Emissions 0.010 0.050 0.010 0.050 87.60 0.05 Total 0.02 0.04 0.04 0.16 • • S N C W a 8 0 to W C c a W z w a • a C W JI Q ' t n N a o o R (.0 9 a = o w B �o ig z 3@wafa a LL _ A 3 O „ w [gogi w " v 0 a N o 0 E c EE ado w t.9. 666 °- w2 - W z+ $ ag °DR ow > ic 1111 Flow rate of each skimmer 10 acfm 5.26 MMACF/yr 4788 Elevation 12.2 psia 4.36 MMSCF/yr Hydrocarbon Concentration 100 ppb Assume Benzene 78.118 MW Total mol flow 11498.66 IbmoVyr 0.001 Ibmol hydrocarbon(benzene)yr 0.09 lb hydrocarbon(benzene)yr • • . Heater Emissions DCP Midstream,LP Enterprise Compressor Station [thy Retailer Unit Rehm 251MMBOa9w Fuel usage: 0.00E MMWOW 2206 MMstfvr Osnaling ham 6760 Petri Nil Sato Value 956 Bbled Clark Pollutant Emission Calcwtlons Emlubne Cmsila Pollutant EtaMoe Fader Dea Souse tbr) NO,x 100 IWMMrt! AP42 Section 1.4,Table 1.4-1(Jul 1998 ration) 1.14 602 0.6 IWMMsd AP-42 Section 1.4,Table 1.4-2(Jury 1998 stew) 0.01 PM 7.6 IMMMstf AP42 Section 1.4.Tale 1.4-2(Jute 1998 salon) 0.09 CO 64 IbMMbd AP-42 Seaton 1.4,Tale 1.4-1(July 199(1 salon) 0.96 VOC 6.5 IbMMsd AP-42 Sedan IA,Table 1.4-2(Jute 1999 salon) 0.06 NWrreporter*Criteria Pollutant Emission Cakuiatkns Emlulaa De Primus' • Nazudoue Ak PcWhntMAP) Emission Feder Data Sauce (robre) 0RM Benzene 2.1E-091bA1Med AP42 Section lA 240E-06 50 Dldmlobnlaene 1.2E-03 MAMBO AP42 Section 1.4 1.37E-05 — . Formaldehyde 7.6602 6NMMed AP42 Sedan 1.4 8557E04 50 NepneWene 6.1E-041OJMMed AP-42 Section 1.4 SATE-06 60O n-Hexane 1.8E+00 I WAMsd AP-42 Section 1.4 0.0 1000 Polnyds Organic Matta(ROM): 2•M9m$nep/9bdne <2Ara05 b'MMId AP42 Eaton IA 2.74E-07 - 3-3.180cleoranthsM <1.8E-06 eanad AP-42 Sedbn 1A 2.08208 - 7,Marlette eert(e)enlMcex <16E.0i b1MMed AP-42 Beton 1.4 1.83E-07 — AoelMyyn8ne <1.8E-06 tMMed AP42 Section 1.4 208E-08 - AcenaW4helene <1AE-08 ba6Msd AP-42 sedan 1.4 206E08 - • Adh2ecene c 243-06 eRAMad AP-42 talon lA 271E-0B — Ben <1AE-08 bitMec1 AP-42 Section IA 208E-08 — Ben elMeane <12E06 lottedAP42 Section IA 1.37248 — Benmfmlboanthene c 1.6E-08 bMMed AP42 Sedbn 1A 2.06308 — Ben2440A0peneeM <12605 bMMMed AP-42 Sedbn 1A 7.37E-08 - BemoBdflrosbhMe <1.BE06 b.lMed AP-42 Salon 1A 2.08E-08 — ClnyaNa <1.8246 UMW( AP-42 Section 1.4 206E-06 - veaM(aAlenbacene <1.2E-06 bNMsd AP-42 Section 1.4 1.37E-08 - F6noaMhene <S0E-03 UMIAK( AP-42 Section 1.4 3.43248 -Rumen <2.8E-06 bMMed AP-42 Section 1.4 9.20E-08 - MM21d1,2,9gdbymM <1.8E08 bIMMed AP-42 Section 1.4 2.06E08 - P6eranlhsne <1.7E-05 buMMed AP42 Sedb21A 1.94E-07 - Pilana <5.0E-00 bRAMed AP42 648110111.4 5.72E-0e - TOTry OM 1.01E-06 50 Toluene 3.4203 blAMed AP-42 Salon 1.4 3.89E-05 1000 'TOTAL <1.96Ee00 0.0 — . •0dee*o R.PYawluaa A a WMNsle isforN..otabReooneNS PWMeee i DCP MMahurn LP 1024x2011 III Heater Emissions DCP Midstream,LP Enterprise Compressor Station Neater gaYng; O.m1MMe tar Fual woes: 0.001 imatum 688 MM¢alr • OFralne MOW 8760 haute Fuel Mean Value 958 B1uaci Criteria Pollutant Emission Calcustions teasslona CMMa Pollutant Bmlflen Factor Date Source 0Py) NCI! 100 IMMMsd AP42 Bedion 14 Table 14.1May 1996 mylew) 0.34 6Os 0.6;Mated AP-42 Section 1.4 Table 14-2(fly 1998 r ssion) 0.00 PM 7.8 blMMed AP42 Section 14 Table 1.4-2 Duly 1996 martin) 0.03 CO 84 IMMMecr AP42 Section 14 Table 1.4-1(Jay 1996 rSSn) 0.29 VOC 5.5 MMMsa AP42 Sects 1.4,Table 1.4-2(July 1968 reason) 0.02 Non-renorrabte Criteria Pollutant Emission Calculations Embalms De Minima' NmrdmlaAM Pollutant plAP) Eminton Factor Data Source neMyr) Man Benzene 2.1E-03 thalami AP-42 Sedan 14 7.20E-06 60 Dichbrobanzene 1.2E-03 entrant( AP-42 section 1.4 4.11606 Formaldehyde 7.5E-02 m'MMaG AP42 Section lA 257E-04 60 NapfhaNne 81E-04 IOMMed AP-42 SMSon 1.4 209E•0S 500 n-H91M11e 1.8E+00 0.VMMed AP-42 Seaton 1.4 0.0 1070 Palycy*01911k Meter(POM): 244S$$tlwNhpyne <24E-05 IdMMed AP42 Section 1.4 823E-08 — 3-Memyydo2nMtone <1.8E-06 @MMeCf AP-42 Seaton IA 6.17E09 — 7,1RAi1ellaMen8(e dMitracew <1.6E-06 tMMed AP42 Sedan 14 OA9E-0e - AwnteMAaa <1.6E-08 m&IMad AP42 Section 14 ' 617E-09 — III AONMDM6Mem <148-04MMMed AP42 Section 14 6.17E-09 - Aneimeene 4 211-06 B/a1Med AP-42 Seddon 1.4 823E-09 — pe/M(a ol'eLC1M <1.8E-0fi MMMad AP426101100lA B17E4M - aemoaMYINq <1,3E-0B IWMMsc1 AP42 Set lA 4.11E-09 Bwc(ppwmnlwie <1.8E-0B MMMed AP-42 Section 1.4 _ 8.17E-09 - . Ben(9Alkuylene <1.2E-06 I881Mtd AP42 Sedan lA 4.11E-09 — aenm(deltmm hone <1.8E-06 R1e1Med AP-42 Section 1.4 6..17009 - COyaene <1.8E-06 M/MMed AP-42 Section 1.4 £17009 - arreezienemerratene <1.2E-06 MMMed AP-42 Sadao 1.1 4.11E-09 - fRpmBane <.20E-08 M/MMed AP-02 Section 1.1 1.03E-08 — Phyane <29E-0B MMMS AP42 2491011.4 9.80E-09 - /ndeno(1,23cd)eyrcne <1.8E-0B FSM1Mad AP-42 Sedan 1.! 817609 - pfiylyRkeec <1.7E-06 IblMMed AP42 Section 1.4 5.83608 — "gene <5.0E-0B IRMMed AP42 Section 1.4 1.71E08 - TOTAL POM 3.02E-07 30 Toluene 3.4E-03 IOMMed AP-42 Section 1.4 1.17E-0S 1000 TOTAL <1.861400 6.0 — . 'CMeam Re9MMm timber&De MNenk tame la MonhNm RnaDge PLTMOm • DCP lldeeenn,LP 10.242011 Heater Emissions DCP Midstream,LP Enterprise Compressor Station Heater Unb Raw 000E-16MSmbr Fuel usage: 0.000 MMemlr 006 M.MS O MO%Num 8780 haus Fuel Misting Value 988 Blued treads Pollutant Emission Calcuatbns Embalms C1Wna Polmmra E1111Ylon FamOr Dm Source 1419 IdOx 100 WMMsd AP-42 Sadim 1.4,Table 1.4-1(July 1998 merlon) 0.0W SO, 0.6 mlMM cr AP-42 Se on 1.4,Table 1.4-2(94 1098 merlon) 0000 PM 1.5 m1MMsd AP-42 Section 1A,Tame 1.4-2(July 1998 mullion) 0.000 CO 84 IbIMMsd W-42 Section 14.Tame 1.4-1(JW'1088 rekSiell 0.002 VOC O5164Mrd 1P-42 Section 1.4,Table 1.42(JW 1998 meebnl 0.000 11100reporiaWe Cdtarla Pollutant Emission Calculations Emissions MMWmue' . Emrdaus Alr Pollutant(HAP) Emission Factor Data Soares (t'NFh Mr Benzene 216- Ib/1AMed PP-42 Sedan 1.4 6.18E-09 50 Dldlorobenrere 1.2E-13 lmMMed AP42 Secmn 1.4 929E-08 Formaldehyde 7.8.642 IMAMed AP-42 Seellm 1.4 2.08E-08 50 NaNmlMele 191E-0/ImMMed AP-42 Seaton 1.4 1.67E-08 500 nHmrle 1.9.600 IOIMMed AP-42 Sec0cn 1.4 00 1000 Pebc dicOmmlc Mead PO60: <24E-05 bMMed AP-42 Sedlm 1.4 160E-t0 - 3-MM540150mdlume C 1.8E-0611NAMad AP-02 Sectb11.4 4.94E-it - 7.12-0InNlnwbel *'tkI,L8ae <1.8E-06 b!AMec1 AMC Section 1.4 4.39E-10 - ApMFpMSM <1.8043 Wad AP-42 Section 1.4 494E-11 - ppn9pp801ym <19E-06 bMMed AP-42 Sedbn 1.4 4.94E-11 — AnlMnlene <240410 WMMsc1 AP-42 Section 1.4 508E-11 - E808f nlM0aee <1.8E-06 WMMed AP-425xton 1.4 4.94E-11 - eelW(N9eee C 1.2E-06 bANtMa1 AP-42 Sect,1.4 3.29-11 — Banmtt)e9WanMene <1.8E-08 bNMMd AP-42 Waal 1.4 4.84611 - BMmM,69pe ene <120476 B MMed AP-42 Sed6n 1.4 3.29611 - Sp6209Avaanmane <1.8E-166RAMecf AP-42 Sector 1A 4.94-if - CerMan4 <18008 WMMed AP-42 Sacks,1.4 494[x11 - Obem(e,67aaf6recmn <12E-06 bMMed AP-42 H&Mon IA 3.20E-11 - . FAomnDMne <3.0E-05 WMMed AP-42 Sedbn IA 523-71 - FAmmne <28E-06 WlANd AP42 Section 1.4 7.58611 - Indem(1,234dbwmn <1.8E-0e WNMed AP-42 Section IA 4.04-11 — Phenam6lene <1.7E-00 bAMed AP-12 Section 1.4 466-10 - Panne <50.6-08 WMMed AP-42 Becton 1.4 L37E-10 - TOTAL POM 2.42E-09 80 'toluene 3.4E-03WLIMad AP-42 Seaton 1.4 9.93E-08 1000 TOTAL <1.88E+00 00 — 'eeenax reaeama moor s,De imam mars far InnCmam RrW.Ie FWWevn OLP Mideesa LP 100412011 Enterprise Compressor Station • Compressor Blowdown Emissions DCP Midstream,LP Carbon Dioxide 44.0 2.647 1.16 5.57 Helium 4.0 0.006 0.00 0.00 O gen 32.0 0.000 0.00 0.00 Nitro!en 28.0 0.294 0.08 0.39 Methane 16.0 77.493 12.40 59.33 Ethane 30.0 12.696 3.81 18.23 - Pro•ane 44.0 4.621 2.03 9.73 i-Butane 58.0 0.571 0.33 1.58 n-Butane 58.0 1.077 0.62 2.99 i-Pentane 72.0 0.217 0.16 0.75 . n-Pentane 72.0 0.203 0.15 0.70 Other Hexanes+ 86.0 0.000 0.00 0.00 n-Hexane 86.0 0.175 0.15 0.72 Benzene 78.1 0.000 0.00 0.00 Toluene 92.1 0.000 0.00 0.00 Eth (benzene 106.2 0.000 0.00 0.00 QErallill. 106.2 0.000 0.00 0.00 • VOC wt% 16.47 % Methane Wt% 59.33 % C02 Wt% 5.57 % Volume @ 60 psi 3425.8 cubic feet/event Vent ton/blowdown #/yr TPY VOC. P018 0.094 12 0.19 C235 0.094 12 0.19 C236 0.094 12 0.19 C238 0.094 12 0.19 Total 0.75 T1 Blowdown 0.094 12 0.19 Turbine T1 blows down to a separate vent. • SITE SLOWDOWN Enterprise Compressor Volume Measurements • wit HP 234 3550 235 3550 238 3550 238 3550 Diameter Length Pressure Volume 1t]t In Et alit cn C-234 N(P-01811235/236/238 Inlet Piping 1 13.0 37 80 219.3 Disch Piping 1 4.6 97.3 80 71.8 1st stg to cooler 1 13.8 63 80 418.6 Cooler to 2nd stg 1 8.6 144.3 80 374.5 2nd stg to cooler 1 6.9 76.3 80 128.7 Cooler to 3rd stg 1 6.9 65.3 80 108.5 IC-1 Tubes 54 1 48 80 91.1 IC-2 Tubes 66 1 48 80 111.3 AC Tubes 53 0.75 48 80 50.3, 1st Stage Scrubber 1 48 6.18 80 498.7 2nd Stage Scrubber 1 36 6.8 80 309.6 0 3rd Stage Scrubber 1 30 6.7 80 211.9 1st Stage Suction Battle 1 30 10 80 316.2 1st Stage Discharge Bottle 1 24 10 80 202.4 2nd Stage Suction Bottle 1 24 6 80 121.4 2nd Stage Discharge Bottle 1 19.2 6 80 77.7 3rd Stage Suction Bottle 1 19.2 4 80 51.8 3rd Stage Discharge Bottle 1 19.2 3.5 80 45.3 1st stg Cylinder 3 14.4 0.6 80 13.1 2nd stg Cylinder 2 10.2 0.6 80 4.4 3rd stg Cylinder 1 7.8 0.6 80 1.3 NOTE: All streams routed to the front end of the plant until they are down to 80 psi. 3425.8 cft 3.43 macf S Monthly Meter Analysis DCP Midstrear January, 2010 • 212950 ENTERPRISE DISCHARGE 10 Total C6 Pli. Component Mole% GPMs Mass % Property Sample Fractic Carbon Dioxide, CO2 2.6470 5.5615 Pressure Base 14.730 Nitrogen, N2 0.2940 0.3932 Temperature Base 60.00 Methane, C1 77.4930 59.3511 HCDP @ Sample Pressure Ethane, C2 12.6960 3.4061 18.2255 Cricondentherm Propane, C3 4.6210 1.2771 9.7280 HV, Dry @ Base P,T 1210.02 iso-Butane, iC4 0.5710 0.1874 1.5844 1-11/, Sat @ Base P,T 1188.84 n-Butane, nC4 1.0770 0.3406 2.9885 HV,Sat @ Sample P,T iso-Pentane, iC5 0.2170 0.0796 0.7475 Relative Density 0.7258 n-Pentane, nC5 0.2030 0.0738 0.6992 Fws Factor Hexanes Plus, C6+ 0.1750 0.0766 0.7200 Free Water GPM Water, H2O Stock Tank Condensate Br-16/mm Hydrogen Sulfide, H2S 0.0000 26#RVP Gasoline 0.334 •Oxygen, O2 0.0000 Testcar Permian 0.562 Carbon Monoxide, CO Testcar Panhandle 0.501 Hydrogen, H2 Testcar Midcon 0.503 Helium, He 0.0060 0.0011 C4 and Lighter ST Cond Argon,Ar C5 and Heavier ST Cond C6/C7 GPM Totals 100.0000 5.4412 100.0000 Sample Date: 12/01/2009 Pressure: 850.9 Type S Temperature: 86.0 *** End of Report*** • 0 • Enterprise Compressor Station Summary of GHG Emissions DCP Midstream, LP Combustion Sources 88,682.5 Slowdowns 70.9 Rod Packin• Venti , 3,266.72 TEG Dehydration System 53.27 Total CO2e PTE 92,020 • • DCP Midstream,LP 10/24/2011 ri g � 2 \ { � fq • ] 2 c \ { 04 2 C0m2 ill \ . co \ / } j \ mit # far - R ) ] 2 \ to co . toC \ r § IC • ] _ 1O CO N E k o 07 N 6o o N 022 \ . 22mmCO2 ) o � § w � k � � � ■ i § § § § 2 § § § t § co CO NNelnw ° j § j • » r 22 . 3a � a % kk co ! 2 — ttt ca ! R $ § � 6. 2222 co co § § O. = 0 au iii\ 77 ; { uc ■ ca E _ , @ , q ( 2 ■ = I ! ` $03 ) • C LL O � [ / t § � k IL ) a) CO III 0 $ \ \ / I . E • Enterprise Compressor Station Compressor Slowdown Emissions DCP Midstream,LP Carbon Dioxide 44.0 2.647 1.16 5.57 . Helium 4.0 0.006 0.00 0.00 O •en 32.0 0.000 0.00 0.00 Nitro.en 28.0 0.294 0.08 0.39 Methane 16.0 77.493 12.40 59.33 Ethane 30.0 12.696 3.81 18.23 Pro.=ne 44.0 4.621 2.03 9.73 i-Butane 58.0 0.571 0.33 1.58 n-Butane 58.0 1.077 0.62 2.99 i-Pentane 72.0 0.217 0.16 0.75 n-Pentane 72.0 0.203 0.15 0.70 Other Hexanes+ 86.0 0.000 0.00 0.00 exane 86.0 0.175 0.15 nH 0.72 VOC wt% 16.47 % Methane Wt% 59.33 % C02 Wt% 5.57 % • Volume @ 60 psi 3430.0 cubic feet/event Vent ton/blowdown #/yr TPY VOC TPY Methane TPY C02 TPY CO2e P018 0.094 12 0.19 0.67 0.06 14.2 C235 0.094 12 0.19 0.67 0.06 14.2 C236 0.094 12 0.19 0.67 0.06 14.2 C238 0.094 12 0.19 0.67 0.06 14.2 T1 0.094 12 0.19 0.67 0.06 14.2 ragAggtari • • DCP Midstream,LP 10/24/2011 \ ei al � � % na oft / - 02 I To \ > a.O y /k \ O k ) Jo ±° R ® e ■ „ � ) 1 { § 2u a O , . > $ 41 % 2 - C2 ;- on 2 2 .- . E0 ( t 2 t = az ° CO { a ikk C \ I 03 % a < 2k \ t ! 2 a ) I § % A2 I. in 03 co ttt & r2 � ft § % E• E 000 . o ta• C ` J \ / { co k O. la ) Iz ) k ` ::' j o D k� ! & g ,2 § § ; 2 | ) n k { | § • § 2 § T tJ /, l'.1 t 10 ID i ` ! 2.2 '. - - PHc & (n _ 0,. |` i ! ! ! & � flu \kP I • .! . a f • ri �k � k k GI ' ` r « ■ § ! r • Attachment D Company Contact Information Enterprise Compressor Station • S Form APCD-101 -A' Colorado Department of Public Health and Environment 4 i Air Pollution Control Division 7)4 Colorado Department ofPublic Health Company Contact Information Form and Environment Ver.September 10,2008 Company Name: DCP Midstream, LP Source Name: Enterprise Compressor Station Permit t Wesley Hill Compliance Michael Barrett ** Contact l: Contact2: 370 17th Street, Suite 2500 3026 41°Avenue Address: Street Address: Street Denver CO 80202 Greeley CO 80631 City State Zip City State Zip Phone Number: 303-605-1716 Phone Number: 970-378-6383 Fax Number: 303-605-1957 Fax Number: 303-572-3516 E-mail: WDHill@dcpmidstream.com E-mail: MJBarrett@dcpmidstreamcom • Billing Contact: Billing Contact: s Wesley Hill Wesley Hill (Permit Fees) (Annual FeesZ See Permit Contact See Permit Contact Address: Street Address: Street City State Zip City State Zip Phone Number: Phone Number: Fax Number: Fax Number: E-mail: E-mail: ** NOTE-New Compliance Contact for all Colorado facilities Check how would you like to receive your permit fee invoice? Mail: 11 E-mail: 11 Fax: ❑ Footnotes: The permit contact should be the point of contact for technical information contained in the permit application. This may be a company representative or a consultant. 2 The compliance contact should be the point of contact for discussing inspection and compliance at the permitted facility. 3 The billing contact(Permit fees)should be the point of contact that should receive the invoice for fees associated with processing the permit application&issuing the permit.(Reg.3,Part A,Section VI.B) 4 The billing contact(Annual fees)should be the point of contact that should receive the invoices issued on an annual basis for fees associated with actual emissions reported on APENs for the facility. (Reg. 3,Part A, Section VI.C) Page 1 of 1 05 Company Contact Sheet.doc • Attachment E Ambient Air Quality Analysis Enterprise Compressor Station • • • Ambient Air Impact Analysis The Colorado Department of Public Health and Environment Colorado Modeling Guideline for Air Quality Permits, dated August 20, 2010,states that the preliminary air impact analysis for construction permit applications can be done using quantitative(modeling) or qualitative(non- modeling)methods. Table 1,Modeling Thresholds,describes that modeling is usually warranted for sources that meet any of the following criteria: • Carbon Monoxide(CO) emissions equal to or greater than 100 tons per year(tpy) or 23 pounds per hour • Nitrogen Oxides (NOx)emissions equal to or greater than 40 tpy or 0.46 pounds per hour • Sulfur Dioxide(SO2) emissions equal to or greater than 40 tpy or 0.46 pounds per hour • Particulate Matter(PM10) emission equal to or greater than 15 tpy or 82 pounds per day • Lead emissions equal to or greater than 0.6 tpy or 100 pounds per month • Sources of 3O2,PM10, CO, or Pb where a substantial portion of the new or modified emissions have poor dispersion characteristics(e.g.,rain caps,horizontal stacks,fugitive releases, 12 or building downwashl3)in close proximity to ambient air at the site boundary • Sources of 3O2, PM10, CO, or Pb located in complex terrain(e.g., terrain above stack height in close proximity to the source) 41. • Sources located in areas with poor existing air quality • Modifications at existing major stationary sources,including grandfathered sources that have never been modeled before. None of the above mentioned thresholds will be exceeded with this modification. Therefore, further analysis is not needed. • Attachment F Facility Emission Inventory Enterprise Compressor Station e • . . , | • f \�• \ \ ' _ _ . i !•- , - » !ems , . . • _ . # ; 0 ......... , - - - I ; !|M.5$---- | . . . i ; • | ..,. , - . , \ / I . -,333 3 . . - 5 ! I .,,,,,!... , . . , 1 : Ja24�@t ! .� . . . I \ E 02225;\7 - , 1 t .==„232.3 i , . , , I | . eag . 2 2 53 .11 | a r ...�. _ 33 . } | | . , \ 2 . . .. :88 : , 2 . 3 2! | . - o::: 2 . . 3 |$ ;s - -- , . , , ! „ k� h�P �\ , - a ' ` f 11 if .; ;8888 ! - . . ! : 0 il ig b""55 1 - . . ! ; 2 k !!:!a . ■ • \ . ! 2 J /)`f"" ■ ' f ! . E---- a . . . _ - | 3.333.|,,, 1 - 1 . § ; , .----.l... ! . . . - ! . | . |.w | - - . 1 1 | I J' i 7 ---; 3 —®; i|... | . . . | IE \ ,a;�, --- ( r \f || 3222228:8: i . . , ! I j& � ! : a 2 48i /_`. , . :| | ..,.,.;., : 8 , . ,,,,,3222, I :32===22333 3 3 83 32233 § 1 , --:...., 1 , 8 , 3 !|| !| J i | F. i t |• | \;i;IHIII ! ` 7 I mi goyim I §\. k beq • Attachment G Process Description,Flow Diagram,and Plot Plan Enterprise Compressor Station • • • Enterprise Compressor Station Process Description The Enterprise Compressor Station classified as a natural gas compressor station as set forth under Standard Industrial Classification Code 4922. The plant uses four(4) gas-fired internal combustion engines to drive compressors to boost the inlet gas pressure from about 80 PSIG to about 1,050 PSIG to facilitate movement of the gas in the pipeline. The station also includes a triethylene glycol(TEG) dehydrator unit which contacts"lean"triethylene glycol with the inlet natural gas stream to remove moisture. The"rich"glycol mixture is regenerated in a still for reuse in the process. The still vent exhaust stream is sent to a flare where it is combusted. The TEG dehydration system operates with a flash tank. The flash tank emissions are routed back to the process. A condensate product is generated when the inlet gas is routed through the inlet scrubber.The condensate is transferred first to a 30,000 gallon pressurized storage tank,then to a stabilizer tank to remove any volatile material, and finally to four(4) 300 barrel atmospheric storage tanks.The atmospheric tanks are controlled by a combustor.A loading system is provided for moving the liquid condensate material from the tanks into a truck for transport offsite. The plant is located one(1)mile north of US Highway 76 on the Gutterson Road between the towns of Keenesburg and Roggen,Weld County, Colorado. • • • M a - t N F O ti 04 E. N {a. es IiI o g e U • is: „isit i • C , F a dQ n i P. G 4 L O CJ U v h r a te co in V1 —A— LA g `V/ et O I ► c 2 0 U i d a a a g t h b 2 a V • Q ENTERPRISE COMPRESSOR STATION 1, 1.74 PY`S h9 de {40 1910 1044877 __. _.1 • 4 1 fa; i l mpa .. - f 391 J. 57, 75 t r. .. 18 . 18---'18 I 17s 6 J___...... 1_ ...* '65 '67, �� ak _4==R; y e e • kiM . . .7 1:r 2. 2.5 Connote ine-m02 aosoft Cap.anNa its suppkere AlNgM . IOW raaYred.Mlp/Nawk mm S sdRcortrvNs 6Capydya 2001 by Geographic Doh TMnology,Inc.Al tights reserved.O2001 Ne 4gapon Tawndagias.NI rights reamed.laic date Includes information taken vMh pamhmon from Canadian wtl atine&O Km Majesty the Queen h Rigid al Canada , ... ,,,, . n!!!!rii!!!!!!?i- 1 !,. , -„ 1 1 11 1 i�t trjk a a S i �' ! �[��{ya r E �IF Ai 1, i , , ......m....., 51 tgg � B ' 41f11. Ai Li N _ Ib a 3 IaaiiYi J SLR L i- ;.Y el !Ito': 11! IE fit FFF � I ?t,1! Il '1F ! 1,,,,A t , .Xx ! I iii i'uuI • h:. G q+ CDOC pe Eni ! -I � y , IIN,T " was 6�i-.wko,I E jj ria o _ W N - , ! . � . a 1r ii i � 1. '� ° ' v q iqq^ Y d i!ciI � . i ' 7d AN , �.. _Ri k I . Ala: all gill 1 6---- � i mraL[6—� in - EEE I: i i I • III • Attachment H Operating and Maintenance Plans Enterprise Compressor Station This is a major source and the equipment being modified with this amendment have O&M requirements already stated in the current operating permit. These O&M requirements will still be applicable with the current changes. DCP would like to maintain the current O&M requirements in Operating Permit 95OPWE103. • • • Attachment I Regulatory Analysis Enterprise Compressor Station • • • ENTERPRISE COMPRESSOR STATION REGULATORY ANALYSIS 1.0 Federal 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 major sources with respect to Non-Attainment New Source Review(NNSR)if emissions of NO.or VOC are in excess of 100 tpy.This facility emits more than 100 tpy of both NO„and VOC and therefore, is a major source under NNSR. However,this modification will not result in an increase in NO„or VOC emissions of more than 40 tpy,therefore,this is a minor modification with respect to NNSR and will not trigger new source review. 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. This facility 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. 75 Fed.Reg. 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. In this case,the proposed project is not subject to PSD review for any criteria pollutant;therefore,GHG emissions from the project are not subject to PSD review.The emissions of CO2e from the facility(approximately 92,020 tpy),which is less than any Step 2 period GHG permitting threshold. 2.0 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 hazardous air pollutant(HAP),25 tpy of any group of HAPs in the aggregate,or 100 tpy of any criteria air pollutant. This facility is a major source for NO„,VOC,and HAPs and currently operates under Operating Permit 95OPWE103. • • Regulation No. 3,Part A,Section I.B.44.e specifies that beginning July 1,2011,GHG emissions shall be"subject to regulation"under Title V operating permit requirements if a new or modified stationary source will emit 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"). This facility,does not emit more than 100,000 tpy of CO2e,Tide V does not apply to the GHG emissions from the project. 3.0 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" No steam generating units with a design heat input capacity in excess of 10.0 MMBtu/hr are located at this facility; therefore,NSPS Subpart Dc does not apply. NSPS Subpart GG, Standards of Performance Stationary Gas Turbines(40 C.F.R. §§60.330 to 60.335) Subpart GG applies to each all stationary gas turbines with a heat input at peak load equal to or greater than 10 MMBTU/hr,based on the lower heating value of the fuel,and constructed, modified or reconstructed after October 3, 1977. Turbines subject to NSPS KKKK,are not subject to NSPS GG per §60.4305. This turbine will be subject to NSPS KICKK as explained below. 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 storage • • tanks at this facility are either pressurized or have a capacity less than 19,800 gallons;therefore, Subpart Kb does not apply. 40 CFR Part 60 Subpart KICK-Standards of Performance for Equipment Leaks of V0C 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 KICK 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]. This facility does not process natural gas and is therefore,not subject to Subpart KKK. 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 engines at this facility were - constructed prior to July 1,2007 and are therefore not subject to Subpart JJJJ. 40 CFR Part 60 Subpart KKKK-Standards of Performance for Stationary Combustion Turbines (40 C.F.R. §§60.4300 to 60.4420) Subpart KKKK applies to stationary combustion turbines with a heat input at peak load equal to or greater than 10 MMBTU/hr that commence construction,reconstruction,or modification after February 18,2005. The turbine that will be installed at Enterprise Compressor Station will be a new turbine with a peak load greater than 10 MMBTU/hr and will therefore be subject to Subpart KKKK. This will be a new turbine firing natural gas with a heat rate greater than 50 MMBTU/hr and less than 850 MMBTU/hr. Therefore, it will meet a NO.rate of 25 ppm at 15%O2. All of the required testing,recordkeeping and reporting will be completed as specified by Subpart K}CKK. • • 4.0 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]. This facility is a major source of HAPs. The TEG unit is the only source that is potentially subject to any control requirements.However, the TEG unit at this facility is exempt from all major source requirements as stated in §63.764(e)(1)since the criteria in paragraph §63.764(e)(1)(ii)are met,but DCP does maintain records as required in§63.774(d)(1). 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 777.7 applies to stationary reciprocating internal combustion engines(RICE) at major or area sources of HAP emissions. As a major source of HAP emissions, the engines at this facility are subject to Subpart ZZZZ and are currently maintaining compliance with all requirements. 5.0 State Regulations • Regulation 3, Part A, Section II Regulation 3,Part A, Section H describes when an Air Pollutant Emission Notice(APEN)must be filed for new,modified, and existing sources. Eight APENs are included in this application. All of the heaters are this facility are less than 5 MMBTU/br and are therefore MEN exempt per Reg 3,Part A, Section II.D.1.k.. Regulation 3, Part B Regulation 3,Part B describes the requirements for Construction Permits. DCP requests one facility-wide construction permit for the proposed changes requested in this application. Regulation 3, Part C Regulation 3,Part C describes the requirements for Title V Operating Permits. The facility is a major source and currently operates under Operating Permit Number 95OPWE103. The changes will be rolled into the operating permit with-in one year of construction permit issuance. Regulation 3, Part D Regulation 3,Part D sets forth PSD and NNSR requirements. The facility is not a PSD major source and this modification will not trigger NNSR as discussed above. 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 XII 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.I.a and XII.C.1.b; Section XII.C.1.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. Section XII.C.l.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 memorializM 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 X1I.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 natural gas dehydrator at this facility is controlled by greater than 90%. • Section XVI specifies emission control requirements applicable to portable and stationary RICE located in 8-Hour Ozone Control Area. The compressor engines are controlled with selective oxidation catalysts • • 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. • • Attachment J Construction Permit Application Completeness Checklist Enterprise Compressor Station • • . Form APCD-100 Colorado Department of Public Health and Environment Air Pollution Control Division ws. • Oil & Gas Industry Colorado D p rho of Public Construction Permit Application Completeness Checklist andEtvironment Ver.September 28,2009 Company Name: DCP Midstream, LP Source Name: Enterprise Compressor Station Date: October 2011 Yes No. Are you requesting a facility wide permit for multiple emissions points? // ❑ In order to have a complete application,the following attachments must be provided,unless stated otherwise. If application is incomplete,it will be returned to sender and filing fees will not be refunded. Attachment Application Element Applicant APCD A MEN Filing Fees ® ❑ B Air Pollutant Emission Notice(s)(APENs) & ® ❑ Application(s)for Construction Permit(s)—APCD Form Series 200 C Emissions Calculations and Supporting Documentation �/ ❑ D Company Contact Information- Form APCD-101 i 1 ❑ E Ambient Air Impact Analysis ® ❑ ❑ Check here if source emits only VOC(Attachment E not required) • F Facility Emissions Inventory—Form APCD-102 ® ❑ ❑ Check here if single emissions point source(Attachment F not required) G Process description, flow diagram and plot plan of emissions unit and/or ® ❑ facility ❑ Check here if single emissions point source(Attachment G not required) 13 Operating&Maintenance(O&M)Plan—APCD Form Series 300 ® ❑ ❑ Check here if true minor emissions source or application is for a general permit(Attachment H not required) I Regulatory Analysis ® ❑ ❑ Check here to request APCD to complete regulatory analysis (Attachment I not required) Colorado Oil and Gas Conservation Commission(COGCC) 805 Series Rule zi Requirements—Form APCD-105 ® Check here if source is not subject to COGCC 805 Series requirements (Attachment J not required) Send Complete Application to: Colorado Department of Public Health&Environment APCD-SS-B1 4300 Cherry Creek Drive South • Denver, Colorado 80246-1530 • Check box if facility is an existing Title V source: ® Send an additional application copy Check box if refined modeling analysis included: ❑ Send an additional application copy Page 1 of 1 09 CompleteChecklist-Va.9-28-2009.docx • Attachment K RACT Analysis Enterprise Compressor Station • • • Enterprise Compressor Station RACT All of the sources at the this compressor station will utilize RACT per Regulation Number 7 to minimize the NOx and VOC emissions since this facility is located in the non- attainment area. Please see a description of the controls below. TEG Dehydration Unit • Still vent overhead emissions controlled by BTEX condenser and the overhead stream from the condenser is routed to the flare to achieve approximately 98% destruction efficiency; • Flash gas emissions are recycled back to the inlet via the VRU to achieve 100% control efficiency Stabilized Condensate • Raw condensate that enters the facility is heated and stabilized where the flash vapors are captured and recycled back to the inlet gas stream. The stabilized condensate is stored in atmospheric tanks. The atmospheric tank vents are routed to an enclosed combustor for 95% control of V0C emissions. Compressor Engines • Compressor engines utilize NSCR/AFRC controls. Although not required by Regulation Number 7, DCP will also commit to the follow RACT • requirement for the equipment listed below: Fugitive Emissions from Equipment Leaks • Weekly Audio,Visual, and Olfactory Inspections(AVOs). • If a leak is found, it will be tagged and a first attempt to fix the leak will be made within 5 days from the time the leak was detected. • If the leak is unable to be fixed on the first attempt, a second attempt will be made within 15 days unless a facility shutdown is required to isolate the component to fix the leak. In that situation, the leak will be fixed during the next shutdown. • A soap test or equivalent will be used to ensure the leak is fixed. • Documentation of the weekly AVOs will be kept onsite. • • Appendix F Revised APEN and Check for P018 AIRS ID: 123/0277/070 • E. 9 O X °0 O t O a O ° E o c en ;111:14 6. .P. C C. w o se .1 p E u _ 0• ea. `0 — u - to a U .Ea. W Cowen en en p o 0p0 ❑ �LC o. 7 64 G e' C LC U d u E o00 ° % o oc N m a F ca. 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"g ( ct N O LLI C N IX M CU j L N (0 Q W _ -0 E C , r` . = M — z O L. >+ (n m J N V ('2 0 0 To s N U r ` J C Z d Q1 C N O d O (o E c c co cn 0 o 0 E 2 0 O o Z C o C Q `-' cn o I 112 ±C I a .a (4 J C - � 1;3' Z � ' '� O N � E C:1 C 0 E U u) < to °Q C U' E E E N a 0 a a w QO1 Q �n co 2 DCP Midstream,LP PAYEE NUMBER CHECK NUMBER 370 17th Street,Suite 2500 0000074502 00310925 Denver,Colorado 80202 APCustomerService@dcpmid mstream.co PAYEE NAME CHECK DATE 303 605 2219 COLORADO 11/15/11 all INVOICE NUMBER INVOICE DATE NET AMOUNT DESCRIPTION ENTERPRISEP018APEI'1111/10/11 152.90 return check for Enterpri • TOTAL PAID $152.90 PLEASE RETAIN FOR YOUR RECORDS DCP Midstream LP JPMorgan Chase Bank,NA so 937/213 Midstream, Syracuse,New York 370 17th Street,Suite 2500 Denver,Colorado 80202 APCustomerSerncogdcpnudstream.com PAYEE NO. CHECK DATE CHECK NO. 303.605.2219 0000074502 11/15/11 00310925 TO THE ORDER OF I�II�� 1�rr��II�� ]] 4�t/)t/t/t/00ON Y��1�.l 1De CHECK AMOUNT NOT NEGOTIABLE AFTER 120 DAYS *******$152.90 COLORADO DEPT OF PUBLIC HLTH &ENVRNMNT AIR POD CNTRL DIV APCD SSB1 4300 CHERRY CREEK DR SOUTH Denver,CO 80246-1530 in ea AUTHORIZED SIGNATURE One hundred fifty two and 90/100 Dollars 11'00310925'1' I:0 2 L3093791: G018951,960 Hello