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Home My WebLink About20142078.tiff STATE OF COLORADO John W.Hickenlooper,Governor Larry Wolk,MD,MSPH .cv'coto,� Executive Director and Chief Medical Officer 4140,Dedicated to protecting and improving the health and environment of the people of Colorado ,,, 4300 Cherry Creek Dr.S. Laboratory Services Division "fare Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health www.colorado.gov/cdphe and Environment Weld County-Clerk to the Board 1150O St POBox758 RECEIVED Greeley, CO 80632 July JUL 0 9 2014 3, 2014 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On July 9, 2014,the Air Pollution Control Division will publish a public notice for DCP Midstream LP— Libsack Compressor Station, in the 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 of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty(30) days from the date the public notice is published. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health& Environment APCD-SS-B 1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure rTU.bic ggait W9Lnm1PWC4+er t�m�NtlP�) 1 - 9 - aorti 7 9 aoi� 2 78 - 14 20 0 NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT DCP Midstream LP proposes a project at a compressor station located at Section 36, T6N, R65W, in Weld County. Modification to fugitive emissions at an existing compressor station. This project is subject to public notice because: permitted emissions exceed public notice threshold values in Regulation No.3, Part B, Section III.C.I.a(25 tpy in a non-attainment area and/or 50 tpy in an attainment area). The Division has made a preliminary determination of approval of the application. Comments concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission are solicited from any interested person. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Additional information regarding this action can be found at the Weld Clerk's office and on the Division's Website at: www.colorado.gov/cdphe/AirPublicNotices or by contacting Stephanie Chaousy of the Division at 303-692-2297. RELEASED TO: The Greeley Tribune on PUBLISHED: July 9,2014 July 3.2014 STATE OF COLORADO John W.Hickenlooper,Governor Larry Wolk, MD,MSPH .0S cohe Executive Director and Chief Medical Officer c < T Dedicated to protecting and improving the health and environment of the people of Colorado .Aitcrso,st9< 4300 Cherry Creek Dr.S. Laboratory Services Division * Denver,Colorado 80246-1530 8100 Lowry Blvd. X6'!6 Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health www.colorado.gov/cdphe and Environment Website Title: DCP Midstream LP—Libsack Compressor Station—Weld County Released To: The Greeley Tribune On: July 3, 2014 Published: July 9, 2014 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: DCP Midstream LP Facility: Libsack Compressor Station Compressor station Section 36,T6N,R65W Weld County The proposed project or activity is as follows: Modification to fugitive emissions at an existing compressor station. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3,Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3,Part B, Section I1l.C.1.a (25 tpy in a non-attainment area and/or 50 tpy in an attainment area) The Division has made a preliminary determination of approval of the application. A copy of the application,the Division's analysis,and a draft of Construction Permit 11 WE1475 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at www.colorado.gov/cdphe/AirPublicNotices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Stephanie Chaousy Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South,APCD-SS-B 1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us STATE OF COLORADO of coto COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION , 0 *, TELEPHONE: (303) 692-3150 . .' 1846 CONSTRUCTION PERMIT PERMIT NO: 11WE1475 WE1 475 Issuance 2 DATE ISSUED: ISSUED TO: DCP Midstream, LP THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural gas compression facility, known as the Libsack Compressor Station, located in Section 36, Township 6N, Range 65W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Description Equipment ID Point One (1)Waukesha, Model L7044GSI, Serial Number 5283701797, natural gas-fired, turbo-charged, 4SRB reciprocating internal combustion engine, site rated at 1680 C-185 001 horsepower at 1200 RPM. This engine shall be equipped with non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. One (1)Waukesha, Model L7044GSI, Serial Number 5283701843, natural gas-fired, turbo-charged, 4SRB reciprocating internal combustion engine, site rated at 1680 C-186 002 horsepower at 1200 RPM. This engine shall be equipped with non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. One (1)Waukesha, Model L7044GSI, Serial Number 5283701844, natural gas-fired, turbo-charged, 4SRB reciprocating internal combustion engine, site rated at 1680 C-187 003 horsepower at 1200 RPM. This engine shall be equipped with non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. AIRS ID: 123/9008 Page 1 of 23 NGEngine Version 2009-1 Co do C(♦paft e o PubD lic PollutionHealthand Control DivisionEnvironment Facility AIRS Description Equipment ID Point One (1)Waukesha, Model L7044GSI, Serial Number 5283701845, natural gas-fired, turbo-charged, 4SRB reciprocating internal combustion engine, site rated at 1680 C-188 004 horsepower at 1200 RPM. This engine shall be equipped with non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. One (1) Triethylene glycol (TEG) natural gas dehydration unit (QB Johnson, serial number: 639012A) with a design capacity of 50 MMscf per day. This emissions unit is equipped with one (1) electric pump (Best Pump Works) with D-1 005 a design capacity of 24 gallons per minute. This unit is equipped with a flash tank, reboiler and still vent. Emissions from the still vent are routed to a condenser and then to an enclosed combustor. Emissions from the flash tank are routed to a vapor recovery unit(VRU)which retums vapors back to the inlet of the compressor station. FUG 006 Equipment leaks (fugitive VOCs)from a natural gas compression facility. The engines addressed under AIRS Points 001 through 004 may be replaced with another engine in accordance with the temporary engine replacement provision or with another Waukesha L7044GSI engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. This construction permit represents final permit approval and authority to operate this emissions source. Therefore, it is not necessary to self-certify. (Regulation 3, Part B, Section III.G.5). EMISSION LIMITATIONS AND RECORDS 2. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility AIRS Tons per Year Emission Type VOC CO Equipment ID Point NO, C-185 001 8.1 11.4 16.2 Point C-186 002 8.1 11.4 16.2 Point AIRS ID: 123/9008 Page 2 of 23 Co do p e o Public D Air PollutionHealthand Control DivisionEnvironment C-187 003 8.1 11.4 16.2 Point C-188 004 8.1 11.4 16.2 Point D-1 005 -- 16.7 2.0 Point FUG 006 --- 53.7 --- Fugitive See "Notes to Permit Holder #4 for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the synthetic minor status of this facility shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly emissions and keep a compliance record on site, or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all emission units, requiring an APEN, at this facility. PROCESS LIMITATIONS AND RECORDS 3. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility Equipment AIRS Annual Process Parameter ID Point Limit C-185 001 Consumption of natural gas as a fuel 128.8 MMscf/yr C-186 002 Consumption of natural gas as a fuel 128.8 MMscf/yr C-187 003 Consumption of natural gas as a fuel 1288 MMscf/yr C-188 004 Consumption of natural gas as a fuel 128.8 MMscf/yr 18,250 D-1 005 Natural gas throughput MMscf/yr FUG 006 Not applicable Compliance with the yearly consumption limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly consumption of natural gas and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS AIRS ID: 123/9008 Page 3 of 23 D Co do p e o Pu and Airblic PollutionHealth Control DivisionEnvironment 4. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable). 5. Visible emissions shall not exceed twenty percent(20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.1. &4.) 6. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) Waukesha Engines (AIRS Points 001 through 0041 7. Each engine shall be equipped with non-selective catalytic reduction (NSCR) system and air-fuel ratio control. The control system shall reduce uncontrolled emissions of NOx, VOC and CO from each engine to the emission levels listed in Condition 2, above. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 8. This equipment is subject to the control requirements for stationary and portable engines in the 8-hour ozone control area under Regulation No. 7, Section XVI.B.1. For rich burn reciprocating internal combustion engines, a non-selective catalyst reduction system and an air fuel controller shall be required. 9. This equipment is subject to the control requirements for natural gas-fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas-fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state 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: Maximum Engine Construction or Emission Standard in g/hp-hr HP Relocation Date NOx CO VOC <100HP Any N/A N/A N/A . 2100HP and January 1, 2008 2.0 4.0 1.0 <500HP January 1, 2011 1.0 2.0 0.7 2500HP July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 Note: Per Regulation No. 7, Section XVII.B.4, internal combustion engines that are subject to an emissions control requirement in a federal maximum achievable control technology ("MACT") standard under 40 CFR Part 63, a Best Available Control Technology ("BACT") limit, or a New Source Performance Standard under 40 CFR Part 60 are not subject to this Section XVII. TEG Dehv (AIRS Point 005) AIRS ID: 123/9008 Page 4 of 23 DCo i do S p ' ' e o Public Health and Environment II Air Pollution Control Division 10. Compliance with the emission limits in this permit shall be demonstrated by running the GRI GlyCalc model version 4.0 or higher on a monthly basis using the most recent wet gas analysis and recorded operational values (including gas throughput, lean glycol recirculation rate, VRU downtime and other operational values specified in the O&M Plan). Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into GRI GlyCalc. 11. This unit shall be configured such that the flash tank vapors are routed to the VRU to be recycled to the compressor station inlet and still vent vapors are routed to an enclosed combustor. The control system shall reduce uncontrolled emissions of VOC from the TEG dehydration unit to the emission levels listed in Condition 2, above. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 12. 100% of emissions that result from the flash tank associated with this dehydrator shall be recycled to the compressor station inlet and recompressed. 13. This source shall be limited to a maximum lean glycol recirculation pump rate as calculated per 40 CFR, Part 63, Subpart HH, §63.764 (d)(2)(i). If the owner or operator requests an altemate circulation rate per §63.764(d)(2)(ii), then maximum recirculation rate shall not exceed 24.0 gallons per minute. The owner or operator shall maintain monthly records of the actual lean glycol recirculation rate and make them available to the Division for inspection upon request. 14. This equipment is subject to the control requirements for glycol natural gas dehydrators under Regulation No. 7, Section XII.H. Beginning May 1, 2005, uncontrolled actual emissions of volatile organic compounds from the still vent and vent from any gas- condensate-glycol (GCG) separator (flash separator or flash tank), if present, shall be reduced by at least 90 percent through the use of air pollution control equipment. This source shall comply with all applicable general provisions of Regulation 7, Section XII. 15. The enclosed flare covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed, have no visible emissions during normal operations, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XVII. 16. This equipment is subject to the control requirements for glycol natural gas dehydrators under Regulation No. 7, Section XVII.D (State only enforceable). Beginning May 1, 2008, uncontrolled actual emissions of volatile organic compounds from the still vent and vent from any gas-condensate-glycol (GCG) separator (flash separator or flash tank), if present, shall be reduced by an average of at least 90 percent through the use of air pollution control equipment. This source shall comply with all applicable general provisions of Regulation 7, Section XVII. 17. This source is subject to the TEG dehydrator area source requirements of 40 CFR, Part 63, Subpart HH - National Emission Standards for Hazardous Air Pollutants for Source AIRS ID: 123/9008 Page 5 of 23 Co do p e o Public Health and Environment D Air Pollution Control Division Categories from Oil and Natural Gas Production Facilities including, but not limited to, the following: • §63.760—Applicability and designation of affected source o §63.760 (f) -The owner or operator of an affected major source shall achieve compliance with the provisions of this subpart by the dates specified in paragraphs (f)(1) and (f)(2) of this section. The owner or operator of an affected area source shall achieve compliance with the provisions of this subpart by the dates specified in paragraphs (f)(3) through (f)(6) of this section. • §63.760 (f)(6) - The owner or operator of an affected area source that is not located in an Urban-1 county, as defined in §63.761, the construction or reconstruction of which commences on or after July 8, 2005, shall achieve compliance with the provisions of this subpart immediately upon initial startup or January 3, 2007, whichever date is later. • §63.764 - General Standards o §63.764 (d)(2) —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)(i) — Determine the optimum glycol circulation rate using the following equation: Lopr =1.15'3.0 gal TEG*(F*(I—O)1 y 1b1-1,O 24hr/day ) Where: LopT = Optimal circulation rate, gal/hr. F = Gas flowrate (MMSCF/D) I = Inlet water content (lb/MMSCF) O = Outlet water content (Ib/MMSCF) 3.0 = The industry accepted rule of thumb for a TEG-to water ratio (gal TEG/IbHZO) 1.15 =Adjustment factor included for a margin of safety. • §63.764 (d)(2)(ii) — 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 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)(iii) — Maintain a record of the determination specified in paragraph (d)(2)(ii) in accordance with the requirements in AIRS ID: 123/9008 Page 6 of 23 Co do p e o PubI) lic PollutionHealthand Control DivisionEnvironment §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). • §63.774 - Recordkeeping Requirements o §63.774 (b) - 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)(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)(i) — All applicable records shall be maintained in such a manner that they can be readily accessed. • §63.774 (b)(1)(ii) — 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)(iii) — The remaining 4 years of records may be retained offsite. • §63.774 (b)(1)(iv) — 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. o §63.774 (f) -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. • §63.775— Reporting Requirements o §63.775 (c) - Except as provided in paragraph (c)(8), each owner or operator of an area source subject to this subpart shall submit the information listed in paragraph (c)(1) of this section. If the source is located within a UA plus offset and UC boundary, the owner or operator shall also submit the information listed in paragraphs (c)(2) through (6) of this section. If the source is not located within any UA plus offset and UC boundaries, the owner or operator shall also submit the information listed within paragraph (c)(7). • §63.775 (c)(1) - The initial notifications required under §63.9(b)(2) not later than January 3, 2008. In addition to submitting your initial notification to the addressees specified under §63.9(a), you must also AIRS ID: 123/9008 Page 7 of 23 Co do p e o Public PollutionHealthand Control DivisionEnvironment submit a copy of the initial notification to EPA's Office of Air Quality Planning and Standards. Send your notification via e-mail to COG— ONG@EPA.GOV or via U.S. mail or other mail delivery service to U.S. EPA, Sector Policies and Programs Division/Coatings and Chemicals Group (E143-01), Attn: Oil and Gas Project Leader, Research Triangle Park, NC 27711. • §63.775 (c)(7) - The information listed in paragraphs (c)(1)(i) through (v) of this section. This information shall be submitted with the initial notification. • §63.775 (c)(7)(i) - Documentation of the source's location relative to the nearest UA plus offset and UC boundaries. This information shall include the latitude and longitude of the affected source; whether the source is located in an urban cluster with 10,000 people or more; the distance in miles to the nearest urbanized area boundary if the source is not located in an urban cluster with 10,000 people or more; and the names of the nearest urban cluster with 10,000 people or more and nearest urbanized area. • §63.775 (c)(7)(ii) - Calculation of the optimum glycol circulation rate determined in accordance with §63.764(d)(2)(i). • §63.775 (c)(7)(iii) - If applicable, documentation of the alternate glycol circulation rate calculated using GRI- GLYCaIcTM, Version 3.0 or higher and documentation stating why the TEG dehydration unit must operate using the alternate glycol circulation rate. • §63.775 (c)(7)(iv) - The name of the manufacturer and the model number of the glycol circulation pump(s) in operation. • §63.775 (c)(7)(v) - Statement by a responsible official, with that official's name, title, and signature, certifying that the facility will always operate the glycol dehydration unit using the optimum circulation rate determined in accordance with §63.764(d)(2)(i) or§63.764(d)(2)(ii), as applicable. o §63.775 (f) - Notification of process change. Whenever a process change is made, or a change in any of the information submitted in the Notification of Compliance Status Report, the owner or operator shall submit a report within 180 days after the process change is made or as a part of the next Periodic Report as required under paragraph (e) of this section, whichever is sooner. The report shall include: • §63.775(f)(1) -A brief description of the process change; • §63.775 (f)(2) - A description of any modification to standard procedures or quality assurance procedures • §63.775 (f)(3) — Revisions to any of the information reported in the original Notification of Compliance Status Report under paragraph (d) of this section; and AIRS ID: 123/9008 Page 8 of 23 Co ^do yp. ' e o Public Health and Environment Air Pollution Control Division • §63.775 (f)(4) - Information required by the Notification of Compliance Status Report under paragraph (d) of this section for changes involving the addition of processes or equipment. Fugitive Emissions (AIRS Point 006) 18. The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas analysis, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. 19. Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply Reasonably Available Control Technology for the pollutants for which the area is nonattainment or attainment/maintenance (Reference: Regulation No. 3, Part B, III.D.2.a). Compliance with the requirements of an inspection and repair program, as required by Condition 20, shall satisfy the requirement to apply RACT. 20. The operator shall use optical gas imaging (i.e. IR camera) to screen all pumps, valves, connectors, and pressure relief devices that contain or contact a process stream that is at least 10 percent VOC by weight. The operator shall perform screening on a semi- annual basis. The IR camera shall be maintained per the manufacturer's recommendations. In addition, the source shall follow procedures for implementing an alternative work practice for monitoring equipment for leaks as specified below: • Any emissions imaged by the optical gas instrument (i.e. IR camera) at the required detection sensitivity level qualify as a leak. Additionally, any indications of liquids dripping shall qualify as a leak. • The detection sensitivity level shall be 60 grams per hour which correlates to the least frequent monitoring schedule listed in Table 1 of 40 CFR 60 Subpart A. • The operator shall comply with the instrument specifications in 40 CFR 60.18(1)(1). • The operator shall comply with the daily instrument checks in 40 CFR 60.18(i)(2). • The operator shall perform screening in accordance with 40 CFR 60.18 (i)(3). • The operator shall tag all leaking components with date of leak detected, date of repair and date of rescreening to confirm repair. Once a leak is repaired, the leaker tag may be removed. • Component leaks detected shall be repaired as set forth below: o The leak will be repaired within 15 days. Repaired components shall be re- screened within five days of repair to determine if the leak is repaired. If the rescreening shows a leak, then the leak shall be repaired as soon as practicable, but no later than 15 days after the rescreening. Repeat the process until the rescreening shows no leak. o As an alternative to using the IR camera, re-screening may be performed in accordance with the Alternative Screening Procedure as specified in 40 CFR 60 Appendix 7, Method 21, Section 8.3.3. AIRS ID: 123/9008 Page 9 of 23 DCo do p e o Pu and ■1'�_ Airblic PollutionHealth Control DivisionEnvironment o If a leak is detected but it is technically infeasible to make the repair without a process unit shutdown, repair of this equipment shall occur before the end of the next process unit shutdown. Facility records shall be maintained documenting the rationale for placing a leaking component on the Delay of Repair list, identifying the repair methods applied in each attempt to repair the leak, identifying the leaking component ID number, and listing an estimated date for repairing the component. Monitoring to verify the repair must occur within 15 days after startup of the process unit. • The following records shall be maintained and kept onsite for two years and shall be made available to the Division upon request: o A video record must be used to document leak survey results. The video record must include a time and date stamp for each monitoring event. o A video record must be used to document leaks that are found and to confirm repairs showing the date/time of screening for each event. The video record must include a time and date stamp for each monitoring event. If the Alternative Screening Procedure per 40 CFR 60 Appendix 7, Method 21, Section 8.3.3 is used for re-screening, then records of re-screening dates, re-screening method, and re-screening results must be maintained in lieu of a video record. o List of components screened and associated dates. o List of currently leaking components. o List of repaired components along with the repair method and associated repair dates. o List of successful repairs, repair delays, and post-repair screenings and associated dates. o Records of daily instrument check including the distance and flow meter reading at which the leak was imaged. Keep a video record of the daily instrument check for each configuration of the optical gas imaging instrument used during the leak survey (for example,the daily instrument check must be conducted for each lens used). The video record must include a time and date stamp for each daily instrument check. The video record must be kept for two years. OPERATING & MAINTENANCE REQUIREMENTS 21. Upon startup of these points, the applicant shall follow the operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section Ill.G.7.) COMPLIANCE TESTING AND SAMPLING Periodic Testing Requirements 22. AIRS Points 001 through 004: Each engine is subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. AIRS ID: 123/9008 Page 10 of 23 ili&' Co A do pp e o Public Health and Environment Ill Air Pollution Control Division Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. 23. AIRS Point 005: The owner or operator shall complete an extended wet gas analysis prior to the inlet of the TEG dehydrator on an annual basis. Results of the wet gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per this permit. 24. AIRS Point 006: On an annual basis, the permittee shall complete an extended gas analysis of gas samples that are representative of VOC and HAP that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. ADDITIONAL REQUIREMENTS 25. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5)tons per year or more, above the level reported on the last APEN; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the permittee is exercising an alternative-operating scenario and is installing a permanent replacement engine. 26. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). 27. MACT Subpart HH - National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities major stationary source requirements shall apply to this source at any such time that this source becomes major solely by virtue of a AIRS ID: 123/9008 Page 11 of 23 Co do p e o Puble D Airic PoHealthllution ControlandEnviroc)ivisionnmnt relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of Subpart HH. (Reference: Regulation No. 8, Part E) 28. MACT Subpart 7777 - National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of that Subpart on the date as stated in the rule as published in the Federal Register. (Reference: Regulation No. 8, Part E) GENERAL TERMS AND CONDITIONS: 29. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 30. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide 'final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 31. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicants agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 32. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 33. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 34. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the AIRS ID: 123/9008 Page 12 of 23 Co A do t °p e o Public Health and Environment Air Pollution Control Division Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 35. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Stephanie Chaousy, PE Permit Engineer Permit History Issuance Date Description Issuance 1 November 21, Issued to DCP Midstream, LP 2011 Issuance 2 This Issuance Issued to DCP Midstream, LP. Increase in VOC emission limit for Point 006. Change the control device for Point 005 to an enclosed combustor. Issued permit as final. Source at a synthetic minor facility. AIRS ID: 123/9008 Page 13 of 23 Co do e o PubD lic PollutionHealthand Control DivisionEnvironment Notes to Permit Holder: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The permittee shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: http://www.cdohe.state.co.us/requlations/,airegs/100102aacccommonprovisionsreq.pdf. 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS# BIN (Ib/yr) reportable? Rate (Ib/yr) Formaldehyde 50000 A 1622 Yes 389 Methanol 67561 C 355 Yes 177 Acetaldehyde 75070 A 323 Yes 162 001 Acrolein 107028 A 305 Yes 152 Benzene 71432 A 183 No 92 1,3-Butadiene 106990 A 77 No 38 Toluene 108883 C 65 No 32 Formaldehyde 50000 A 1622 Yes 389 Methanol 67561 C 355 Yes 177 Acetaldehyde 75070 A 323 Yes 162 002 Acrolein 107028 A 305 Yes 152 Benzene 71432 A 183 No 92 1,3-Butadiene 106990 A 77 No 38 Toluene 108883 C 65 No 32 Formaldehyde 50000 A 1622 Yes 389 003 Methanol 67561 C 355 Yes 177 Acetaldehyde 75070 A 323 Yes 162 AIRS ID: 123/9008 Page 14 of 23 $°' Co Ak do 0 p . e o Public Health and Environment ll Air Pollution Control Division Acrolein 107028 A 305 Yes 152 Benzene 71432 A 183 No 92 1,3-Butadiene 106990 A 77 No 38 Toluene 108883 C 65 No 32 Formaldehyde 50000 A 1622 Yes 389 Methanol 67561 C 355 Yes 177 Acetaldehyde 75070 A 323 Yes 162 004 Acrolein 107028 A 305 Yes 152 Benzene 71432 A 183 No 92 1,3-Butadiene 106990 A 77 No 38 Toluene 108883 C 65 No 32 Benzene 71432 A 114,889 YES 6,108 Toluene 108883 C 141,530 YES 7,605 005 Ethylbenzene 100414 C 6,136 YES 332 Xylenes 1330207 C 70,959 YES 3,863 n-Hexane 110543 C 63,874 YES 1,908 006 n-Hexane 110543 C 2,172 YES NA 5) The emission levels contained in this permit are based on the following emission factors: Points 001 through 004: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.6669 13.1000 0.1400 0.5000 CO 3.2750 11.7000 0.2799 1.0000 VOC 0.4199 1.5000 0.1959 0.7000 50000 Formaldehyde 0.0140 0.0500 0.0034 0.0120 67561 Methanol 0.0031 0.0109 0.0015 0.0055 75070 Acetaldehyde 0.0028 0.0100 0.0014 0.0050 107028 Acrolein 0.0026 0.0094 0.0013 0.0047 71432 Benzene 0.0016 0.0056 0.0008 0.0028 106990 1,3-Butadiene 0.0007 0.0024 0.0003 0.0012 108883 Toluene 0.0006 0.0020 0.0003 0.0010 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 7876 Btu/hp-hr, a site-rated horsepower value of 1680, and a fuel heat value of 900 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer's specifications Manufacturer's specifications CO Manufacturer's specifications Manufacturer's specifications VOC Manufacturer's specifications Manufacturer's specifications 50000 Formaldehyde Manufacturer's specifications Manufacturer's specifications AIRS ID: 123/9008 Page 15 of 23 D Co do p e o Public Health and Environment Air Pollution Control Division CAS Pollutant Uncontrolled EFSource Controlled EF Source 67561 Methanol AP-42; Table 3.2-3 (7/2000); Manufacturer's specifications Natural Gas 75070 Acetaldehyde AP-42; Table 3.2-3 (7/2000); Manufacturer's specifications Natural Gas 107028 Acrolein AP-42; Table 3.2-3 (7/2000); Manufacturer's specifications Natural Gas 71432 Benzene AP-42; Table 3.2-3(7/2000); Manufacturer's specifications Natural Gas 106990 1,3-Butadiene AP-42; Table 3.2-3 (7/2000); Manufacturer's specifications Natural Gas 108883 Toluene AP-42; Table 3.2-3 (7/2000); Manufacturer's specifications Natural Gas Point 005: The emission levels contained in this permit are based on information provided in the application and the GRI GlyCalc 4.0 model. Controlled emissions are based on 100% recycle of the flash tank emissions and 95% control of the still vent vapors. Optimal recirculation rate per MACT HH (63.74(d)(2)(i)) is based on the following information submitted with the application: F = 50MMscfd; I = 121.8 lb/MMscf; and O=6.7 lb/MMscf. Point 006: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 1689 0 1895 0 Flanges 321 0 802 0 Open-ended Lines 0 0 0 0 Pump Seals 0 0 10 0 Valves 389 0 970 0 Other* 24 0 34 0 VOC Content(wt%) 27.87% — 100% -- Benzene Content — __ (wt%) Toluene Content __ • ___ ___ —_ (wt%) Ethylbenzene(wt%) -- -- --- -- Xylenes Content (wt%) — — n-hexane Content 1.404% - 1.404% - ( %) *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors(kg/hr-component): Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 AIRS ID: 123/9008 Page 16 of 23 i ` Co Ado • p- e o Public Health and Environment U. Air Pollution Control Division Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 Note that the emission limits included in this permit are derived by multiplying the equipment counts in the table above by a factor of 1.4 to accommodate other minor changes to the facility and to provide a conservative estimate of facility-wide emissions. Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas analysis. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) The following equipment is currently exempt from construction permitting requirements and/or APEN reporting requirements based on information provided by the operator for the Division's analysis: AIRS ID Facility ID Description Notes NA TEG TEG Dehy unit reboiler, This unit is exempt from APEN reporting Reboiler rated at 2.86 MMBtu/hr requirements because the design rate is less than 5 MMBtu/hr (Regulation No. 3, Part A, II.D.1.k), and is therefore also exempt from construction permitting requirements (Regulation no. 3, Part B, II.D.1.a). Criteria pollutant emission levels for this unit are based on factors from AP-42, Chapter 1.4, Small Boilers < 100 MMBtu/hr (7/1998). 8) AIRS Points 001 through 004: Each engine is subject to 40 CFR, Part 60, Subpart JJJJ— Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting — effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: htto://www.epa.qov/ttn/atw/area/fr18ia08.pdf 9) AIRS Points 001 through 004: Each engine is subject to 40 CFR, Part 63, Subpart ZZZZ- National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.qov/tt0/atw/area/fr18ia08.pdf Additional information regarding area source standards can be found on the EPA website at: htto://www.epa.qov/ttn/atw/area/arearules.html 10) This facility is classified as follows: Applicable Status Requirement AIRS ID: 123/9008 Page 17 of 23 Co do p e o Public PollutionHealthand Control DivisionEnvironment Operating Permit Synthetic Minor Source CO, VOC, NOx, HAPs PSD Synthetic Minor Source CO NANSR Synthetic Minor Source VOC, NOx MACT HH Area Source Requirements MACT ZZZZ Area Source Requirements 11) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DOD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXXXXX AIRS ID: 123/9008 Page 18 of 23 $ Co Ak do P p e o Public Health and Environment Air Pollution Control Division ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES December 10, 2008 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. A.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90-day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit(including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five(5) years and made available to the Division upon request. The permittee shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the permittee shall maintain a copy of all Applicability Reports required under section A.1.2 and make them available to the Division upon request. A.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 emissions from the temporary replacement engine comply with the emission limitations for the existing permitted engine as determined in section A.2. Measurement of emissions from the temporary replacement engine shall be made as set forth in section A.2. A.1.2 The permittee may permanently replace the existing compressor engine with an engine that is of the same manufacturer, model and horsepower without modifying this permit so long as the emissions from the permanent replacement engine comply with 1) the permitted annual emission limitations for the existing engine, 2) any permitted short-term emission limitations for the existing permitted engine, and 3) AIRS ID: 123/9008 Page 19 of 23 Co do p e o Public PollutionHealthand Control DivisionEnvironment the applicable emission limitations as set forth in the Applicability Report submitted to the Division with the Air Pollutant Emissions Notice(APEN)for the replacement engine(see htto://www.cdohe.state.co.us/ap/oilgaspermittina.html for example applicability report formats). Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section A.2. An Air Pollutant Emissions Notice(APEN)that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the 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 at http://www.cdphe.state.co.us/ap/oilaaspermittina.html. This submittal shall be accompanied by a certification from a person legally authorized to act on behalf of the source indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The permittee shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. A.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The permittee may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The permittee shall measure nitrogen oxide(NOX) and carbon monoxide(CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7)calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer)as found on the Division's website at: http://www.cdphe.state.co.us/ap/down/portanalyzeproto.pdf Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year)or short term (lbs/unit of time)emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760),whichever applies. For comparison with a short-term limit that is either input based (Ib/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15%O2)that the existing unit is currently subject to or the replacement AIRS ID: 123/9008 Page 20 of 23 Co/i do B j pr e o Public Health and Environment i Air Pollution Control Division 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. A.3 Applicable Regulations for Permanent Engine Replacements A.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural-gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ 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. A.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State-Only conditions). Control Requirements. Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. AIRS ID: 123/9008 Page 21 of 23 D . Co do p e o Public Health and Environment Air Pollution Control Division The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition A.1.2. Emission Standards: Section XVII.E—State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, • after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 500<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 A.1.2 A.3.3 NSPS for spark ignition internal combustion engines: 40 CFR 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject 40 CFR 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 A.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 A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.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 November 1, 2008 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, §LB(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. A.3.4 Reciprocating internal combustion engine(RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A.3.4.1 Area Source for HAPs AIRS ID: 123/9008 Page 22 of 23 DCo do C>lp e o Public PollutionHealthand Control DivisionEnvironment A permanent replacement engine located at an area source that commenced construction or reconstruction after June 12, 2006 as defined in §63.2, will meet the requirements of 40 CFR Part 63, Subpart ZZZZ by meeting the requirements of 40 CFR Part 60, Subpart JJJJ. 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 A.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 A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2. A.3.4.2 Major source for HAPs A permanent replacement engine that is located at major source is subject to the requirements in 40 CFR Part 63 Subpart ZZZZ as follows: Existing, new or reconstructed spark ignition 4 stroke rich burn engines with a site rating of more than 500 hp are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 12/19/02)2 stroke and 4 stroke lean burn engines with a site rating of more than 500 hp are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 6/12/06)4 stroke lean burn engines with a site rating of greater than or equal to 250 but less or equal to 500 hp and were manufactured on or after 1/1/08 are subject to the requirements in 40 CFR Part 63 Subpart ZZZZ. New or reconstructed (construction or reconstruction commenced after 6/12/06) 2 stroke lean burn or 4 stroke rich burn engines with a site rating of 500 hp or less will meet the requirements of 40 CFR 63, Subpart ZZZZ by meeting the requirements of 40 CFR 60, Subpart JJJJ. New or reconstructed (construction or reconstruction commenced after 6/12/06)4 stroke lean burn engines with a site rating of less than 250 hp will meet the requirements of 40 CFR 63, Subpart ZZZZ by meeting the requirements of 40 CFR 60, Subpart JJJJ. 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 A.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 A.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition A.2. A.3.5 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not"routine replacement"of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/9008 Page 23 of 23 01A d _ 2 ›•-.9 m•W°,.O W N -01 01 0 0 p0 0 0 0 0 0 0 000<q‘- CO - 0 Q d p o N m M O o N 0 O N O O 3;i;;0 O O O O O O O O O 0 h «N O W, U 2 rn 5,`°0 en°010 �Cl q°'oo .'0000000000m im r mo° a o a Q 0 y m N 0 0 m°i o 0 0 0 0 0 0 0 0 0 0 0 0 r_ C « N J 4 05.00d000000oo00'' 000000000000 ee tadddddddddddd6666 dd dd0000000 00 o- 2 U 0 x - C..O o o O o o o,0 0 0 0 0 oa o o o o o o o o o o O O00 °a d O d O d o o 0 0 0 o O O d o 6 o d d d d d d o o C d J u O 5.0 o o o o o o o o o o o o O o o o o o o o 0 o 0 C C d O O O O O O O O O O O O O O O O O O O O O O O O O O d 0 ° 0 U a a o S. _ w 00000000 {00000000000 w ! 0000000000000 oddoddddddo0, 05.00000000000000000dd000000 Qo -addddodoodddd64+6dd666666600 dd 0 o c0' = 0 y 0 a O = co E °rod000dddd0000 -.00000000000 o oa0000dddd66666zddddo6666666 ad w 0 v 9 w iin> LL N 'oE 05,0000000000000000000000000 oc °oo za 0000d00od0000 :i00 dd0dd0oo00 0d a o- I U d Ux c° I "ac v 02w ° oa000a0000000 ,,0000000000eo 0o O00000 Ea . add ddd d d d 6666 d `;d d d0d d o 00600 0o 6,66660 =a 0 8 a 3 0 m <` 4 0o = E t o rOomno Q,m mm00 o0o000o00o? 00000 `o c .E Pdo 0000N oioiddde' 666666ddo oA AO0,66,6 o E o ° y U O U Om - a c > 0 a .Q a or-00,001w00E;`..000o00Q000m ^ -00000' a N o m m�n o e m m 0 0,. 0 0 0 0 0 r o O Q o o o o o N.-N 0 0 0 0';.0 0 o O O o 0 0 o O n el TO 0h 5- O o c .. m O I CO 0 C 0 J. 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X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? Yes X No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no"to any of the above, when did you mail an Gas analysis was not included in Information Request letter to the source? the application modification. On what date was this application complete? May 30, 2014 Section 4—Source Description AIRS Point Equipment Description One (1)Triethylene glycol (TEG) natural gas dehydration unit(make, model, serial number: not submitted)with a design capacity of 50 MMscf per day. This emissions unit is equipped with one (1) electric pump (make, model: not submitted)with a design 005 capacity of 24 gallons per minute. This unit is equipped with a flash tank, reboiler and still vent. Emissions from the still vent are routed to a condenser and then to an enclosed combustor. Emissions from the flash tank are routed to a vapor recovery unit(VRU) which returns vapors back to the inlet of the compressor station. Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria X Yes No pollutant? If"yes", for what pollutant? PM10 CO X Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If'yes", for what pollutant? (Note: These pollutants are subject to minor source PM10 CO Ozone RACT per Regulation 3, Part B, Section III.D.2) Page 1 Is this source located in the 8-hour ozone non- attainment region?(Note: If"yes"the provisions of X Yes No Regulation 7, Sections XII and XVII.C may apply) Section 5-Emission Estimate Information AIRS Point Emission Factor Source 005 GRI Gly-Calc v4.0(Refer to Section 14 for calculations) Did the applicant provide actual process data for the emission inventory? Yes X No Basis for Potential to Emit(PTE) AIRS Point Process Consumption/Throughput/Production 005 18,250 MMSCF per year, 24 gallons per minute glycol circulation rate Basis for Actual Emissions Reported During this APEN Filing(Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year 005 18,250 MMSCF per year, 24 gallons per minute glycol circulation rate Basis for Permitted Emissions(Permit Limits) AIRS Point Process Consumption/Throughput/Production 005 18,250 MMSCF per year, 24 gallons per minute glycol circulation rate Does this source use a control device? X Yes No AIRS Point Process Control Device Description "k Reduction Granted 005 01 Still vent: Combustor and condenser 95 005 02 Flash tank: VRU 100 Section 6—Emission Summar/ (tons per year) Point NO, VOC CO Single HAP Total HAP PTE: 005 0.4 534.3 2.0 70.8 (Toluene) 198.7 Uncontrolled point 005 0.4 534.3 2.0 70.8 (Toluene) 198.7 source emission rate: Controlled point 005 0.4 16.7 2.0 3.8 (Toluene) 9.9 source emission rate: Section 7—Non-Criteria/Hazardous Air Pollutants Uncontrolled nn nro Controlled Emission Pollutant CAS# BIN Emission Rate reportable? roll pEmi 0bNr) r) Benzene 71432 A 114,889 Yes 6,108 Toluene 108883 C 141,530 Yes 7,605 Ethylbenzene 100414 C 6,136 Yes 332 Xylenes 1330207 C 70,959 Yes 3,863 n-Hexane 110543 C 63,874 Yes 1,908 Note: Regulation 3, Part A, Section ll.B.3.b APEN emission reporting requirements for non-criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory Yes X No standard? Page 2 If'yes", complete the information listed below Section 9—Source Classification Is this a new previously un-permitted source? Yes X No What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what programs? X Title V PSD X NA NSR X MACT Is this a modification to an existing permit? X Yes No If"yes"what kind of modification? X Minor Synthetic Major Minor Section 10—Public Comment Does this permit require public comment per CAQCC Regulation 3? Yes X No If"yes", for which pollutants?Why? For Reg. 3, Part B, III.C.1.a(emissions increase > 25/50 tpy)? Yes X No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? Yes X No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? Yes X No Section 11 —Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards (NAAQS)? If"yes", for which pollutants?Why? AIRS Point Section 12— Regulatory Review Regulation 1 - Particulate, Smoke, Carbon Monoxide and Sulfur Dioxide Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which 005 is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A(July, 1992)) in all subsections of Section II. A and B of this regulation. Regulation 2—Odor Section LA- No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are 005 measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 3-APENs, Construction Permits Operating Permits, PSD Part A-APEN Requirements 005 Applicant is required to file an APEN since emissions exceed 1 ton per year VOC in an attainment area for ozone. Part B—Construction Permit Exemptions 005 Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 20 TPY threshold(Reg. 3, Part B, Section It.D.2.a) Regulation 6- New Source Performance Standards 005 None Page 3 Regulation 7—Volatile Organic Compounds Is this source subject to the control requirements of MACT HH? (Regulation 8-Hazardous Air Pollutants review). No 005 Is this source subject to the exemptions under MACT HH (i.e. throughput exemption less than 3 MMSCFD or benzene exemption of less than 1984 Ib/yr)? No This source is subject to review for the Regulation 7 control requirements. Section XII.H: 005 Is this source located in the non-attainment area? No This source is not subject to this regulation. Section XVII.D(State only enforceable). 005 Applicant is required to reduce VOC emissions from this dehydrator by at least 90% since uncontrolled VOC emissions are greater than the 15.0 TPY threshold. Regulation 6-Hazardous Air Pollutants MACT HH: If facility is MAJOR source for HAP(summation of HAPS of dehydrators and fugitives greater than 25 TPY total or 10 TPY single HAP), then all glycol dehydrators at this facility are subject to MACT HH. If facility is an area source of HAP, only TEG dehydrators are subject to MACT HH. 1.Is facility a production field facility per 63.761 (Refer to Section 14 for definition)?Yes 2.If facility is defined as a production facility, then is it a major source of HAPS when 005 summing up dehydrator and flash tank emissions? No 3.Is this facility considered MAJOR for HAPS? No 4.Is this source subject to MACT HH?Yes 5.WHY? This facility is an area source of HAP and MACT HH area source requirements apply to this TEG dehydrator. This dehydrator is not located within an urban cluster or within two miles of an urban area, and is subject to the optimal circulation rate work practice standard in HH. Section 13—Aerometric Information Retrieval System Coding Information Point Process Description Throughput Emission Pollutant/ Fugitive Emission Control Description limit Factor CAS# (Y/N) Factor Source (%) 58.5489 V0C No GlyCalc 4.0 95 Ibs/mmscf 6.2953 Benzene/ No GlyCalc 40 95 Ibs/mmscf 71432 7.7551 Toluene/ 18,25O No GlyCalc 4.O 95 01 Glycol MMSCFper Ibs/mmscf 108883 005 Dehydrator year 0.3362 Ethylbenzene No GlyCalc 4.0 95 Ibs/mmscf /100414 3.8881 Xylenes/ No GlyCalc 4.0 95 lbs/mmscf 1330207 3.4999 n-Hexane/ No GlyCalc 40 95 Ibs/mmscf 110543 SCC 31000227: Glycol Dehydrator: reboiler still stack Page 4 Section 14—Miscellaneous Application Notes AIRS Point 005 Glycol Dehydrator Operator is requesting a permit modification. They are requesting to change how the still vent is controlled. Instead of routing the still vent stream to the reboiler, they want to have it routed to an enclosed combustor. This will therefore meet the newly proposed Regulation 7, Section XVII.B.2 requirements. This modification changed the NOX and CO slightly but did not affect the VOC and HAP emissions. In order to determine emissions, the operator used GRI GIyCALC 4.0. The source assumed the inlet gas temperature of 125°F and pressure of 920 psig. The permitted glycol recirculation rate is 24 gallons per minute. The GlyCalc model was based off of the extended gas analysis used with the first application. I believe the operator wanted to submit the original application showing how the change in control device would not affect the emissions. An extended gas analysis was provided when the operator submitted self- certification documents. D. Ryder approved the self-certification for this facility on 4/22/14. I am not goig to request a new gas analysis. Gly-Calc-Uncontrolled Emission factors VOC = ((304.2091+230.0492)*2000)/(50*365) = 58.5489 lb/mmscf(matches APEN) Benzene = ((55.5245+1.9201)*2000)/(50*365) = 6.2953 lb/mmscf(matches APEN) Toluene= ((69.1354+1.6296)*2000)/(50*365) = 7.7551 lb/mmscf(matches APEN) Ethylbenzene= ((3.0247+0.0435)*2000)/(50*365) = 0.3362 lb/mmscf(matches APEN) Xylenes= ((35.1183+0.3608)*2000)/(50*365) = 3.8881 lb/mmscf(matches APEN) N-hexane= ((17.3406+14.5961)*2000)/(50*365) = 3.4999 lb/mmscf(matches APEN) MACT HH includes requirements for both major and area sources of HAPs. The definition of major source for MACT HH (63.761) states: (3) For facilities that are production field facilities, only HAP emissions from glycol dehydration units and storage vessels with the potential for flash emissions shall be aggregated for a major source determination. For facilities that are not production field facilities, HAP emissions from all HAP emission units shall be aggregated for a major source determination. The following definitions from 63.761 are also needed to determine major source applicability: Production field facilities means those facilities located prior to the point of custody transfer Custody transfer means the transfer of hydrocarbon liquids or natural gas: after processing and/or treatment in the producing operations, or from storage vessels or automatic transfer facilities or other such equipment, including product loading racks, to pipelines or any other forms of transportation. For the purposes of this subpart, the point at which such liquids or natural gas enters a natural gas processing plant is a point of custody transfer. Natural gas processing plant(gas plant) means any processing site engaged in the extraction of natural gas liquids from field gas, or the fractionation of mixed NGL to natural gas products, or a combination of both. Based on the definitions above, this source qualifies as a production field facility. Does this dehydrator have a reboiler?Yes If Yes, what is the reboiler rated? 2.86 mmbtu/hr The source has a design rate less than 5 mmbtu/hr, it is APEN-exempt(Regulation No. 3, Pad A, ILD.1.k), and is therefore also exempt from construction permitting requirements (Regulation no. 3, Part B, II.D.1.a). Criteria pollutant emission levels for this unit are based on factors from AP-42, Chapter 1.4, Small Boilers < 100 MMBtu/hr(7/1998). Page 5 O s t Y N O ) zz o _� s ° E ° ❑ U U] 0 G •I-. 0 . Ni.. M M en F .: 0 G ., w. 0o > r /` .. co� CO °J ° ❑. W ❑ `o W U d " �` c •�/,.;' o o o o o gi A W 0 0 '' T "v 0 = c . 0 v m rJ- O°. 0 o C a P o ia a a n ❑ ' a ° CC o r 0 pup " 0.. c y y. 0/• ` o h o E W W .n C `A. io az N NPc it, .c ppw.�, ❑ 0. 4 N C o u u y ae _+ a u .'4u' G d C m 6 �' r C d r u .c .. 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