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Home My WebLink About20192040.tiffdo P Midstream. December 27, 2016 DCP Midstream 370 17th St., Suite 2500 Denver, CO 80202 (303) 605-2039 www.dcpmidstream.com UPS Tracking No. 1ZF469150299879366 Blue Parish Colorado Department of Public Health and Environment APCD-SS-B 1 Air Pollution Control Division 4300 Cherry Creek Drive South Denver, CO 80246-1530 Re: Marla Compressor Station Operating Permit 95OPWE020 Title V Renewal Application AIRS ID 123/0243 Dear Sir or Madam: DCP Midstream, LP (DCP) is submitting the attached operating permit renewal application for the Marla Compressor Station, located south of Kersey, CO at Section 28, Township 4N, Range 64W in Weld County, Colorado. This renewal application incorporates minor changes that have occurred at the facility since the last issuance of Operating Permit 95OPWE020 on January 1, 2013. These changes are listed below. In general, application forms have only been included where there are changes from the operating permit issued in 2013. Requested Changes — Permitted Sources DCP requests that all terms and conditions of current Operating Permit 95OPWE020 be incorporated into this renewal, apart from the following minor updates: • C-148: Waukesha L-7042 GSI Compressor Engine: engine included in 2013 operating permit was replaced under alternate operating scenario (AOS) provisions; updated serial number • C-166: Waukesha L-7044 GSI Compressor Engine: engine included in 2013 operating permit was replaced under AOS provisions; updated serial number • C-174: Waukesha L-7044 GSI Compressor Engine: engine included in 2013 operating permit was replaced under AOS provisions; updated serial number • C-176: Waukesha L-7044 GSI Compressor Engine: engine included in 2013 operating permit was replaced under AOS provisions; updated serial number Updated Title V Operating Forms 200 and 302 have been included for each of these engines, reflecting the updated serial numbers. Please see Attachment A. Pub\c. 9 Q,k ?JJi Col3l q 2019-2040 Requested Changes — Insignificant Activities • The fugitive emissions (P-106) included in the 2013 issuance of 95OPWE020 have been removed as a significant emission point and the APEN for this point cancelled. DCP has implemented the new Colorado Regulation Number 7 fugitives monitoring program and revised emissions based on updated emission factors show fugitive emissions less than the APEN threshold of 1 tpy VOC and are considered insignificant activities under the operating permit. The fugitive emissions have been added to the list of insignificant activities for this facility; please see Attachment D. Please remove all conditions relating to the fugitive emissions P-106 from the operating permit. Potential facility wide criteria and non -criteria emissions have decreased due to the decrease in emissions from this AIRS point. Please see the updated Title V Operating Forms 602 and 603, included in Attachment A. • Various updates to the insignificant activity list have been reflected in this renewal application. Attachments Attached please fmd forms and attachments needed to renew and to make the requested changes to operating permit 95OPWE020, as well as the required certifications signed by the Responsible Official, William L. Johnson, Vice President of Operations. The following attachments are included in this renewal application: • Attachment A: Updated Title V Operating Permit Forms • Attachment B: Copies of most recent APENs for all equipment • Attachment C: Updated Facility Wide Emissions Form (APCD-102) • Attachment D: Updated Facility Plot Plan • Attachment E: List of Insignificant Activities The current Operating Permit 95OPWE020 was originally issued by the Colorado Depaitinent of Public Health and Environment (CDPHE), Air Pollution Control Division on June 1, 1999 and most recently renewed on January 1, 2013. This renewal application is being submitted to fulfill the 5 -year renewal requirements under Regulation 3 Part C, as well as to incorporate the changes listed above. If you have any questions or require any additional information about this submittal, please contact me at (303) 605-2039 or RShankaran@dcpmidstream.com. Sincerely, DCP Midstream, LP Roshini Shankaran Environmental Engineer Attachments Attachment A Title V Operating Permit Renewal Forms Marla Compressor Station Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division FACILITY IDENTIFICATION SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-100 Rev 06-95 1. Facility name and mailing address Name Marla Compressor Station Street or Route City, State, Zip Code 370 17th Street, Suite 2500 Denver, Colorado 80202 2. Facility location (No P.O. Box) Street Address City, County, Zip Code SESE, Section 28, T4N, R64W South of Kersey (Kersey, Weld County, CO 80644) 3. Parent corporation Name Street or Route City, State, Zip Code Country (if not U.S.) DCP Midstream, LP 370 17th Street, Suite 2500 Denver, Colorado 80202 4. Responsible official Name Title Telephone William L. Johnson Vice President of Operations 303-605-1752 5. Permit contact person (If Different than 4) Name Title Telephone Roshini Shankaran Environmental Engineer 303-605-2039 6. Facility SIC code: 4922 7. Facility identification code: CO 123-0243 8. Federal Tax I. D. Number: 841041166 9. Primary activity of the operating establishment: Natural Gas Liquids Processing and Compression 10. Type of operating permit ❑ New ❑ Modified X Renewal 11. Is the facility located in a "nonattainment" area: X Yes 0 No If "Yes", check the designated "non -attainment" pollutant(s): 0 Carbon Monoxide x Ozone 0 PM10 0 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. 95OPWE020, Title V Operating Permit, Issued: June 1, 1999 Renewed: January 1, 2013 01WE0499, Construction Permit for Engine C-148 (P-102), Issued: September 25, 2001 01WE0500, Construction Permit for Engine C-135 (P-103), Issued: September 25, 2001 01WE0501, Construction Permit for Engine C-151 (P-104), Issued: September 25, 2001 01WE0502, Construction Permit for Facility Fugitive Emissions (P-106), Issued: September 25, 2001 DEC 282016 01WE0503, Construction Permit for Engine C-166 (P-109), Issued: September 25, 2001 01WE0504, Construction Permit for Engine C-174 (P-110), Issued: September 25, 2001 01WE0505, Construction Permit for Engine C-176 (P-111), Issued: September 25, 2001 01WE0506, Construction Permit for TEG Dehydrator (P-112), Issued: September 25, 2001 05WE0579, Construction Permit for TEG Dehydrator (P-113), Issued: February 22.2006 1 Operating Pennit Application Colorado Department of Public Health and Environment Air Pollution Control Division FACILITY PLOT PLAN FORM 2000-101 Rev 06-95 Facility Name: Marla Compressor Station Facility Identification Code: CO 123-0243 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. Please see Attachment D for an updated Plot Plan for this facility 1. A plant layout (plan view) including all buildings occupied by or located on the site of the facility and any outdoor process layout. 2. The maximum height of each building (excluding stack height). 3. The location and coded designation of each stack. Please ensure these designations correspond to the appropriate stacks listed on the other permit forms in this application. The drawings need not be to scale if pertinent dimensions are annotated, including positional distances of structures, outdoor processes and free standing stacks to each other and the property boundaries. 4. The location of property boundary lines. 5. Identify direction "North" on all submittals. Are there any outdoor storage piles on the facility site with air pollution emissions that need to be reported? Yes x No If "Yes", what is the material in the storage pile(s)? Are there any unpaved roads or unpaved parking lots on the facility site? x Yes No List the name(s) of any neighboring state(s) within a 50 mile radius of your facility: Wyoming 2 Operating Permit Application Colorado Department of Public Health and Envionment Air Pollution Control Division SOURCE AND SITE DESCRIPTIONS FORM 2000-102 Rev 06-95 Facility Name: Marla Compressor Station Facility Identification Code: CO 123-0243 The operating permit must be prepared and submitted on forms supplied by the Division. Use of this form is required for all operating permit applications. The Division will not consider or act upon your application unless each form used has been entirely completed. Completion of the information in the shaded area of this form is optional. Use "NA" where necessary to identify an information request that does not apply and is not in the optional shaded area. 1.Briefly describe the existing Unit(s) to be permitted. Attach copies of Form 2000-700 as needed to provide the information. Process flowsheets or line diagrams showing major features and locations of air pollution control equipment can be most effective in showing the location and relationships of the units. Providing mass flowrates/balances at critical points on the diagrams is very helpful when developing an understanding of the processes involved. The Marla Compressor Station uses six (6) gas -fired internal combustion engines to driver compressors to transmit natural gas gathered from field laterals to a primary pipeline. These engines are controlled through non- selective catalytic reduction (NSCR). The station also includes two (2) triethylene glycol dehydrator units that contact "dry" triethylene glycol with the natural gas stream to remove the moisture. The "wet: glycol mixture is regenerated in a still for reuse in the process. These units are equipped with a shared condenser and combustor devices for VOC control. Liquids from the dehydrators are routed to the pressurized slug catchers. Each dehydrator's flash tank vapors are captured by a vapor recovery unit and routed back into the inlet stream. Regenerator still vent vapors are routed to a condenser before being sent to the combustor device. Other equipment on site includes two pressurized bullet condensate storage tanks, which are considered an insignificant activity. Please see attached list in Attachment E for details on these tanks, as well as other insignificant activities at this facility. 2. Site Location and Description (Include instructions needed to drive to remote sites not identified by street addresses) Site location: SESE Section 28, T4N, R64W Directions from Denver, CO: Take 1-76 North out of the Denver Metro area, go approximately 3 miles past the town of Hudson and exit 1-76 at CO Road 49 and proceed north. Travel north on CO Road 49 for approximately 10 miles and turn east on CO Road 34. Proceed east bound on CO road 34 for 2 miles, turn north on CO Road 53. Proceed north on CO Road 53 for 3 miles and turn east on CO Road 40, proceed for one mile, Marla Compressor Station is at the NW corner of CO Road 40 & CO Road 55. 3. Safety Equipment Identify safety equipment required for performing an inspection of the facility: Protection x Hard Hat x Safety shoes x Hearing Protection Gloves x Other, specify Fire retardant clothing 3 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SOURCE DESCRIPTION - APENS FORM 2000-102A Rev 06-95 Facility Name: Marla Compressor Station Facility Identification Code: CO 123-0243 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) Attachment B contains copies of the following APENs: Source ID AIRS ID Description APEN Date C-148 / P-102 052 Waukesha Model L-7042 GSI Natural Gas Fired Internal Combustion Reciprocating Engine, 4 -cycle, Standard Rich Burn, Serial No. 232481, 1,478 HP, powering a natural gas compressor 06/12/2014 C-135 / P-103 053 Waukesha Model L-7042 GSI Natural Gas Fired Internal Combustion Reciprocating Engine, 4 -cycle, Standard Rich Burn, Serial No. 317310, 1,478 HP, powering a natural gas compressor 03/23/2016 C-151 / P-004 054 Waukesha Model L-7042 GSI Natural Gas Fired Internal Combustion Reciprocating Engine, 4 -cycle, Standard Rich Burn, Serial No. C-12843/1, 1,478 HP, powering a natural gas compressor 03/23/2016 C-166 / P-109 059 Waukesha Model L-7044 GSI Natural Gas Fired Internal Combustion Reciprocating Engine, 4 -cycle, Standard Rich Burn, Serial No. C-13852/1, 1,680 HP, powering a natural gas compressor 09/30/2016 C-174 / P-110 060 Waukesha Model L-7044 GSI Natural Gas Fired Internal Combustion Reciprocating Engine, 4 -cycle, Standard Rich Burn, Serial No. C-13849/1, 1,680 HP, powering a natural gas compressor 03/23/2016 C-176 / P-111 061 Waukesha Model L-7044 GSI Natural Gas Fired Internal Combustion Reciprocating Engine, 4 -cycle, Standard Rich Burn, Serial No. C-17976/1, 1,680 HP, powering a natural gas compressor 12/01/2015 P-112 062 Natural Gas Dehydration System using triethylene glycol, maximum glycol recirculation rate of 6.25 gallons/minute 03/23/2016 P-113 063 Natural Gas Dehydration System using triethylene glycol, maximum glycol recirculation rate of 6.25 gallons/minute 03/06/2015 2.No APEN exists for an emission unit. List the new APEN and the appropriate descriptive information here. Submit the APEN with a construction permit application. New APEN and permit application submitted (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 0 Filing Fee Enclosed New permit application enclosed: ❑ Yes x No Permit modification application enclosed: 0 Yes x No 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: Marla Compressor Station Facility Identification Code: CO 123-0243 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 form used has been entirely completed. Please see Attachment E, and included Supplemental Form 700 for complete list of Insignificant Activities 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 I.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). Petroleum industry flares, not associated with refineries, combusting natural gas containing no H2S except in trace (less than 500 ppmw) amounts, approved by the Colorado Oil and Gas Conservation Commission and having uncontrolled emissions of any pollutant of less than five tons per year. Chemical storage tanks or containers that hold less than 500 gallons, and which have a daily throughput less than 25 gallons. Landscaping and site housekeeping devices equal to or 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. x 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. 5 x Crude oil or condensate storage tanks with a capacity of 40,000 gallons or less. ❑ 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 6 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division ( SEE INSTRUCTIONS ON REVERSE SIDE SUPPLEMENTAL INFORMATION 1. Facility name: Marla Compressor Station FORM 2000-700 09-94 2. Facility identification code: CO 123-0243 3. This form supplements Form 2000 -102B for Emission Unit Insignificant Sources Source Description Insignificant Per 1,000 gal methanol tank Regulation No. 3, Part C, Section H.E.3.a 300 bbl methanol tank Regulation No. 3, Part C, Section H.E.3.a 1,000 gal TEG glycol tank Regulation No. 3, Part C, Section II.E.3.a 1,000 gal Norkool glycol tank Regulation No. 3, Part C, Section II.E.3.a 30,000 gal Pressurized Condensate Storage Tank Regulation No. 3, Part C, Section II.E.3.a 30,000 gal Pressurized Condensate Storage Tank Regulation No. 3, Part C, Section H.E.3.a TK-0173 -10 bbl slop oil tank Regulation No. 3, Part C, Section H.E.3.aaa TK-8 —1,000 gal lube oil tank Regulation No. 3, Part C, Section II.E.3.aaa TK-8A — 210 bbl lube oil tank Regulation No. 3, Part C, Section II.E.3.aaa TK-0515 - 80 bbl produced water tank Regulation No. 3, Part C, Section II.E.3.uu TK-0516 - 80 bbl produced water tank Regulation No. 3, Part C, Section H.E.3.uu TK-0175 - 80 bbl produced water tank Regulation No. 3, Part C, Section H.E.3.uu TK-1080 - 80 bbl TEG/produced water tank Regulation No. 3, Part C, Section II.E.3.uu TK-0850 - 50 bbl produced water tank Regulation No. 3, Part C, Section H.E.3.uu TK-1074 - 80 bbl used oil tank Regulation No. 3, Part C, Section H.E.3.aaa TK-1 — 500 gal mobile used oil tank Regulation No. 3, Part C, Section II.E.3.aaa Meter Shed Heaters (x3) — 0.01 MMBtu/hr Regulation No. 3, Part C, Section H.E.3.k Building Heaters (x2) — 0.1 MMBtu/hr Regulation No. 3, Part C, Section H.E.3.k Dehy Reboiler H-112 Regulation No. 3, Part C, Section II.E.3.k Dehy Reboiler H-113 Regulation No. 3, Part C, Section H.E.3.k Condenser Combustor Regulation No. 3, Part C, Section II.E.3.a C-148 vent blowdown Regulation No. 3, Part C, Section II.E.3.a C-135 vent blowdown Regulation No. 3, Part C, Section II.E.3.a C-151 vent blowdown Regulation No. 3, Part C, Section II.E.3.a C-166 vent blowdown Regulation No. 3, Part C, Section H.E.3.a C-174 vent blowdown Regulation No. 3, Part C, Section II.E.3.a C-176 vent blowdown Regulation No. 3, Part C, Section II.E.3.a Produced Water Storage Regulation No. 3, Part C, Section H.E.3.a 1 Pressurized Condensate Truck Loadout Regulation No. 3, Part C, Section II.E.3.a Facility Fugitive Emissions Regulation No. 3, Part C, Section II.E.3.a 2 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE STACK IDENTIFICATION FORM 2000-200 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-102 3a. Construction Permit Number: 01WE0499 4. Exhausting Unit(s), use Unit identification code from appropriate Form(s) 2000-300, 301, 302, 303, 304, 305, 306, 307 2000-300 2000-304 2000-301 2000-305 2000-302 C-148 2000-306 2000-303 2000-307 5. Stack identified on the plot plan required on Form 2000-101 /1 No Change in Engine Location 6. Indicate by checking: ® This stack has an actual exhaust point. The parameters are entered in Items 7-13. ❑ This stack serves to identify fugitive emissions. Skip items 7-13. Go to next form. ❑ When stack height Good Engineering Practice (GEP) exceeds 65 meters (Colorado Air Quality Reg 3.A.VIII.D) data entry is required for Item 7. 7. Discharge height above ground level: 25.0 (feet) 8. Inside dimensions at outlet (check one and complete): Circular 1.2 (feet) ❑ Rectangular Maximum (ACFM) 9. , Exhaust flow rate: Normal (ACFM) Velocity 108 (FPS) ❑ Calculated ❑ Stack Test 10. Exhaust gas temperature (normal):. 1,125. (°F) Does process modify ambient air moisture content? ❑ Yes If"Yes", exhaust gas moisture content: Normal percent Down Horizontal 12. Exhaust gas discharge direction:. Up 13. Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack? ❑ Yes /1 No *****Complete the appropriate Air Permit Application Forms(s) 2000-300, 301, 302, 303, 304, ***** 305, 306, or 307 for each Unit exhausting through this stack. INTERNAL COMBUSTION ENGINE OPERATION Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-302 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-102 4. Engine (Unit) code: C-148 4a. Date first placed in service: 05/06/2004 Date last modified: 5. Engine use: natural gas compression 6. Engine Features: 2 -Cycle ❑ 4 -Cycle El Standard rich burn Air/fuel ratio controller Low-NOx design 7. Emission controls: ❑ No Non -Selective catalytic reduction Selective catalytic reduction Oxidation catalyst Spark -ignition ® Diesel ❑ Standard lean burn Turbocharger Other(Describe): ® Yes- Attach control device form (AOS engine swap, no change) 0 0 N Three-way catalyst Ammonia injected Other: 8. Manufacturer: Waukesha 9. Model No: L-7042 GSI S/N: 232481 10. Max Fuel Design Rate: 11.6 mmBTU/hr 11. Horsepower Max Design: 1,478 Site: 1,478 12. Heat Rate: 7,830 BTU/HP-hr 13. Operating Temp: Min. Max. EF 14. Fuels: Primary Fuel Backup Fuel #1 Fuel Type: Natural Gas Heating Value BTU/SCF 1,200 Sulfur Content (Wt %) Neg. Ash Content, (Wt %) Neg. Moisture Content (%) Maximum Hourly Consumption (Ft3,gal) 9,644 scf/hr Maximum Yearly Consumption (Ft3,gal) 84.5 MMscf/yr NOTE: Data entry below is NOT OPTIONAL if parametric monitoring is used for compliance demonstration 15.Operational Parameters ' Low . . High REMARKS , Ignition Timing (degrees) `. Speed (RPM) ' Intake"Air Temp. (EF) Air.and Fuel Manifold Pressure . Exhaust Temperature (EF) . Exhaust Oxygen (°%) . = Waste Gate Position <. Fuel Regulator Setting **'K** Identify, the method of compliance demonstration by completing Form 2000-500, ***** DESCRIPTION OF METHODS USED FOR DETERMINING COMPLIANCE. Attach Form 2000-500 to this form. ***** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE STACK IDENTIFICATION FORM 2000-200 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-109 3a. Construction Permit Number: 01WE0503 4. Exhausting Unit(s), use Unit identification code from appropriate Form(s) 2000-300, 301, 302, 303, 304, 305, 306, 307 2000-300 2000-304 2000-301 2000-305 2000-302 C-166 2000-306 2000-303 2000-307 5. Stack identified on the plot plan required on Form 2000-101 ® No Change in Engine Location 6. Indicate by checking: This stack has an actual exhaust point. The parameters are entered in Items 7-13. This stack serves to identify fugitive emissions. Skip items 7-13. Go to next form. When stack height Good Engineering Practice (GEP) exceeds 65 meters (Colorado Air Quality Reg 3.A.VIILD) data entry is required for Item 7. 7. Discharge height above ground level: `'40.0 (feet) 8. Inside dimensions at outlet (check one and complete): Circular 1.2 (feet) ❑ Rectangular length (feet) 9. Exhaust flow rate: Normal (ACFM) Velocity 205 (FPS) ❑Calculated ❑ Stack Test Maximum (ACFM) 10. Exhaust gas temperature (normal): 1,152 (°F) 11. Does process modify ambient air moisture content? ❑ Yes If "Yes", exhaust gas moisture content: Normal ' percent ❑ Down ❑ Horizontal 12. Exhaust gas discharge direction: ® Up. 13. Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack? ❑ Yes 11 No *****Complete the appropriate Air Permit Application Forms(s) 2000-300, 301, 302, 303, 304, ***** 305, 306, or 307 for each Unit exhausting through this stack. INTERNAL COMBUSTION ENGINE OPERATION Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-302 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-109 4. Engine (Unit) code: C-166 4a. Date first placed in service: 09/25/2001 Date last modified: 5. Engine use: natural gas compression 6. Fngine Features: 2 -Cycle ❑ 4 -Cycle ® Spark -ignition Standard rich burn Air/fuel ratio controller ❑ Low-NOx design ❑ 7. Emission controls: ❑ No Non -Selective catalytic reduction Selective catalytic reduction Oxidation catalyst Diesel ❑ Standard lean burn Turbocharger Other(Describe): 0 ® Yes - Attach control device form (AOS engine swap, no change) Three-way catalyst ❑ 0 Ammonia injected 0 Other: 8. Manufacturer: Waukesha 9. Model No: L-7044 GSI S/N: C-13852/1 10. Max Fuel Design Rate: 13.2 mmBTU/hr 11. Horsepower Max Design: 1,680 Site: 1,680 12. Heat Rate: 7,860 BTU/HP-hr 13. Operating Temp: Min. Max. EF 14. Fuels: Primary Fuel Backup Fuel #1 Fuel Type: Natural Gas Heating Value BTU/SCF 1,200 Sulfur Content (Wt.%) Neg. Ash Content, (Wt.%) Neg. Moisture Content (%) Maximum Hourly Consumption (Ft3,gal) Maximum Yearly Consumption (Ft3,gal) NO 1'E: Data entry below is NOT OPTIONAL if parametric monitoring is used for compliance demonstration 11,004 scf/hr 96.4 MMscf/yr 15.Operational Parameters . • • •:: Ignition Timing°(degrees) "' Low •: . High • REMARKS • ' Speed (RPM) Intake .O1'4O1 (EF) . . Air and Fuel Manifold Pressure Exhaiist,Temperatu're (EF): Exhaust Oxygen (%): Waste Gate Position Fuel Regulator Setting ***** Identify, the method of compliance demonstration by completing Form 2000-500, ***** DESCRIPTION OF METHODS USED FORDEIERMINIING COMPLIANCE. Attach Form 2000-500 to this form. ***** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE STACK IDENTIFICATION FORM 2000-200 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-110 3a. Construction Permit Number: 01WE0504 4. Exhausting Unit(s), use Unit identification code from appropriate Form(s) 2000-300, 301, 302, 303, 304, 305, 306, 307 2000-300 2000-304 2000-301 2000-305 2000-302 C-174 2000-306 2000-303 2000-307 5. Stack identified on the plot plan required on Form 2000-101 ® No Change in Engine Location 6. Indicate by checking: This stack has an actual exhaust point. The parameters are entered in Items 7-13. This stack serves to identify fugitive emissions. Skip items 7-13. Go to next fa( 1. When stack height Good Engineering Practice (GEP) exceeds 65 meters (Colorado Air Quality Reg 3.A.VIII.D) data entry is required for Item 7. Discharge height above ground level: 40.0 (feet) 8. Inside dimensions at outlet (check one and complete): ® Circular 1.0 (feet) ❑ Rectangular length (feet) width (feet) 9. Exhaust flow rate: _Normal (ACFM) Velocity .. 205 (FPS) ❑ Calculated ❑ Stack Test Maximum (ACFM 10. Exhaust gas temperature (noiuial): 1,152 (°F) 11': Does process modify ambient air moisture content? ❑ Yes If "Yes", exhaust gas moisture content: Normal percent El Down Horizontal Maximum percent 12.; Exhaust gas discharge direction: Up 13. ' Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack? ❑ Yes ® No *****Complete the appropriate Air Permit Application Forms(s) 2000-300, 301, 302, 303, 304, ***** 305, 306, or 307 for each Unit exhausting through this stack. INTERNAL COMBUSTION ENGINE OPERATION Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-302 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-110 4. Engine (Unit) code: C-174 4a. Date first placed in service: 12/2001 Date last modified: 5. igine use: natural gas compression 6. Engine Features: 2 -Cycle ❑ 4 -Cycle El Standard rich burn Air/fuel ratio controller Low-NOx design 7. Emission controls: ❑ No Non -Selective catalytic reduction Selective catalytic reduction Oxidation catalyst Spark -ignition O Diesel ❑ Standard lean burn Turbocharger Other(Describe): ❑ ® Yes - Attach control device form (AOS engine swap, no change) Three-way catalyst ❑ ❑ Ammonia injected ❑ ❑ Other: 8. Manufacturer: Waukesha 9. Model No: L-7044 GSI S/N: C-13849/1 10. Max Fuel Design Rate: 13.2 mmBTU/hr 11. Horsepower Max Design: 1,680 Site: 1,680 12. Heat Rate: 7,860 BTU/HP-hr 13. Operating Temp: Min. Max. EF 14. Fuels: Primary Fuel Backup Fuel #1 Fuel Type: Natural Gas Heating Value BTU/SCF 1,200 Sulfur Content (Wt.%) Neg. Ash Content, (Wt.%) Neg. Moisture Content (%) Maximum Hourly Consumption (Ft3,gal) 11,004 scf/hr Maximum Yearly Consumption (Ft3,gal) 96.4 MMscf/yr NOTE: Data entry below is NOT OPTIONAL if parametric monitoring is used for compliance demonstration 15: Operational Parameters Low: High., • .. REMARKS ..:. Ignition Timing (degrees) Speed.(RPM) . Intake Air Temp. (EF) Air and.Fuel Manifold Pressure Exhaust,Temperature (EF) Exliaiis Oxygen ,Waste Gate Position' Fuel Regulator Setting ***** Identify, the method of compliance demonstration by completing Form 2000-500, ***** DESCRIPTION OF METHODS USED FOR DE1'ERM NING COMPLIANCE. Attach Form 2000-500 to this form. ***** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE STACK IDENTIFICATION FORM 2000-200 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-111 3a. Construction Permit Number: 01WE0505 4. Exhausting Unit(s), use Unit identification code from appropriate Form(s) 2000-300, 301, 302, 303, 304, 305, 306, 307 2000-300 2000-304 2000-301 2000-305 2000-302 C-176 2000-306 2000-303 2000-307 5. Stack identified on the plot plan required on Form 2000-101 ® Engine Location Identified 6. Indicate by checking: ® This stack has an actual exhaust point. The parameters are entered in Items 7-13. ❑ This stack serves to identify fugitive emissions. Skip items 7-13. Go to next form. ❑ When stack height Good Engineering Practice (GEP) exceeds 65 meters (Colorado Air Quality Reg 3.A.Vf.D) data entry is required for Item 7. Discharge height above ground level: 40.0 (feet) 9. Inside dimensions at outlet (check one and complete): Exhaust flow rate: ❑ Rectangular Normal Velocity 205 (FPS) ❑ Calculated ❑ Stack Test (ACFM) Maximum (ACFM 10. Exhaust gas temperature (normal): ' 1,152 (°F) 11. Does process modify ambient air moisture content? ❑ Yes If "Yes",exhaust gas moisture content: Normal percent ® No ❑ Down Maximum percent 12. Exhaust gas discharge direction: Up Horizontal 13. Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack? ❑ Yes 14 No *****Complete the appropriate Air Permit Application Forms(s) 2000-300, 301, 302, 303, 304, ***** 305, 306, or 307 for each Unit exhausting through this stack. INTERNAL COMBUSTION ENGINE OPERATION Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-302 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-111 4. Engine (Unit) code: C-176 4a. Date first placed in service: 02/2003 Date last modified: 5. Engine use: natural gas compression 6. Engine Features: 2 -Cycle ❑ 4 -Cycle Standard rich burn Air/fuel ratio controller Low-NOx design 7. Emission controls: ❑ No Non -Selective catalytic reduction Selective catalytic reduction Oxidation catalyst Spark -ignition El El Diesel ❑ Standard lean burn ❑ Turbocharger El Other(Describe): Yes - Attach control device form (AOS engine swap, no change) Three-way catalyst Ammonia injected Other: 8. Manufacturer: Waukesha 9. Model No: L7044 GSI S/N: C-17976/1 10. Max Fuel Design Rate: 13.2 mmBTU/hr 11. Horsepower Max Design: 1,680 Site: 1,680 12. Heat Rate: 7,860 BTU/I P -hr 13. Operating Temp: Min. Max. EF 14. Fuels: Primary Fuel Backup Fuel #1 Fuel Type: Natural Gas Heating Value BTU/SCF 1,200 Sulfur Content (Wt.%) Neg. Ash Content, (Wt.%) Neg. Moisture Content (%) Maximum Hourly Consumption (Ft3,gal) 11,004 scf/hr Maximum Yearly Consumption (Ft3,gal) 96.4 MMscf/yr NO 1•h: Data entry below is NOT OPTIONAL if parametric monitoring is used for compliance demonstration 15.Opeiational Parameters Low.'.; • High .. . Ignition Timing (degrees) Speed (4P): `: • Intake Air. Temp. (EF), . Air and Fuel Manifold Pressure :::= Exlans.Temperature. (EF). Exhaust Oxygen (%): :... Wasid.Gate Position: Fuel Regulator Setting; . ,. . ***** Identify, the method of compliance demonstration by completing Form 2000-500, ***** DESCRIPTION OF METHODS USED FOR DETERMINING COMPLIANCE. Attach Form 2000-500 to this form. ***** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2060-601 for this Unit. ***** Operating Permit Application PLANT -WIDE HAZARDOUS AIR POLLUTANTS Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-602 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 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 Pollutant Name Actual emissions Allowable OR Potential to emit Quantity Units Quantity Units 75-07-0 Acetaldehyde 0.5 TPY 107-02-8 Acrolein 0.4 TPY 71-43-2 Benzene 0.9 TPY 50-00-0 Formaldehyde 1.6 TPY 67-56-1 Methanol 0.5 TPY 110-54-3 n -Hexane 0.2 TPY 108-88-3 Toluene 1.1 TPY 1330-20-7 Xylenes 0.5 TPY 100-41-4 Efhylbenzene 0.04 TPY 540-84-1 2,2,4 Trimethylpentane 0.0 TPY NOTE: If there is a permit for this unit, the permit limits are the same as the potential to emit. 7 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE PLANT -WIDE CRITERIA AIR POLLUTANTS FORM 2000-603 09-94 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Complete the following emissions summary for the listed emissions at this facility. Air pollutant Actual ' Potential to emit Maximum allowable TPY TPY TPY Particulates (TSP) 6.3 6.3 PM -10 6.3 6.3 Nitrogen oxides 184.2 184.2 Volatile organic compounds 95.2 95.2 Carbon monoxide 213.7 213.7 Lead Sulfur dioxide 0.2 0.2 Total reduced sulfur Reduced sulfur compounds Hydrogen sulfide Sulfuric acid mist Fluorides 8 Operating Operating Permit Application TABULATION OF PERMIT APPLICATION FORMS Colorado Department of Health Air Pollution Control Division Facility Name: Marla Compressor Station I. ADMINISTRATION FORM 2000-800 09-94 Facility Identification Code: CO 1230243 This 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 DESCRIPTION Total Number of This Form This application contains the following forms (one form for each facility boiler. printing ❑ Form 2000-200, Stack Identification 4 o Form 2000-300, Boiler or Furnace Operation o Form 2000-301, Storage Tanks o Form 2000-302, Internal Combustion Engine 4 ❑ Form 2000-303, Incineration ❑ Form 2000-304, Printing Operations o Form 2000-305, Painting and Coating Operations ❑ Form 2000-306, Miscellaneous Processes o Form 2000-307, Glycol Dehydration Unit III. AIR POLLUTION CONTROL SYSTEM Total Number of This Form This application contains the following forms: ❑ Form 2000-400, Miscellaneous o Form 2000-401, Condensers ❑ Form 2000-402, Adsorbers o Form 2000-403, Catalytic or Thermal Oxidation o Form 2000-404, Cyclones/Settling Chambers ❑ Form 2000-405, Electrostatic Precipitators o Form 2000-406, Wet Collection Systems ❑ Form 2000-407, Baghouses/Fabric Filters IV. COMPLIANCE DEMONSTRATION Total Number of This Form This application contains the following forms (one for each facility boiler, printing operation, x Form 2000-500, Compliance Certification - Monitoring and Renortine o Form 2000-501, Continuous Emission Monitoring X Form 2000-502, Periodic Emission Monitoring Using Portable Monitors X Form 2000-503, Control System Parameters or Operation Parameters of a Process o Form 2000-504, Monitoring Maintenance Procedures ❑ Form 2000-505, Stack Testing o Form 2000-506, Fuel Sampling and Analysis X Form 2000-507, Recordkeeping X Form 2000-508, Other Methods 9 V. EMISSION SUMMARY AND COMPLIANCE CERTIFICATION Total Number of This Form This application contains the following forms quantifying emissions, certifying compliance with applicable requirements, and developing a compliance plan x Form 2000-600, Emission Unit Hazardous Air Pollutants X 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 x 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 0 Form 2000-607, Plant -Wide Applicable Requirements ❑ Form 2000-608, Plant -Wide Compliance Plan - Commitments and Schedule VI. SIGNATURE OF RESPONSIBLE OFFICIAL - FEDERAL/STATE CONDITIONS A. STATEMENT OF COMPLETENESS I have reviewed this application in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this application are true, accurate and complete. B. CERTIFICATION OF FACILITY COMPLIANCE STATUS - FEDERAL/STATE CONDITIONS (check one box only) x I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. ❑ I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements, except for the following emissions unit(s): (list all non -complying units) WARNING: Any person who knowingly, as defined in § 18-1-501(6), C.R.S., makes any false material statement, representation, or certification in, or omits material information from this application is guilty of a misdemeanor and may be punished in accordance with the provisions of § 25-7 122.1, C.R.S. Printed or Typed Name William L. Johnson Title Vice President of Operations Signature Date Signed / 2 I r it/P/Li 10 Operating Permit Application Colorado Department of Health Air Pollution Control Division Facility Name: Marla Compressor Station CERTIFICATION FOR STATE -ONLY CONDITIONS FORM 2000-800 09-94 Facility Identification Code: CO 123-0243 VI. SIGNATURE OF RESPONSIBLE OFFICIAL - STATE ONLY CONDITIONS A. STATEMENT OF COMPLETENESS I have reviewed this application in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this application are true, accurate and complete. B. CERTIFICATION OF FACILITY COMPLIANCE STATUS FOR STATE -ONLY CONDITIONS (check one box only) X I certify that the facility described in this air pollution permit application is 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 William L. Johnson Title Vice President of Operations Si nature Date Signed //Z i i gal-, SEND ALL MATERIALS TO: COLORADO DEPARTMENT OF HEALTH APCD-SS-B 1 4300 CHERRY CREEK DRIVE SOUTH DENVER, CO 80246-1530 11 MAJOR SOURCE OPERATING PERMIT APPLICATION APPLICATION COMPLETENESS SUMMARY FORM 1. FACILITY NAME: 2. PERMIT: 3. REVIEW ENGINEER: 4. DATE OF APPLICATION: 5. DATE RECEIVED BY APCD COMPLETENESS DETERMINATION I. IDENTIFYING INFORMATION II. EMISSIONS III. APPLICABILITY IV. COMPLIANCE COMPLETE INCOMPLETE NOT APPLICABLE _ COMPLETE _ INCOMPLETE _ NOT APPLICABLE _ COMPLETE INCOMPLETE NOT APPLICABLE COMPLETE INCOMPLETE NOT APPLICABLE APPLICATION FORM CERTIFIED FOR TRUTH, ACCURACY, AND COMPLETENESS BY: OFFICIAL TITLE SIGNATURE DATE APPLICATION EVALUATION COMPLETE (BASIC INFORMATION PRESENT TO BEGIN PROCESSING) INCOMPLETE - RETURN WITH ADDITIONAL INFORMATION BY: COMMENTS REVIEWED BY: DATE MAJOR SOURCE OPERATING PERMIT APPLICATION APPLICATION COMPLETENESS CHECK LIST !. IDENTIFYING INFORMATION APPLICABLE COMPLETE _ INCOMPLETE _ NOT 12 A. FACILITY INFORMATION FACILITY NAME, LOCATION & MAILING ADDRESS _ YES _ NO PERMIT CONTACT PERSON _ YES _ NO RESPONSIBLE OFFICIAL _ YES NO PERMIT REQUESTED _ YES _ NO B. SOURCE DESCRIPTION 1. OPERATIONAL INFORMATION: _ YES _ NO SIC/SCC CODES _ YES _ NO LISTING AND DESCRIPTION OF EMISSION SOURCE(S) _ YES NO 2. IDENTIFICATION AND DESCRIPTION OF ALTERNATIVE OPERATIVE SCENARIOS (IF APPLICABLE) _ YES _ NO _ N/A C. PERMIT SHIELD REQUESTED _ 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 ANY WORK PRACTICE STANDARDS 6. OTHER INFORMATION REQUIRED BY ANY APPLICABLE REQUIREMENTS FOR ALL REGULATED AIR POLLUTANTS SUCH AS: FLOW RATES STACK PARAMETERS YES NO N/A YES NO N/A YES NO N/A 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 APPLICABLE REQUIREMENTS OR TO DETERMINE THE APPLICABILITY OF REQUIREMENTS N/A YES NO 3. AN EXPLANATION OF ANY PROPOSED EXEMPTIONS FROM OTHERWISE APPLICABLE REQUIREMENTS _ YES NO _ 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 NOT APPLICABLE COMPLETE INCOMPLETE 1. A SCHEDULE OF COMPLIANCE FOR SOURCES THAT ARE NOT IN COMPLIANCE WITH ALL APPLICABLE REQUIREMENTS AT THE TIME OF PERMIT ISSUES YES NO N/A 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 A RESPONSIBLE OFFICIAL YES NO 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 4. A STATEMENT INDICATING THE SOURCE'S COMPLIANCE STATUS WITH ANY APPLICABLE ENHANCED MONITORING AND COMPLIANCE CERTIFICATION REQUIREMENTS OF THE FEDERAL ACT YES NO YES NO 14 Attachment B Current APENs Marla Compressor Station AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Reciprocating Internal Combustion Engine' You will be charged an additional APEN fee if APEN is filled out incorrectly or missing information and requires re -submittal. Permit Number: 95OPWE020 [Leave blank unless APCD has already assigned a pcnnit It & AIRS ID] Emission Source AIRS ID: Facility Equipment ID: C-1481 P-102 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01 — Administrative Information Company Name: DCP Midstream, LP Source Name: Marla Compressor Station Source Location: Portable Source 1 -tome Base: SE Sec 28, T4N, R64W Mailing Address: 370 17th Street, Suite 2500 Denver, Colorado Person To Contact: Roshini Shankaran E-mail Address: RShankaran@DCPMidslream.com Section 03 — General Information For existing sources. operation began on: 05 / 06 Normal hours of source operation: 24 hours/day 7 days/week 52 weeks/year General description of equipment purpose: Natural Gas Compression NAICS, or SIC Code: 4922 County: Weld Elevation: 4,737 Feet ZIP Code: 80202 Phone Number: 303-605-2039 Fax Number: 303-605-1957 123 / 0243 / 052 Section 02 —Requested Action (check applicable request boxes) ❑ Request for NEW permit or newly reported emission source O Request for coverage under GENERAL PERMIT number GP02 (Natural Gas Only) O Request MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O Change company name O Change permit limit ❑ Transfer of ownership 0 Other ❑ Request PORTABLE source permit O Request APEN Update Emissions data must be completed. Blank APENs trill not be accepted El Notification of AOS permanent replacement Addl. Info. bi - Notes: / 2004 For new or reconstructed sources, the projected startup date is: / / Date the engine was ordered: 1987 Date engine construction commenced: Date the engine was relocated into Colorado: 05/06/2004 Date of any rcconstnuction/modification: Will this equipment be operated in any NAAQS nonatlainmcnt area? (http:!,ww v.coloradomovicchheiallainment) Section 04 — Ermine Information Engine date of manufacture: 08/25/1972 Manufacturer: Waukesha Model: L-7042 GSI Engine function: O Primary and/or peaking power 0 Compression O Pump jack Manufacturer's maximum rated horsepower @ sea level: Manufacturer's maximum site ralina: Engine Brake Specific Fuel Consumption @ 100% Load: Cycle Type: ❑ 2 -Stroke❑ 4 -Stroke Ignition Source: E Spark O Compression 1987 N/A Ycs O No Engine displacement: 115 Serial No.: 232481 O Emergency back-up power O Water pump ❑ Other: 13I-IP (a; RPM 1,478 BHP @ 1,200 RPM 7,830 Blu/I-1F-hr Combustion: Aspiration: .What is the maximum number of hours this engine is used for emergency back—up power? Don't lalow L/cyl kW Lean Buns I Rich Buns Natural E Turbocharged I-Iours/year Colorado Department of Public Health and Environment Air Pollution Control Division (APCD) This notice is valid for five (5) years. Submit a revised APEN prior to expiration of live -year term, or when a significant change is made (increase production, new equipment, change in fuel type, etc). Mail this form along with a check for $152.90 per APEN and S1,500 for each general permit registration to: Colorado Department of Public Health Sc Environment APCD-SS-Bl 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Air Pollution Control Division: (303) 692-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 APEN forms: htlp://www.colorado.gov/cdphc/APENforms Application status: littp://wmv.coiorado.gov/cdphc/permitstatus ❑ Check box to request copy of draft permit prior to issuance. O Check box to request copy of draft permit prior to public notice. FORM APCD-201 Page I of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Reciprocating Internal Combustion Engine' Permit Number: 95OPWE020 Emission Source AIRS ID: 123 / 0243 / 052 Section 05 — Stack Information (Attach a separate sheet with relevant information in the event of multiple stacks; provide datum roc either Lai/Long or UTM) Operator Stack ID No. Stack Base Elevation (feet) Stack Discharge Height Above (feet) Temp. (°F) Ground Level (ACFM) (tUsec) Flow Rate Velocity Moisture o; (•�) Horizontal Datum (NAD27, NAD83, WGS84 ) UTM Zone (12 or 13) UTM Easting or Longitude (meters or degrees) UTM Northing or Latitude (meters or degrees) Method of Collection for Location Data (e.g. map, GPS, GoogleEarth) C -1481P-102 4,737 25 1,125 6,967 108 AMB WGS84 13 538,468.97 4,458,467.15 GPS Direction of stuck outlet (check one): ■❑ Vertical O Vertical with obstn cling raincup Exhaust Opening Shape & Size (check one): LI Circular: Inner Diameter (incises) = 14 Section 06 — Fuel Consumption information ❑ Horizontal O Down O Other (Describe): O Other: Length (inches) = Width (inches) _ Fuel Type u Fuel Use Rate @100 /o load (SCF/hr, gal/hr) Annual Fuel Consumption (gal/yr or MMSCF/yr) Fuel Heating Value (Btu/lb, Btu/gal, Btu/SCF) Sulfur Content (% wt.) Seasonal Fuel Use (% of Annua Use) Actual Reported for Calendar Year Requested Permit Limit Dec -Feb Mar -May Jun -Aug Sep -Nov Natural Gas 9,644 SCF/hr 81.7 MMscf/yr 84.5 MMscf/yr 1,200 Btu/scf neg. 25 25 25 25 Is this engine equipped with an Air/Fuel ratio controller? Yes ❑ No Section 07 — Emissions Inventory Information & Emission Control Information i l Emission Factor Documentation attached Data year for actual calendar yr. emissions below & fuel use above (e.g. 2007): 2013 Pollutant Control Device Description Control Efficiency (% Reduction) Emission Factor Actual Calendar Year Emissions2 Requested Permitted Emissions Estimation Method or Emission Factor Source Primary Secondary Uncontrolled Basis Units Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) TSP PM10 1.94 E-02 lb/mmbtu 0.89 0.89 0.98 0.98 AP42 PM, 5 1.94 E-02 lb/mmbtu 0.89 0.89 0.98 0.98 AP42 SOx 5.88 E-04 lb/mmbtu 0.027 0.027 0.03 0.03 AP42 NOx NSCR 11.0 g/hp-hr 142.55 38.66 156.99 42.82 Manuf. Data VOC NSCR 1.5 g/hp-hr 19.44 12.89 21.41 14.27 Manuf. Data CO NSCR 8.0 g/hp-hr 103.67 38.66 114.18 42.82 Manuf. Data Formaldehyde NSCR 76 2.05 E-02 lb/mmbtu 0.94 0.23 1.04 0.25 AP42 Acetaldehyde NSCR 50 2.79 E-03 lb/mmbtu 0.13 0.06 0.14 0.07 AP42 Acrolcin NSCR 50 2.63 E-03 lb/mmbtu 0.12 0.06 0.13 0.07 AP42 Benzene NSCR 50 1.58 E-03 lb/mmbtu 0.07 0.04 0.08 0.04 AP42 Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. You will be charged an additional APEN fee if ADEN is tilled out incorrectly or missing information and requires re -submittal. 'Anual emission fees will be based on actual emissions reported here. If left blank, annual emission fees will be based on requested emissions. Section 0'f —Applicant Certification - I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration forcovcrage under general permit GPO?, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. Signature of Person Legally Authorized to Supply Data Dale / I2 r Z Q 1 (r Roshini Shankaran Environmental Engineer "t Name of Legally Authorized Person (Please print) Title Page 2 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) Permit Number: Company Name: Plant Location: Person to Contact: E-mail Address: 95OPWE020 DCP Midstream, LP SE Sec 28, T4N, R64W Roshini Shankaran RShankaran@DCPMidstream.com AIRS ID Number: 123 / 0243 / 052 County: Weld Phone Number: 303-605-2039 Zip Code: Fax Number: 303-605-1957 Chemical Abstract Service (CAS) Number Chemical Name Control Equipment / Reduction (%) Emission Factor (Include Units) Emission Factor Source Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions (lbs/year) 30.52 106-99-0 1,3 Butadiene NSCR/ 50% 6.63E-04 Ib/mmbtu AP -42 61.03 68-56-1 Methanol NSCR/ 50% 3.06E-03 lb/mmbtu AP -42 281.68 140.84 Calendar Year for which Actual Data Applies: 2013 _ Signature of Person Legally Authorized to Supply Data Roshini Shankaran Name of Person Legally Authorized to Supply Data (Please print) 0G/ ralzeict Date Environmental Engineer Title of Person Legally Authorized to Supply Data Form Revision Date: April 14, 2014 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Reciprocating Internal Combustion Engine' `i You sill be charge an additional APEN fee if APEN is Filled out incorrectly or missing information and requires re -submittal. Permit Number: 95OPWE020 [Leave blank unless APCD has already assigned a permit # & AIRS ID] Emission Source AIRS ID: 123 / 0243 / 053 Facility Equipment ID: C135/P103 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01 — Administrative Information Company Name: DCP Midstream, Li' Source Name: Marla Compressor Station Source Location: SE Sec 28, T4N, R64W Portable Source Home Base: Mailing Address: 370 17th Street, Suite 2500 Person To Contact: E-mail Address: Denver, CO Roshini Shankaran rshankaran@dcpmidstream.com Section 03 — General information For existing sources, operation began on: 09 I 25 / 2001 Normal hours of source operation: General description of equipment purpose: Date the engine was ordered: NAICS, or SIC Code: 4922 County: Weld Elevation: 4,737 Feet ZIP Code: 80202 Phone Number: 303-605-2039 Fax Number: 303-605-1957 24 hours/day 7 days/week 52 weeks/year Natural Gas Compression Section 02 — Requested Action (check applicable request boxes) O Request for NEW permit or newly reported emission source O Request for coverage under GENERAL PERMIT number GP02 (Natural Gas Only) ❑ Request MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership O Other ❑ Request PORTABLE source permit ® Request APEN Update Emissions data crust be completed. Blank APENs will not be accepted ❑ Notification of AOS permanent replacement Addl. Info. & Notes: For new or reconstructed sources, the projected startup date is: / / Prior 9/2001 Date the engine was relocated into Colorado: 5 / 1 / 2010 Will this equipment be operated in any NAAQS nonattainment area? (htt p:r /www.cdphe.statc.co. us/an/an inmaintain. html) Section 04 — Engine information Engine date of manufacture: 02 / 13 / 1978 Manufacturer: Date engine construction commenced: Date of any reconstruction/modification: Waukesha Model: L7042 GSi Engine function: ❑ Primary and/or peaking power ® Compression ❑ Pump jack Manufacturer's maximum rated horsepower @ sea level: Manufacturer's maximum site rating: Engine Brake Specific Fuel Consumption @ 100% Load: Cycle Type: Ignition Source: ❑ 2 -Stroke ® 4 -Stroke • Spark ❑ Compression n/a ® Yes ❑ No O Engine displacement: 9.58 Serial No.: 317310 ❑ Emergency back-up power ❑ Water pump O Other: 1,478 BHP @ 1,200 RPM 1,478 BHP @ 1,200 RPM 7,830 Btu/HP-hr Combustion: Aspiration: What is the maximum number of hours this engine is used for emergency back—up power? Don't know Ucyl kW ❑ Lean Bum ® Rich Burn ❑ Natural ® Turbocharged Hours/year Colorado Department of Public Health and Environment Air Pollution Control Division (APCD) This notice is valid for five (5) years. Submit a revised APEN prior to expiration of fve-year term, or when a significant change is made (increase production, new equipment, change in fuel type, etc). Mail this form along with a check for $152.90 per APEN and $1,500 for each general permit registration to: Colorado Department of Public Health & Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Air Pollution Control Division: (303) 692-3150 Small Business Assistance Program (SBAP): (303) 692-3145 or (303) 692-3175 APEN forms: http://colorado.eov/edphc/ADEN forms Annlication status: hun://www.colorado.eov/cdohc/nermitstatus ❑ Check box to request copy of draft permit prior to issuance. ❑ Check box to request copy of draft permit prior to public notice. FORM APCD-201 Page 1 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Reciprocating Internal Combustion Engine' Permit Number: 95OPWE020 Emission Source AIRS ID: '123 / 0243 / 053 Section 05 — Stack Information (Attach a separate sheet with relevant information in the event of multiple stacks; provide datum & either Lat/Long or UTM) Operator Stack ID No. Stack Base Elevation (feet) Stack Discharge Height Above (feet) Temp. (°F) Ground Level (ACPM) (IUsec) Flow Rate Velocity Moisture ° (%) Horizontal Datum (NAD27, NAD83, WGS84) UTM Zone (12 or 13) UTM Fasting or Longitude (meters or degrees) UTM Northing or Latitude (meters or degrees) Method ol'Collection for Location Data (e.g. map, GPS, GoogleEatth) C135/P103 4,737 25 1,125 6,967 108 AMB 'WGS 84 13 538,468.97 4,458,467.15 GPS Direction of stack outlet (c seek one): ® Vertical ❑ Vertical with obstructing raincap ❑ Horizontal ❑ Down Other (Describe): Exhaust Opening Shape & Size (check one): ® Circular: Inner Diameter (inches) = 14 ❑ Other: Length (inches) = Width (inches) _ Section 06 — Fuel Consumption Information Fuel Type Fuel Use Rate @ 100% load ( SCF/hr, gal/hr) Annual Fuel Consumption (gal/yr or MMSCF/yr) Fuel Heating Value Btu! al, Btu/SCF) g Sulfur Content (% wt.) Seasonal Fuel Use (% of Annua Use) Actual Reported for Calendar Year Requested Permit Limit(Btu/lb, q Dec -Feb Mar -May Jun -Aug Sc Nov Sep-Nov Gas 9,644 SCF/hr 74.13 MMscf/yr 84.5 MMscf/yr 1,200 BTU/SCR Ncg. 25 25 25 25 Is this engine equip )cd with an Air/Fuel ratio controller? ® Yes ❑ Section 07 — Emissions Inventory Information & Emission Control information • No ticndar yr. emissions below & fuel use above (e.o. 2007): 2015 Pollutant Control Device Description Control Efficiency (% Reduction) Emission Factor Actual Calendar Year Emissions2 Requested Permitted Emissions Estimation Method or Emission Factor Source Primary Secondary Uncontrolled Basis Units Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) TSP 1.94E-02 Ib/MMBtu 0.81 0.81 0.98 0.98 AP -42 PMto 1.94E-02 lb/MMBtu 0.81 0.81 0.98 0.98 AP -42 PM: 1.94E-02 Ib/MMBtu 0.81 0.81 0.98 0.98 AP -42 .5 SOx 5.88E-04 Ib/MMBtu 0.02 0.02 0.03 0.03 AP -42 NOx NSCR 82 11.0 g/hp-hr 129.00 2332 156.99 28.54 Manuf Spec. VOC NSCR 33 1.5 g/hp-hr 17.59 11.66 21.41 14.27 Manuf. Spec. CO NSCR 63 8.0 g/hp-hr 93.82 34.99 114.18 42.82 Manuf. Spec. Formaldehyde NSCR 76 2.05E-02 lb/MMBtu 0.85 0.20 1.04 0.25 AP -42 Acetaldehyde Acrolein Benzene Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. You will be charged an additional APEN fcc if ADEN is filled out incorrectly or missing information and requires re-subnuttal. 2 Annual emission fees will be based on actual emissions reported here. If left blank, annual emission fees will be based on requested emissions. Section 08 —Applicant Certification - I hereby cerdfy that all information contained herein and information submitted with this application is complete, true and correct. o3(Z3f2016 Signature of erson Legally Authorized to Supply Data Date Roshini. Shankaran Name of Legally Authorized Person (Please print) Title Environmental Engineer Page 2 of 2 Form APCD-20 l-RICEAPEN-Ver.02.10.2014.docx NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) Permit Number: 95OPWE020 Company Name: Plant Location: Person to Contact: E-mail Address: DCP Midstream, LP Marla Compressor Station Dana Stephens dstephens@dcpmidstream.com AIRS ID Number: 123 / 0243 / 053 County: Weld Zip Code: Phone Number: Fax Number: 303-605-1745 303-605-1957 Chemical Abstract Service (CAS) Number Chemical Name Control Equipment / Reduction (%) Emission Factor (Include Units) Emission Factor Source Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions (lbs/year) 67-56-1 Methanol 50 3.06E-03 AP -42 254.90 127.45 Calendar Year for which Actual Data Applies: 2015 03(Z 3/Z01,6 Signature of Person Legally Authorized to Supply Data Dana Stephens Name of Person Legally Authorized to Supply Data (Please print) Date Rockies Air Permitting Manager Title of Person Legally Authorized to Supply Data Fnrm Ravisinn r)atp• Anril 14 91114 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Reciprocating Internal Combustion Engines `i You will be charge an additional APEN fee if APEN is filled out incorrectly or missing information and requires re -submittal. Permit Number: 95OPWE020 [Leave blank unless APCD has already assigned a permit # & AIRS ID] Emission Source AIRS ID: 123 / 0243 / 054 Facility Equipment ID: C151/P104 [Provide Facility Equipment ID to identity how this equipment is referenced within your organization.] Section 01— Administrative Information Company Name: DCP Midstream, LP Source Name: Marla Compressor Station Source Location: SE Sec 28, T4N, R64W Portable Source Home Base: Mailing Address: 370 17th Street, Suite 2500 Person To Contact: E-mail Address: Denver, CO Roshini Shankaran rshankaran@dcpmidstream.com Section 03 — General Information For existing sources, operation began on: 06 / 23 / 2005 Normal hours of source operation: General description of equipment purpose: Date the engine was ordered: Date the engine was relocated into Colorado: NAICS, or SIC Code: 4922 County: Weld Elevation: 4,737 Feet ZIP Code: 80202 Phone Number: 303-605-2039 Fax Number: 303-605-1957 24 hours/day 7 days/week 52 weeks/year Natural Gas Compression Section 02 — Requested Action (check applicable request boxes) CI Request for NEW permit or newly reported emission source Request for coverage under GENERAL PERMIT number GP02 (Natural Gas Only) Request MODIFICATION to existing permit (check each box below that applies) El Change fuel or equipment El Change company name ❑ Change permit limit El Transfer of ownership ❑ Request PORTABLE source permit ® Request APEN Update Emissions data must be completed. Blank APENs will not be accepted El Notification of AOS permanent replacement Addl. Info. & Notes: Other For new or reconstructed sources, the projected startup date is: / / 1999 04/26/2011 Will this equipment be operated in any NAAQS nonattainment area≥ (hnn:4www.cdphc.slate.co.us/apiatlainmaintain.html) Section 04 — Engine Information Engine date of manufacture: 07 / 23 / 1999 Manufacturer: Waukesha Date engine construction commenced: Prior 06/05 Date of any reconstruction/modification: ❑ Don't ® Yes El No know n/a Engine displacement: 9.58 L/cyl Model: L-7042 GSI Serial No.: C-12843/1 Engine function: El Primary and/or peaking power ® Compression ❑ Pump jack Manufacturer's maximum rated horsepower @ sea level: Manufacturer's maximum site rating: Engine Brake Specific Fuel Consumption @ 100% Load: Cycle Type: Ignition Source: El 2 -Stroke ® Spark ❑ 4 -Stroke Compression ❑ Emergency back-up power El Water pump ❑ Other: 1,478 BHP @ 1,200 RPM 1,478 BHP @ 1,200 RPM 7,830 Btu/HP-hr Combustion: Aspiration: kW ❑ Lean Burn ® Rich Burn El Natural Z Turbocharged What is the maximum number of hours this engine is used for emergency back—up power? Hours/year Colorado Department of Public Health and Environment Air Pollution Control Division (APCD) This notice is valid for live (5) years. Submit a revised APEN prior to expiration of five-year term, or when a significant change is made (increase production, new equipment, change in fuel type, etc). Mail this form along with a check for $152.90 per APEN and $1,500 for each general permit registration to: Colorado Department of Public Health & Environment APCD-SS-Bl 4300 Cherry Creek Drive South Denver, CO 80246-1530 • For guidance on how to complete this APEN form: Air Pollution Control Division: (303) 692-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 APEN forms: http://colorado.gov/cdphc/APENforms Application status: httu://www.colorado.uov/cdohc/ocrntitstatus ❑ Check box to request copy of draft permit prior to issuance. El Check box to request copy of draft permit prior to public notice. FORM APCD-201 Page 1 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Reciprocating Internal Combustion Engine' Permit Number: 95OPWE020 Emission Source AIRS ID: 123 / 0243 / 054 Section 05 — Stack Information (Attach a separate sheet with relevant information in the event of multiple stacks; provide datum & either Lat/Long or UTM) Operator Stack ID No. Stack Base Elevation (feet) Stack Discharge Height Above Ground Level ( feet) Temp. (�" ) Flow Rate (ACFM) Velocity (11/sce) Moisture (%) Horizontal Datum AD27, NAD83, WGS84) UI'M Zone (12 or 13) UTM Easting or Longitude g (meters or degrees) UTM Northing or Latitude (meters or degrees) Method of Collection for Location Data (e.g. map, GPS, GooglcEarth) S151 4,737 25 1,125 6,967 108 AMB VCS 84 13 538,468.97 4,458,467.15 CPS Direction of stack outlet (check one): ® Vertical Exhaust Opening Shape & Size (check one): Z Circular. Inner Diameter (inches) = 14 D Other: Length (inches) = Width (inches) = Section 06 — Fuel Consumption Information ❑ Vertical with obstructing raincap O Horizontal ❑ Down Other (Describe): Fuel Type Fuel Use Rate @ 100% load (SCF/hr, gal/hr) Annual Fuel Consumption (gal/yr or MMSCF/yr) Fuel Heating Value (Btu/lb, Btu/gal, Btu/SCF) Sulfur Content ° ( /° wt.) Seasonal Fuel Use (% of Annua Use) Actual Reported for Calendar Year Requested Permit Limit Dec -Feb Mar -May Jun -Aug Sep -Nov Natural Gas 9,644 SCF/hr 74.47 MMscf/yr 84.5 MMscf/yr 1,200 BTU/SCF Neg. 25 25 25 25 Is this engine equip aed with an Air/Fuel ratio controller? ® Yes ❑ Section 07— Emissions Inventory Information & Emission Control Information No eta year for actual calendar yr. emissions below & fuel use above (e.g. 2007): 2015 Pollutant Control Device Description Control Efficiency (% Reduction) Emission Factor Actual Calendar Year Emissions Requested Permitted Emissions Estimation Method or Emission Factor Source Primary Secondary Uncontrolled Basis Units Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) TSP 1.94E-02 lb/MMBtu 0.81 0.81 0.98 0.93 AP -42 PM in 1.94E-02 lb/MMBtu 0.81 0.81 0.98 0.98 AP -42 PM2, 1.94E-02 lb/MMBtu 0.31 0.81 0.98 0.98 AP -42 SOx 5.83E-04 Ib/MMBtu 0.025 0.025 0.03 0.03 AP -42 NOx NSCR 91 11.0 g/hp-hr 129.55 11.71 156.99 14.27 ManuE Spec. VOC NSCR 53 1.5 g/hp-hr 17.67 837 21.41 9.99 Manuf. Spec. CO NSCR 75 8.0 g/hp-hr 94.22 23.42 114.18 28.54 Manuf. Spec. Formaldehyde NSCR 76 2.05E-02 Ib/IVIMBtu 0.86 0.21 1.04 0.25 AP -42 Acetaldehyde Acrolcin Benzene Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. You will be charged an additional ADEN fee if APEN is filled out incorrectly or missing information and requires re-subnuttal. 2 Annual emission fees will be based on actual emissions reported here, 'cleft blank, annual emission fees will be based on requested emissions. Section 08 —App 'cant Certification - I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Person Legally Authorized to Supply Data ©(7:72(2O1 6 Roshini Shanitaran Date Name of Legally Authorized Person (Please print) Title Environmental Engineer Page 2 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) Permit Number: Company Name: Plant Location: Person to Contact: E-mail Address: 95OPWE020 DCP Midstream, LP Marla Compressor Station Dana Stephens dstephens@dcpmidstream.com AIRS ID Number: 123/0243 / 054 County: Phone Number: Fax Number: Zip Code: 303-605-1745 303-605-1957 Chemical Abstract Service (CAS) Number Chemical Name Control Equipment / Reduction (%) Emission Factor (Include Units) Emission Factor Source Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions (lbs/year) 67-56-1 Methanol 50 3.06E-03 lb/mmBtu AP -42 255.99 127.99 Calen r Year for which Actual Data Applies: 2015 Signature of Person Legally Authorized to Supply Data r Dana Stephens Name of Person Legally Authorized to Supply Data (Please print) 03(23/2()(,6 Date Rockies Air Permitting Manager Title of Person Legally Authorized to Supply Data Form Revision Date: April 14, 2014 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Reciprocating Internal Combustion Engines ri You be charge an additional APEN fee if APEN is filled out incorrectly or missing information and requires re -submittal Permit Number: 95OPWE020 [Leave blank unless APCD has already assigned a permit # & AIRS ID] Emission Source AIRS ID: 123 / 0243 / 059 Facility Equipment ID: C166 / P109 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01 — Administrative Information Section 02 — Requested Action (check applicable request boxes) Company Name: DC1' Midstream, LP NAICS, or ❑ Request for NEW permit or newly reported emission source Source Name: Marla Compressor Station SIC Code: ❑ Request for coverage under GENERAL PERMIT number CP02 (Natural Gas Only) Source Location: SE Sec 28, T4N, R64W County: Weld ❑ Request MODIFICATION to existing permit (check each box below that applies) Elevation: 4,737 Feet ❑ Change fuel or equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership ❑ Other 0 Request PORTABLE source permit 370 17th Street, Suite 2500 ZIP Code: 80202 0 Request APEN Update Denver, CO Emissions data must be completed. Blank APENs ,gill not be accepted Portable Source Home Base: Mailing Address: Person To Contact: E-mail Address: RoshiniShankaran rshankarangdcpmidstream.com Section 03 — General Information For existing sources, operation began on: Normal hours of source operation: General description of equipment purpose: Date the engine was ordered: 9/25/2001 4922 Phone Number: 303-605-2039 Fax Number: 303-605-1957 24 hours/day 7 days/week 52 weeks/year Natural Gas Compression ® Notification of AOS permanent replacement Addl. Info. & Notes: AOS: new engine started on 9 / 20 / 2016 For new or reconstructed sources, the projected startup date is: / / Before 1/2002 Date the engine was relocated into Colorado: Before 1/2002 Will this equipment be operated in any NAAQS nonattainment area? (http://www.cd1he.state.co.us/ap/attaintnaintain.lam I) Section 04 — Engine information Engine date of manufacture: 8 / 21 / 2001 Manufacturer: Waukesha Date engine construction commenced: Date of any reconstruction/modification: Model: L-7044 GS1. Engine function: ❑ Primary and/or peaking power ® Compression . 0 Pump jack Before 1/2002 n/a ® Yes 0 No 0 Engine displacement: Serial No.: ❑ Emergency back-up power 0 Water pump ❑ Other: Manufacturer's maximum rated horsepower @ sea level: 1,680 BHP @ 1,200 RPM Manufacturer's maximum site rating: 1,680 BHP @ 1,200 RPM Engine Brake Specific Fuel Consumption @ 100% Load: 7,860 Btu/HP-hr Cycle Type: Ignition Source: ❑ 2 -Stroke ® 4 -Stroke ® Spark ❑ Compression Combustion: Aspiration: What is the maximum number of hours this engine is used for emergency back—up power? • Don't know 9.58 . L/cyl C-13852/1 kW Lean Bum ® Rich Burn Natural ® Turbocharged 1-lours/year Colorado Department of Public 1-Iealth and Environment Air Pollution Control Division (APCD) This notice is valid for five (5) years. Submit a revised APEN prior to expiration of five-year term, or when a significant change is made (increase production, new equipment, change in fuel type, etc). Mail this form along with a check for $152.90 per APEN and $1,500 for each general permit registration to: Colorado Department of Public Health & Environment APCD-SS-Bl 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Air Pollution Control Division: (303) 692-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 APEN forms: http://colorado.t;ov/ctlphe/APENforms Application status: htio://www.colorado.eov/cdohe/ocrmitstatus O Check box to request copy of draft permit prior to issuance. ❑ Check box to request copy of draft permit prior to public notice. FORM APCD-201 Page 1 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Reciprocating internal Combustion Enainel Permit Number: 95OPWE020 Emission Source AIRS ID: 123 / 0243 / 059 Section 05 — Stack information (Attach a separate sheet with relevant information in the event of multiple stacks; provide datum & either Lat/Long or UTM) Operator Stack ID No. Stack Base Elevation (feet) Stuck Discharge Height Above (feet) Temp. (°P) Flow Rate Ground Lcvcl (ACFM) (!1/sec) (%) Velocity Moisture Horizontal Datum (NAD27, NADS3, WGS84) UTM Zone (12 or 13) UTM Easling or Longitude (meters or degrees) UTM Northing or Latitude (meters or degrees) Method of Collection for Location Data (e.g. map, GPS, GoogleEarth) C166/P109 4,737 40 1,152 9,662 205 AMB SVGS 84 13 538,468.97 4,458,467.15 GPS Direction of stack outlet (check one): ® Vertical ❑ Vertical with obstructing raincap Exhaust Opening Shape & Size (check one): ® Circular: Inner Diameter(inches) = 14 Section 06 — Fuel Consumption Information ❑ Eorizontal ❑ Down ❑ Other: Length (inches) = ❑ Other (Describe): Width (inches) = Fuel Type Fuel Use Rate 100%@ load (SCF/hr, gal/hr) Annual Fuel Consumption (gal/yr or MMSCF/yr) Fuel Heating Value (Btu/lb, Btu/gal, Btu/SCF) Sulfur Content (% wt.) Seasonal Fuel Use (% of Annual Use) — . Actual Reported for Calendar Year Requested Permit Limit Dec -Feb Mar -May Jun -Aug Sep -Nov Natural Gas 11,004 scf/hr 86.45 MMscf/yr 96.4 MMscf/yr 1,200 btu/scf Neg. 25 25 25 25 Is this engine equipped with an Air/Fuel ratio controller? ® Yes O Section 07 — Emissions Inventory Information & Emission Control Information Emission Factor Documentation attached No Data year for actual calendar yr. emissions below & fuel use above (e.g. 2007): 2015 Pollutant Control Device Description Control Efficiency (% Reduction) Emission Factor Actual Calendar Year Emissions 2 Requested Permitted Emissions Estimation Method or Emission Factor Source Primary Secondary Uncontrolled Basis Units Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) TSP 1.94 E-02 lb/MMBtu 0.94 0.94 1.12 1.12 AP -42 PM„ n 1.94 E-02 lb/MMBtu 0.94 0.94 1.12 1.12 AP -42 PM,s 1.94 E-02 lb/MMBtu 0.94 0.94 1.12 1.12 AP -42 SON 5.88 E-04 Ih/MMBtu 0.03 0.03 0.03 0.03 AP -42 NO); NSCR 82 11.0 g/hp-hr 149.85 27.20 178.45 32.45 Manuf Spec. VOC NSCR 33 1.5 g/hp-hr 20.43 13.60 24.33 16.22 Manuf Spec. CO NSCR 75 8.0 g/hp-hr 108.98 27.20 129.78 32.45 Manuf. Spec. Formaldehyde NSCR 76 2.05 E-02 lb/MMBtu 1.00 0.24 1.19 0.28 AP -42 Acetaldehyde NSCR 50 2.79 E-03 Ib/MMBtu 0.14 0.07 0.16 0.08 AP -42 Acrolein NSCR 50 2.63 E-03 Ib/MIVIBtu 0.13 0.06 0.15 0.03 AP -42 Benzene Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. You will be charged an additional APEN fee if APEN is tilled out incorrectly or missing information and requires re -submittal. 'Annual emission fees will be based on actual emissions reported here. If left blank, annual emission fees will be based on requested emissions. Section 08 —A plicant Certification - I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. • 13O(2 O14 Roshini Shankaran Environmental Engineer Signature of erson Legally Authorized to Supply Data Date Name of Legally Authorized Person (Please print) Title Page 2 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) Permit Number: 95OPWE020 Company Name: Plant Location: Person to Contact: E-mail Address: DCP Midstream, LP Marla Compressor Station Roshini Shankaran rshankaran@dcpmidstream.com AIRS ID Number: 123 / 0243 / 059 County: Weld Phone Number: Fax Number: Zip Code: 303-605-2039 303-605-1957 Chemical Abstract Service (CAS) Number Chemical Name Control Equipment / Reduction (%) Emission Factor (Include Units) Emission Factor. Source Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions (lbs/year) 67-56-1 Methanol 50 3.06E-03 lb/mmBtu AP -42 297.24 148.62 Calend-Year for which Actual Data Applies: 2015 Cti30 (Z 016 Signature of Person Legally Authorized to Supply Data Roshini Shankaran Name of Person Legally Authorized to Supply Data (Please print) Date Environmental Engineer Title of Person Legally Authorized to Supply Data Form Revision Date: April 14, 2014 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Reciprocating Internal Combustion Engine' `i You will be charge an additional APEN fee if APEN is filled out incorrectly or missing information and requires re -submittal. Permit Number: 95OPWE020 [Leave blank unless APCD has already assigned a permit # S. AIRS 1D] Facility Equipment ID: C -1741P-110 Section 01 — Administrative Information Company Name: DCP Midstream, LP Source Name: Source Location: Portable Source Home Base: Mailing Address: Person To Contact: E-mail Address: Emission Source AIRS ID: 123 / 0243 / 060 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Marla Compressor Station SE Sec 28, T4N, R64W 370 17th Street, Suite 2500 Denver, CO NAICS, or SIC Code: 4922 County: Weld Elevation: 4,737 Feet ZIP Code: 80202 Roshini Shankaran Phone Number: 303-605-2039 rshankaran@dcpmidstream.com Section 03 — General Information For existing sources, operation began on: Normal hours of source operation: General description of equipment purpose: Date the engine was ordered: Date the engine was relocated into Colorado: Fax Number: 303-605-1957 Section 02 — Requested Action (check applicable request boxes) ❑ Request for NEW permit or newly reported emission source ❑ Request for coverage under GENERAL PERMIT number CP02 (Natural Gas Only) ❑ Request MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership ❑ Other ❑ Request PORTABLE source permit ❑ Request APEN Update Emissions data must be completed. Blank APENs will not be accepted ❑ Notification of AOS permanent replacement Addl. Info. & Notes: 12 / 2001 For new or reconstructed sources, the projected startup date is: 24 hours/day 7 days/week Natural Gas Compression 52 weeks/year / / Pre -2001 Pre -2001 Will this equipment be operated in any NAAQS nonattainmcnt area? (http://www.edphe.state.eo.usiaoiattainmaintain.himl) Section 04 — Engine Information Engine date of manufacture: Pre -2001 Manufacturer: Waukesha Model: Engine function: ❑ Primary and/or peaking power ® Compression ❑ Pump jack Manufacturer's maximum rated horsepower @ sea level: 1,680 Date engine construction commenced: Date of any reconstruction/modification: Pre -2001 n/a ❑ Yes ❑ No ❑ Don't know Engine displacement: 9.58 L/cyl L-7044 GSI Serial No.: C-13849/1 ❑ Emergency back-up power ❑ Water pump ❑ Other: Manufacturer's maximum site rating: 1,680 Engine Brake Specific Fuel Consumption @ 100% Load: 7,860 Cycle Type: Ignition Source: 2 -Stroke Ei 4 -Stroke Spark ❑ Compression BHP @ 1,200 RPM BHP @ 1,200 RPM Btu/HP-hr Combustion: Aspiration: What is the maximum number of hours this engine is used for emergency back—up power? kW Lean Burn ❑ Rich Burn Natural ® Turbocharged Hours/year Colorado Department of Public Health and Environment Air Pollution Control Division (APCD) This notice is valid for five (5) years. Submit a revised APEN prior to expiration of five-year term, or when a significant change is made (increase production, new equipment, change in fuel type, etc). Mail this form along with a check for $152.90 per APEN and $1,500 for each general permit registration to: Colorado Department of Public Health & Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Air Pollution Control Division: (303) 692-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 APEN forms: http://colorado.2ov/cdphc/AP EN forms Annlication status: htto://www.colorado.uov/cduhc/oermitstaius ❑ Check box to request copy of draft permit prior to issuance. ❑ Check box to request copy of draft permit prior to public notice. FORM APCD-201 Page 1 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Reciprocating Internal Combustion Engines Permit Number: 95OPWE020 Emission Source AIRS ID: 123 / 0243 / 060 Section 05 — Stack Information (Attach a separate sheet with relevant information in the event of multiple stacks; provide datum & either Lat/Long or UTM) Operator Stack ID No. Stack Base Elevation (feet) Stuck Discharge Height Above Ground Level (feet) Temp. Flow Rate (ACFM) Velocity (It/see) Moisture (%) Horizontal Datum (NAD27, NAD83, WGS84(12 ) UTM Zone or 13) UTM Easting or Longitude (meters or degrees) b ) UTM Northing or Latitude (meters or degrees) g ) Method of Collection for Location Data (e.g. map, GPS, GoogleEarth) g ) C174/P110 4,737 40 1,152 9,662 205 AMB WGS 84 13 538,468.97 4,458,467.15 CPS Direction of stack outlet (check one): ® Vertical Exhaust Opening Shape & Size (check one): ® Circular: Inner Diameter (inches) = 12 ❑ Vertical with obstructing taincap Section 06 — Fuel Consumption Information ❑ Horizontal 0 Down ❑ Other: Length (inches) = ❑ Other (Describe): Width (inches) = Fuel Type Fuel Use Rate @ 100% load (SCF/hr, gal/hr) Annual Fuel Consumption (gal/yr or MMSCF/yr) Fuel Heating Value (Btu/lb, Btu/gal, Btu/SCF) Sulfur Content (% wt.) Seasonal Fuel Use (% of Annual Use) Actual Reported for Calendar Year Requested Permit Limit Dec -Feb Mar -May Jun -Aug Sep -Nov Natural Gas 11,004 SCF/hr 85.92 MMscf/yr 96.4 MMscf/yr 1,200 BTU/SCF Neg. 25 25 25 25 Is this engine equip )cd with an Air/Fuel ratio controller? ® Yes 0 Section 07 — Emissions Inventory Information & Emission Control Information mission Factor Documentation attached No Data 'ear for actual calendar yr. emissions below & fuel use above (e.g. 2007): 2015 Pollutant Control Device Description Control Efficiency (% Reduction) Emission Factor Actual Calendar Year Emissions2 Requested Permitted Emissions Estimation Method or Emission Factor Source Primary Secondary Uncontrolled Basis Units Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) TSP 1.94E-02 lb/MMBtu 0.94 0.94 1.12 1.12 AP -42 Min 1.94E-02 Ib/MVIMBtu 0.94 0.94 1.12 1.12 AP -42 PM,; 1.94E-02 lb/MMBtu 0.94 0.94 1.12 1.12 AP -42 SOx 5.88E-04 lb/MMBtu 0.03 0.03 0.03 0.03 AP -42 NOx NSCR 82 11.0 g/hp-hr 148.90 27.03 178.45 32.45 Manuf. Spec. VOC NSCR 33 1.5 g/hp-hr 20.30 13.51 24.33 16.22 Manuf. Spec. CO NSCR 75 8.0 g/hp-hr 108.29 27.03 129.73 32.45 Manuf. Spec. Formaldehyde NSCR 76 2.05E-02 lb/MMBtu 0.99 0.24 1.19 0.28 AP -42 Acetaldehyde NSCR 50 2.79E-03 lb/MMBtu 0.14 0.07 0.16 0.08 AP -42 Acrolein NSCR 50 2.63E-03 lb/MMBtu 0.13 0.06 0.15 0.08 AP -42 Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. You will be charged an additional APEN fee if APEN is filled out incorrectly or missing information and requires re -submittal. Annual emission ices will be based on actual emissions reported here. If left blank, annual emission fees will be based on requested emissions. Section 08—Ajlplicant Certification - I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Person Legally Authorized to Supply Data 03 (7_5 2,01G Roshitu Shankaran Environmental Engineer Date Name of Legally Authorized Person (Please print) Title Page 2 of 2 Form APCD-201-RICEAPEN-Ver.02.10.2014.docx NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) Permit Number: Company Name: Plant Location: Person to Contact: E-mail Address: 95OPWE020 DCP Midstream, LP Marla Compressor Station Dana Stephens dstephens@dcpmidstream.com AIRS ID Number: 123 / 0243 / 060 County: Weld Zip Code: Phone Number: Fax Number: 303-605-1745 303-605-1957 Chemical Abstract Service (CAS) Number Chemical Name Control Equipment / Reduction (%) Emission Factor (Include Units) Emission Factor Source Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions (lbs/year) 67-56-1 Methanol 50 3.06E-03 Ib/mmB u AP -42 295.36 147.68 Calendar Year for which Actual Data Applies: 2015 (Z3/Z,0 Signature of Person Legally Authorized to Supply Data Dana Stephens Name of Person Legally Authorized to Supply Data (Please print) Date Rockies Air Permitting Manager Title of Person Legally Authorized to Supply Data Form Revision Date: April 14, 2014 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit— Reciprocating Internal Combustion Engine' "You will be charge an additional APEN fee if APEN is filled out Incorrectly or missing information and requires re -submittal. Permit Number: 950 PWE020 [Leave blank unless APCD has already assigned a permit /I & AIRS ID) Emission Source AIRS ID: 123 I 0243 / 061 Facility Equipment ID: CI76/P 111 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.) Section 01— Administrative Information Company Name: DCP Midstream, LP Source Name: Maria Compressor Station Source Location: SE Sec 28, T4N, R64W Portable Source Home Base: Mailing Address: 370 17th Street, Suite 2500 Denver, CO Person To Rosltinf Shankaran Contact: E-mail Address: rshankaran@dcpmidstrcam.com Section 03 -- General Information For existing sources, operation began on: x Normal hours of source operation: General description of equipment purpose: Date the engine was ordered: NAICS, or SIC Code: 4922 County: Weld Elevation: 4,737 Feet ZIP Code: 80202 Phone Number: 303-605-2039 Fax Number: 303-605-1957 Section 02 — Requested Action (check applicable request boxes) ❑ Request for NEW permit or newly reported emission source ❑ Request for coverage under GENERAL PERMIT number GP02 (Natural Gas Only) ❑ Request MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change permit limit ❑ Change company name ❑ Transfer of ownership ❑ Other Request PORTABLE source permit ❑ Request APEN Update Emissions data must be completed Blank APENs will not be accepted ® Notification of AOS permanent replacement Addl. Info. & AOS engine started up on 11/18/15 Notes: 02 / 2003 For new or reconstructed sources, the projected startup date is: 24 hours/day 7 days/week 52 weeks/year Natural Gas Compression / / 12/2007 Date the engine was relocated into Colorado: n/a Will this equipment be operated in any NAAQS nonattainment area? (ltttp://www.cdphe. state.co.us/ap/attainmai ntain.html) Section 04— Engine Information Engine date of manufacture: 03/27/2008 Manufacturer: Waukesha Date engine construction commenced: Date of any reconstruction/modification: Model: L7044GSI Engine function: ❑ Primary and/or peaking power ® Compression El Pump jack Manufacturer's maximum rated horsepower @ sea level: 1,680 Manufacturer's maximum site rating: 1,680 03/2008 n/a ® Yes ❑ No ❑ Don't know Engine displacement: 9.58 L/cyl Serial No.: C-17976/1 ❑ Emergency back-up power ❑ Water pump ❑ Other: Engine Brake Specific Fuel Consumption @ 100% Load: 7,860 Cycle Type: ❑ 2 -Stroke El 4 -Stroke Ignition Source: ® Spark ❑ Compression BHP @ 1,200 RPM BHP @ 1,200 RPM Btu/HP-hr Combustion: Aspiration: What is the maximum number of hours this engine is used for emergency back—up power? FORM APCD-201 o Lean Burn Natural kW ® Rich Burn Z Turbocharged Hours/year Page 1 of 2 Colorado Department of Public Health and Environment Air Pollution Control Division (APC)) This notice is valid for five (5) years. Submit a revised APEN prior to expiration of five-year term, or when a significant change is made (increase production, new equipment, change in fuel type, etc). Mail this form along with a check for $152.90 per APEN and $1,500 for each general permit registration to: Colorado Department of Public Health & Environment APCD-SS-BI 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Air Pollution Control Division: (303) 692-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 APEN forms: http://colorado.aov/cdohe/APENforms Application status: http://www.colomdo.nov/cdphe/permitstatus ❑ Check box to request copy of draft permit prior to issuance. ❑ Check box to request copy of draft permit prior to public notice. Fonn APCD-201-RICEAPEN-Ver.02.10.2014.docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit— Reciprocating Internal Combustion Engines Permit Number: 95OPWE020 Emission Source AIRS ID: 123 / 0243 / 061 Section 05 — Stack Information (Attach a separate sheet with relevant information in the event of multiple stacks; provide datum & either Lat/Long or UTM) Operator Stack ID No. Stack Base Elevation (feet) Stack Discharge Height Above (feet) Temp. (°F) Flow Rate Velocity li/scc) Moisture CYOWGS84) Horizontal Datum (NAD27, NAD83, UTM Zone (12 or 13) UTM Fasting or Longitude (meters or degrees) UTM Northing or Latitude (meters or degrees) Method of Collection for Location Data (e.g. map, GPS, GoogleEarth) C176/P111 4,737 40 1,152 9,662 205 AMB WGS84 13 538,468.97 4,458,467.15 GPS Direction of stack outlet (check one): ® Vertical Exhaust Opening Shape & Size (check one): ® Circular: Inner Diameter (inches) = 12 ❑ Vertical with obstructing raincap Section 06 — Fuel Consumption Information ❑ Horizontal O Down ❑ Other: Length (inches) = ❑ Other (Describe): Width (inches) = Fuel Type u Fuel Use Rate @100 /o load (SCF/hr, , g al/Iu) Annual Fuel Consumption (gal/yr or MMSCF/yr) Fuel Heating Value al (Btu/lb, Btu/gal, Btu/SCF) g(% Sulfur Content wt.) Seasonal Fuel Use % of Annua Use) Actual Reported for Calendar Year Requested Permit Limit Dec -Feb Mar -May Jun -Aug Sep -Nov Natural Gas 11,004 SCF/hr 84.43 MMscf/yr 96.40 MMscf/yr 1,200 Btu/SCF 0 25 25 25 25 Is this engine equipped with an Air/Fuel ratio controller? ® Yes O No Section 07 — Emissions lnventory Information & Emission Control Information Emission Factor Documentation attached Data year for actual calendar yr. emissions below & fuel use above (e.g. 2007): Pollutant Control Device Description Control Efficiency (% Reduction) Emission Factor Actual Calendar Year Emissions' Requested Permitted Emissions Estimation Method or Emission Factor Source Primary Secondary Uncontrolled Basis Units Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) TSP 1.94E-2 1b/N11VlBtu 0.90 0.90 1.12 1.12 AP -42 PMi0 1.94E-2 lb/MMBtu 0.90 0.90 1.12 1.12 AP -42 PM2.s 1.94E-2 1b/MMBtu 0.90 0.90 1.12 1.12 AP -42 SOx 5.83E-4 lb/MMBtu 0.03 0.03 0.03 0.03 AP -42 NOx NSCR 82 11.0 g/hp-hr 143.6 26.1 178.4 32.4 Manuf. Spec. VOC NSCR 33 1.5 g/hp-hr 19.6 13.0 24.3 16.2 Manuf. Spec. CO NSCR 75 8.0 g/hp-hr 104.4 26.1 129.8 32.4 Manuf. Spec. Formaldehyde NSCR 76 0.0205 Ib/MMBtu 0.95 0.23 1.19 0.28 AP -42 Acetaldehyde NSCR 50 .00279 Ib/MMBtu 0.13 0.065 0.161 0.081 AP -42 Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. You will be charged an additional ADEN fee if AI'EN is filled out incorrectly or missing information and requires re -submittal. 'Annual emission lees will be based on actual emissions reported here. If left blank, annual emission fees will be based on requested emissions. Section 08 —Applicant Certification - I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. 1Zi \ 1lzo1 Signature b -f -Person Legally Authorized to Supply Data Date Roshini Shankaran Environmental Engineer Name. of Legally Authorized Person (Please prilit) Title Page 2 of 2 Form APCD-201-ItICEAPEN-Vcr.02.102014.docx NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) Permit Number: 95OPWE020 Company Name: DCP Midstream, LP Plant Location: SE Sec 28, T4N, R64W Person to Contact: E-mail Address: Marla Compressor Station Roshini Shankaran RShankaran@dcpmidstream.com AIRS ID Number: 123/0243/061 County: Weld Zip Code: Phone Number: Fax Number: 303-605-2039 303-605-1957 Chemical Abstract Service (CAS) Number Chemical Name Control Equipment / Reduction (%) Emission Factor (Include Units) Emission Factor Source Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions (lbs/year) 67-56-1 Methanol 50 3.06E-3 lb/MMBtu AP42 252 126 Iendarear for which Actual Data Applies: 2014 Signature of Person Legally Authorized to Supply Data Roshini Shankaran I?05 Date Environmental Engineer Name of Person Legally Authorized to Supply Data (Please print) Title of Person Legally Authorized to Supply Data Form Revision Date: April 14, 2014 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Glycol Dehydration Unit' Permit Number: 95OPWE020 [Leave blank unless APCD has already assigned a permit # & AIRS !D] Emission Source AIRS ID: 123 / 0243 / 062 Facility Equipment ID: P-112 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01 — Administrative information Section 02 —Requested Action (Check applicable request boxes) Company Name: Source Name: DCP Midstream, LP Marla Compressor Station Source Location: SE Sec 28, T4N R64W Mailing Address: 370 17th Street, Suite 2500 Denver, CO Person To Contact: Roshini Shankaran NAICS, or SIC Code: County: Weld ❑ Change process or equipment 4922 ❑ Request for NEW permit or newly reported emission source ❑ Request MODIFICATION to existing permit (check each box below that applies) ❑ Change company name Elevation: 4,737 Feet O Change permit limit O Transfer of ownership O Other ZIP Code: 80202 Phone Number: 303-605-2039 E-mail Address: rshankaran@dcpmidstream.com Fax Number: 303-605-1957 Section 03 — General information For existing sources, operation began on: Normal Hours of Source Operation: General description of equipment and purpose: ► Is this unit subject to the 90% control requirement of Colorado Regulation No. 7, XVILD (total uncontrolled actual VOC emissions from all dehydration units at this stationary source, including APEN Exempt units,> 15 tons/yr)? ► Will this equipment be operated in any NAAQS nonattainment area? (hitp://www.colorado.gov/cdphe/attainment) ► Is this unit located at a stationary source that is considered a Major Source of Hazardous Air Pollutant (HAP) emissions? Section 04 — Dehydration Unit Equipment information Manufacturer: Model: TEG Dehydration Unit Serial No.: Request to limit HAPs with a Federally enforceable limit on PTE ® Request APEN update only (check the box below that applies) Revision to actual calendar year emissions for emission inventory Update 5 -Year APEN term without change to permit limits or previously reported emissions O Addl. Info. & Notes: 11 ; 2005 For new or reconstructed sources, the projected startup date is: 24 hours/day 7 days/week 52 weeks/year Natural Gas Dehydration Reboiler Rating: 0.6 MMBtu/lir Glycol Used: ® TriEthylene Glycol (TEG) Glycol Pump Drive: ® Electric ❑ Gas Pump Make & Model: 45015PV Glycol recirculation rate (gal/min): Max: Dehy. Gas Throughput: Design Capacity: MMSCF/day Requested': 16,425 O Ethylene Glycol (EG) ❑ DiEthylene Glycol (DEG) If gas, injection pump ratio: # of Pumps: Requested': 6.25 Lean glycol water content: Inlet Gas: Water Content: Flash Tank: Cold Separator: Pressure: psig Stripping Gas: ® None O Use flash gas ❑ Use dry gas: scfm O Use N2: acfln/gpm 1 1.5 wt. % Calendar year actual: 4,547.83 MMSCF/yr. MMSCF/yr. Pressure: 900 psig Temperature: 80 °F Wet Gas: lb/MMscf ® Saturated Dry Gas: 7.0 lb/MMscf Pressure: 125 psig Temperature: 65 °F O °F El Temperature: 'You will be charged an additional APEN fee if APEN is filled out incorrectly or missing information and requires re -submittal. '-Requested values will become permit limitations. Additional Information Required: None None scfm ❑ Attach a process flow diagram O Attach GR1-GLYCaIc 4.0 Input Report & Aggregate Report (or equivalent simulation report/test results) O Attach the extended gas analysis ;including BTEX & n -Hexane, temperature & pressure) Dzi Yes Yes Yes ❑ No LI No ® No ❑ Don't know ❑ Don't know ❑ Don't know Colorado Department of Public Health and Environment Air Pollution Control Division (APCD) This notice is valid for five (5) years. Submit a revised AP EN prior to expiration of five-year term, or when a significant change is made (increase production, new equipment, change in fuel type, etc). - Mail this form along with a check for $152.90 to: Colorado Department of Public Health & Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Air Pollution Control Division: (303) 692-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 APEN forms: http://www.colorado.gov/cdplie/AP EN lbrms Application status: http://www.colorado.eov/cclphe/permitstatus ❑ Check box to request copy of draft permit prior to issuance. ❑ Check box to request copy of draft permit prior to public notice. FORM APCD-202 Page 1 of 2 FormAPCD-202-GlycolDehydrator.APEN-Ver.10-11-2013.docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Glycol Dehydration Unitl Permit Number: 95OPWE020 Emission Source AIRS ID: 123 / 0243 / 062 Section 05 — Stack Information (Combustion stacks must be listed here) Operator Stack ID No. Stack BaseStack Elevation (legit) Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (11/sec) Moisture (%) S-112 4,737 Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Horizontal Datum (NAD27, NAD83, WGS84) UTM Zone (12 or 13) UTM Easting or Longitude (meters or degrees) UTM Northing or Latitude (meters or degrees) Method of Collection for Location Data (e.g. map, GPS, GooglcEarth) WGS84 -104.5475 40.2767 GPS Direction of stack outlet (check one): ® Vertical O Vertical with obstructing mina ) Exhaust Opening Shape & Size (check one): O Circular: Inner Diameter (inches) _ ❑ Horizontal 0 Down 0 Other: Length (inches) = Section 07 — Control Device Information (Indicate if a control device controls the flash tank and/or regenerator emissions) 0 Other (Describe): Width (inches) = Condenser used for control of: Overhead Stream O Combustion Device used for control of: Overhead Stream Rating: MMBtu/hr Type: Make/Model: Type: Enclosed Combustor Make/Model/Serial #: Cimarron Temperature (°F): Maximum: Average: VOC & HAP Control Efficiency: Requested: 95 °!o Manufacturer Guaranteed: Requested VOC & HAP Control Efficiency: % Minimum temp. to achieve requested control: °F Waste gas heat content: Bt/sef ►� VRU used for control of: Flash Stream Constant pilot light? 4 Yes ■ No • Pilot burner rating: MMBtu/hr Size: Make/Model: ■ Closed loop system used for control of: Requested VOC & HAP Control Efficiency: Annual time that VRU is bypassed (emissions vented): 100 % % Description: ■ Describe Any Other: Section 08 — Emissions Inventory Information & Emission Control Information ❑ Emission Factor Documentation attached Data year for actual calendar yr. emissions below & gas throughput above (e.g. 2007): 2015 Pollutant Control Device Description Control Etficizncy (% Reduction) Emission Factor Actual Calendar Year Emissions3 Requested Permitted Emissions Estimation Method or Emission Factor Source Primary Secondary Uncontrolled Basis Units Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) NOx Identify in Section 07 VOC 160.30 Ib/MMscf 287.7 2.58 364.5 2.82 GLYCalc CO Benzene 10.73 Ib/MMscf 13.8 0.69 24.4 0.31 GLYCalc Toluene 41.12 lb/MMscf 9.8 0.34 93.5 0.51 GLYCalc Ethylhenzenc 3.23 lb/MMscf 0.31 9.99E-03 7.34 0.02 GLYCalc Xylene 59.54 lb/MMscf 3.15 0.09 135.4 0.25 GLYCalc n -Hexane 1.39 Ib/MMscf 3.91 0.06 3.15 0.06 GLYCalc Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. 'You will be charged an additional APEN fee if APEN is filled out incorrectly or missing information and requires re -submittal. Annual emission ices will be based on actual emissions reported here. 1 f lclt blank, annual emission fees will be based on requested emissions. Section 09—jplicant Certification - I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Person Legally Authorized to Supply Data - O3(23/2 p( Roshiui Shankaran Environmental Engineer Date Name of Legally Authorized Person (Please print) Title Page 2 oft FormAPCD-202-GlycolDehydratorAPEN-Ver.10-11-2013.docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Glycol Dehydration Unit' Permit Number: 95O PWE020 .[Lcavc blank unless APCD has already assigned a permit N & AIRS ID] .Emission Source AIRS ID: 123 / 0243 Facility Equipment ID: P-113 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01 — Administrative Information. Section 02 — Requested Action. (Check applicable request boxes) Company Name: Source Name: Source Location: DCP Midstream, LP Marla Compressor Station SE Sec 28, T4N R64W Mailing Address: 370 17th. Street, Suite 2500 Deriver, CO NAICS, or SIC Code: County: Elevation: 4922 / 063 ❑ Request for NEW permit or newly reported emission source ❑ Request MODIFICATION to existing permit (check each box below that applies) Weld O Change process or equipment ❑ Change company name 4,737 Feet ❑ Change pennit limit ❑ Transfer of ownership ❑ Other ZIP Code: 80202 Person To Contact: Roshini Shankaran Phone Number: (303) 605-2039 E-mail Address: rshankaran@dcpmidstream.com Section 03 — General Information For existing. sources. operation began on: Normal Hours of Source Operation: Fax Number: (303)605-1957 11 / / 2005 ❑ Request to limit HAPs with a Federally enforceable limit on VIE ® Request APEN update only (check the box below that applies) ❑ Revision to actual calendar year emissions for emission inventory Addl. Info. & Notes: Update 5 -Year APEN term without change to permit limits or previously reported emissions For JIM or reconstructed sources, the projected startup date is: 24 hours/day 7 days/week 52 weeks/year General description of equipment and purpose: Natural Gas Dehydration ► Is this unit subject to the 90% control requirement of Colorado Regulation No. 7, XVILD (total uncontrolled actual VOC emissions from all dehydration units at this stationary source, including APEN Exempt units, ≥ 15 tons/yr)? ► Will this equipment be operated in any NAAQS nonattainmentarca?(_hitp:.'wnw.colorado.uov'cdphelattainmcnl_) ► Is this unit located at a stationary source that is considered a Major Source of Hazardous Air Pollutant (HAP) emissions? Section (14 — Dehydration Unit Equipment Information Manufacturer: Model: TEG Dehydration Unit Serial No.: Rcboilcr Rating: 0.6 MMBtu/hr Glycol Used: ® TriEthylene Glycol (TEG) ❑ Ethylene Glycol (EG) ❑ DiEthylene Glycol (DEG) Glycol Pump Drive: © Electric ❑ Gas If gas, injection pump ratio: acfm/gpm Pump Make & Model: 45015PV €/ of Pumps: 1 Glycol recirculation rate(gal/min): Max: Requested`. 6.25 Lean glycol water content: 1.5 wt.% Doty. Gas Throughput: Design Capacity: MMSCF/day Requested: 16,425 MMSCF/yr. Calendar year actual: 5,310.1 MMSCF/yr. Inlet Gas: Pressure: 900 psig Temperature: 80 'F Water Content: Wet Gas: lb/MMscf ® Saturated Dry Gas: 7.0 Flash Tank: Pressure: 125 psig Temperature: 65 Cold Separator: Pressure: psis Temperature: Stripping Gas: E None ❑ Use flash gas • ❑ Use dry gas: sclin ❑ Use N.,.: '.You will be charged an additional APEN fee if APEN is filled out incorrectly or missing information and requires re -submittal. '.Requested values will become permit limitations. Additional ❑ Attach a process flow diagram Information ❑ Attach GRI-GLYCaIc 4.0 Input Report & Aggregate Report (or equivalent simulation report/test results) Ib/MMscf 'F None None scfnt El El Yes Yes Yes ❑ No ❑ No Z No ❑ Don't know ❑ Don't know ❑ Don't know Colorado Department of Public Health and Environment Air Pollution Control Division (APCD) This notice is valid for five (5) years. Submit a revised APEN prior to expiration of five-year term, or when a significant change is made (increase production, new equipment, change in fuel type, etc). Mail this form along with a check for $152.90 to: Colorado Department of Public Health Sc Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Air Pollution Control Division: (303) 692-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303)692-3175 APEN forms: htlp://www.coloraclo.RoviccIplie,APENforms Application status: hitr,/www.colorado.gov'edplic,perniitsiattis ❑ Check box to request copy of draft permit prior to issuance. FORM APCD-202 Page 1 of 3 2a. Marla (P-113) APEN 2015 03 05.doc AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Glycol Dehydration Unit' _Permit Number: 95OPWE020 _Emission Source AIRS ID: 123 I 0243 / 062 Section 05 — Stack Information (Combustion stacks must be listed hero) Operator Slack ID No. Slack Base Elevation Elevation (feet(feet) Stack Discharge Height Above Ground Level Temp. (°F) Flow Rate (ACFM) Velocity (ft/see) Moisture (%) 5-112 4,737 Section 06 —Stack (Source, itno combustion) Location (Datum & either Lat/Long or UTM) Horizontal Datum (NAD27, NAD83, WGS84) .UTM Zone (12 or 13) .UTM Easting or Longitude (meters or degrees) UTM Northing or Latitude (meters or degrees) Method of Collection for Location Data (e.g. map, GPS, GooglcEartlt) WGS84 -104.5475 40.2767 GPS Direction of stack outlet (check one): ® Vertical ❑ Vertical with obstructing raincap Exltuust Opening Shape & Size (check one): 0 Circular: Inner Diameter (inches) _ ❑ Horizontal 0 Down ❑ Other: Length (inches) _ Section 07 — Control Device Information (Indicate if a control device controls the flash tank and/or regenerator emissions) ❑ Other (Describe): Width (inches) = O Condenser used for control of: Overhead Stream ►Z/ Combustion Device used for control of: Overhead Stream Rating: MMBtu/hr Type: Make/Model: Type: Make/Model/Serial 11: Temperature (°F): Maximum: Average: VOC & 1-IAP Control Efficiency: Requested: % Manufacturer Guaranteed: % Requested VOC & HAP Control Efficiency: % Minimum temp. to achieve requested control: °F Waste gas heat content: Btu/sof I VRU used for control of: Flash Stream Constant pilot light? ■ Yes ■ No Pilot burner rating: MMBlu/Ihr Size: Make/Model: U Closed loop system used for control of: Requested VOC & HAP Control Efficiency: Annual time that VRU is bypassed (emissions vented): 100 % °io Description: in Describe Any Other: Section 08 — Emissions Inventory Information & Emission Control Information ❑ .Emission Factor Documentation attached .Data year for actual calendar yr. emissions below & gas throughput above (e.g. 2007): Pollutant Control Device Description Control Efficiency (% Reduction) Emission Factor Actual Calendar Year Emissions} Requested Permitted Emissions .Estimation Method or Emission Factor Source Primary Secondary Uncontrolled Basis Units Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) NOx Identify in Section 07 VOC 44.38 lb/11411-Iscf 156.4 0.99 364.5 2.82 GLYCale CO Benzene 2.97 lb/MMscf 8.36 0.26 24.4 0.31 GLYCale Toluene 11.39 lb/rvB'lscf 6.30 0.19 93.5 0.51 GLYCulc Ethylbenzene 0.89 lb/M?.bcf 0.32 0.01 7.34 0.02 GLYCale Xylcne 16.49 lb/MMscf 2.80 0.09 135.4 0.25 GLYCalc n-l-lezanc 0.39 lb/MMscf 2.18 0.01 3.15 0.06 GLYCale Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. You will be charged an additional APEN lee if APEN is filled out incorrectly or missing information and requires rc-submittal. Annual emission fees will be based on actual emissions reported here. If Icfl blank, annual emission fees will be based on requested emissions. Se ion 09 —• ►plicant Certification - I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. i Signature of Person Legally Authorized to Supply Data s/6/zois Date Roshini Shanlau•an _Environmental Engineer Name of Legally Authorized Person (Please print) Title Page 2 of 2 2a. Marla (P-113) APEN 2015 03 05.doe Attachment C Facility Wide Emissions Marla Compressor Station Form APCD-102 Company Name: DCP Midstream, LP Source Name: Marla Compressor Station Source AIRS m: 123/0243 Colorado Department of Public Health and Environment Air Pollution Control Division Facility Wide Emissions Inventory Form Ver. April, 2015 Uncontrolled Potential to Emit (PTE) Controlled Potential to Emit (PTE) Cetls,4e (TPV) i IIAP. (Ibe/ye) Criteria (TPY) I HAPs (Ibs/yr) AIRS ID Equipment Deteripaon TSP PM10 PM2.5 002 NOx VOC CO WHO Acetal Acre HZ Tot EB Xyl 0 -Hex Meth 224-ThIP TSP P5,110 P6125 502 NOx VOC CO I HCHO Aeeta; Mrs BZ Tat ED Xyl mile: Meth 224-TMP 123/0243/011 Engine C -148/P-102 1.0 1.0 1.0 0.0 157.0 21.4 ; 114.2 i 2,078 283 267 160 57 3 20 0 310 0 1.0 1.0 1.0 0.0 42.8 14.7 42.8 499 141' 133 80 28 I 10 0 155 0 123/0243/053 Engine C -135/P-103 1.0 1.0 1.0 0.0 157.0 21.4 114.2 i 2,078 283 267 160 57 3 20 0 310 0 1.0 1.0 1.0 0.0 28.5 14.3 42.8 i 499 1411 133 80 28 1 10 0 155 0 123/0243/054 Engine C -151/P-104 1.0 1.0 1.0 0.0 157.0 21.4 114.2 2,078 i 283 267 160 57 3 20 0 310 0 1.0 1.0 1.0 0.0 14.3 10.0 28.5 i 499 141 133 80 28 I 10 0 155 0 12360243/039 Engine G -166/P-109 1.1 1.1 1.1 0.0 178.4 24.3 129.8 2,771 i 323 304 193 65 3 23 0 '754 0 1.1 1.1 1,1 0.0 32.4 16.2 32.4 i 569 1611 152 91 32 1 1I 0 177 0 120/0243/060 Engine C -174/P-110 1.1 1.1 1.1 0.0 178.4 24.3 129.8 2,37) 323 304 183 65 3 23 0 354 0 1.1 1.1 1.1 0.0 32.4 16.2 32.4 i 569 161 152 91 32 1 II 0 177 0 123/0243/061 Engine C -176/P-111 1.1 1.1 1.1 0.0 178.4 24.3 129.8 i 2,371 323 304 183 65 3 23 0 354 0 1.1 I.1 1,1 0.0 32.4 16.2 32.4 i 569 161 , 152 9I 32 1 II 0 177 0 123/0243/062 P-112 TEI3 Dehy 0.0 0.0 0.0 0.0 0.0 364.5 0.0 i 0 0 0 48,800 187,000 14,680 270,800 6,300 0 0 0.0 0.0 0.0 0.0 0.0 2.8 0.0 i 0 0 0 620 1,020 40 500 120 0 0 123/0243/063 P-113 TEO Dehy 0.0 0.0 0.0 0.0 0.0 364.5 0.0 ! 0 0 0 48,800 187,000 14,680 270,800 6,300 0 0 0.0 0.0 0.0 0.0 0.0 2.8 0.0 0 0 ' 0 620 1,020 40 500 120 0 0 ' Permitted Sources Subtotal- APEN Only - Permll Exempt Sources 6.3 6.3 6.3 0.2 10063 866.2 7319 i 13,349 1,817 1,713 98,629 374,363 29,376 541,727 12,600 1,993 0 6.3 6.3 6.3 0.2 183.0 92.8 211.5' 3,204 908 856 1,754 2,22E 88 1,063 240 996 0 i i i i i i I I I I APEN Only Subtotal— APEN Exempt /Insignificant sources 0.0 0.0 0.0 0.0 0.0 0.0 0.0 i 0 0 0 0 0 0 0 0 0 0 0.0 0.0 0.0 0.0 0.0 0.0 I 0.0 i 0 0 I 0 0 0 0 0 0 0 0 Insigdficent Acitines (See List) 0.0 0.0 0.0 0.0 1.2 2.4 2.2 i 0 0 0 14 0 0 0 69 0 0 0.0 0.0 0.0 0,0 1.2 2.4 2.2 i 0 0 0 14 0 0 0 69 0 0 I I I I I i I I Insignificant Subtotal- Total, All Sources= 0.0 0.0 0.0 0.0 1.2 2.4 22 3 0 0 0 14 0 0 0 69 0 0 0.0 0.0 0.0 0.0 1.2 2.4 2.2 e 0 0 0 14 0 0 0 69 0 0 6.3 6.3 6.3 0.2 1007.5 868.6 I 734.0 g 13,349 1,817 11,713190,643 374,363 29,376 541,727 12,669 1,993 0 6.3 6.3 6.3 0.2 184.2 95.2 213.7 j 3,204 9081 856 1,769 2,222 88 1,063 309 996 0 UncontrolledflAPs Summery(TPY)- Uncontrolled Tole), All HAPs Controlled HAPs Summary(TPY1-I Controlled Total, All HAP. 6.7 I 0.9 I 0.9 I 49.3 I 187.2 I 14.7 I 270.9 I 6.3 I 1.0 I 0.0 I 1.6 I 0.5' I 0.4 J 0.9 I I.1 I 0.0 I 0.5 I 0.2 I 0.5 I 0.0 (TPV)- SJ7.8 (TPY) - 5.7 Footnotes: 1. This form should be completed to include both existing sources and all proposed new or modifications to existing emissions sources 2. If the emissions some is new then enter "proposed" under the Permit No. and AIRS ID data columns 3. HAP abbreviations include: BZ = Benzene 224-TMP = 2,2,4-Trimethylpentane Tel = Toluene Acetal = Acetaldehyde BB = Ethylbenzene Acro = Acrolein Xyl = Xylene n -flex = n -Hexane HCHO = Formaldehyde Meth = Methanol 4. APEN Exempt/Insignificant Sources should be included when warranted. STOPN LOADOUT 'ERN', D ❑❑ M-1 MOBILE TANK SHED OVMPSIER GATE FAC00Y OJNrMNMENT BERM t1 M-0171 PRODUCED WATER TX -0176 SIOPDWATER LIGHT SHEDS up'I_I Imo AC ❑ c �OSAL000EB TIME PIPE RACK GLYCOL l � O�SURGE TANK PEBOREN J O t) flIV-0214 T-0102 BERM F SCRUBBERCONTACTpft BERM C ANTENNA e/ OFFICE LET V 60110 0 ❑ BUILDING NEWBOUBNE PIG LAUNCHER TK-1080 TEG/PR000CE0 WATER DRUM USED STORAGE FlTEFRS AREA \� p� a /O TX -1074 USED OIL BERN D LUBE OIL ®m--IX-7NORKOOL =IM -5 TM e-TK-S METHANOL =---TK-50 METWNOL BERM C MCC REV DATE GTE METER RUN FLASH TANK T-0 U CONTACTOR LaJ /F-0202 0-0114 CONE5CER DISCHARGE / .SCRUBBER 4 -BOX S REBOILER/ URGE TANK OTK-0172 STORMWATER V-0150 OSEPARATOR FUEL METER F-0115 V -ZOO FILTER V-250 111-0B50 PRODUCED WATER FACILITY CONTUNMEM BEAN AC -0152 COOLER.. ATM ARKS? UGHT METER -O- V-0117 SLUG CATCHER D TX -1071 STORMWATER STORMWATER TK-1145 LUBE OIL DAY TANK V-0101 MEDMNOL Q / V-0118 I) SEPARATORS PUMP I\ SLUG CATCHER / O METER RUN 11 V-0104 TRANSFORMER COUNTY RD 40 M-1075 0. ---SLOP OIL 01-1072 nc-1155 LUKE OIL DAY TN. USED OIL FILTERS 00 SCRUABOO TK-11S1 LOBE OIL DAY TANK UGHT VRU DAY BMX B TANK gvlig (10105 SCRUBBERS 110 W METER LIGHT 0 SCRUBBERS a� 1K-OSIS PRODUCED BERM A ❑ SH�z WATER CONDENSATE TANKS O (IMBSolI) TK-09-0502 TK-0516 PRODUCED / WATER • u I • w— • � GTE SOUND BARRIER PIG CALI METER ENTERPRISE SPHERE PIG LAUNCHER PLATFORM REV DATE REVISION or 0100 MM. LNCR R: 0 12-12-03 DRAWN FROM PLOT PLAN BY DUKE AND FIELD NOTES P.H.W. R.R. I 5-14-08 REVISIONS PER: P.P.M. DELO SKETCH JA.E R.P.M. 2 6-H-09 BENSONS PER: P.P.M. DEW SKETCH 3 B -I9-10 BENSONS PER: R.P.M. FIELD SKETCH - J.R.E. R.P.M. 4 5-27-1I REVISIONS PER: R.P.N. FIELD SKETCH JR.E R.P.A. LEGEND: -yx- 0 N E FENCE SURFACE WATER DRAINAGE DIRECTION SECONDARY CONTAINMENT BERM ABOVE/BELOW GROUND PIPING DOUBLE WALL STORAGE TANK COUNTY RD 55 PDF 10 SCALE Not.: THM dnwhg 1a hosed an a RMd MAIM and &N.. Ih. lacatlon ond contents of each on contahhg .111041WanotyrneaL and plphg (va reaulrad by 40 CFR 112_71511. Thla Mawhg shout, only be used for SRN Pnvenitan Control and Caontermeavan Plan(SPCC) parpaTBT As 6..715 M not la sooty. actual cantata... aah ..nl a plpina may vary h the and pstUon from Boo. rvssented hen. SPCC PLOT PLAN REVISION BY OBIT ENGR. • 5 6-11-14 REDRAWN FROM CODDLE EARTH Clap Midstream. MARLA COMPRESSOR STATION WELD COUNTY GATHERING SYSTEM Weld County COLORADO \data\EhsDrawin gs\M appIng\Colorado\Weld \Marta _SPCC Attachment E List of Insignificant Activities Marla Compressor Station Insignificant Emissions Marla Compressor Station DCP Midstream, LP NOx CO. • . `; VOC Benzene, n,hexane Description:, ' - Insignificant Per ' (tpy), :- (tpy) - ' t, (tpy) • (Ib/yr) . =,', . '(Ib/yr) ;.'' EP Source 1,000 gal methanol tank Regulation No. 3, Part C, Section II.E.3.a 0.02 --- --- TANKS 4.0.9d 300 bbl methanol tank Regulation No. 3, Part C, Section II.E.3.a -- --- 0.20 -- --- TANKS 4.0.9d 1,000 gal TEG glycol tank Regulation No. 3, Part C, Section II.E.3.a -- --- neg. --- --- 1,000 gal Norkool glycol tank Regulation No. 3, Part C, Section II.E3.a --- --- neg. --- -- 30,000 gal Pressurized Condensate Storage Tank Regulation No. 3, Part C, Section II.E.3.a -- --- neg. --- --- N/A - Not a source of emissions 30,000 gal Pressurized Condensate Storage Tank Regulation No. 3, Part C, Section II.E.3.a --- --- neg. -- --- N/A - Not a source of emissions TK-0173 -10 bbl slop oil tank Regulation No. 3, Part C, Section II.E3.aaa --- --- neg. --- --- TK-8 — 1,000 gal lube oil tank Regulation No. 3, Part C, Section II.E.3.aaa --- --- neg. -- -- TK-8A — 210 bbl lube oil tank Regulation No. 3, Part C, Section II.E3.aaa --- --- neg. --- --- TK-0515 - 80 bbl produced water tank Regulation No. 3, Part C, Section II.E.3.uu --- --- neg. --- --- TK-0516- 80 bbl produced water tank Regulation No. 3, Part C, Section II.E3.uu -- --- neg. --- --- TK-0175 - 80 bbl produced water tank Regulation No. 3, Part C, Section II.E.3.uu -- --- neg. -- --- TK-1080 - 80 bbl TEG/produced water tank Regulation No. 3, Part C, Section II.E3.uu --- --- neg. --- -- TK-0850 - 50 -bbl produced water tank Regulation No. 3, Part C, Section II.E.3.uu --- --- neg. -- -- TK-09-0501 - 710 bbl condensate tank Regulation No. 3, Part C, Section II.E3.a -- --- neg. --- --- TK-09-0502- 710 bbl condensate tank Regulation No. 3, Part C, Section ll.E.3.a --- --- neg. -- --- VRU Day Tank —55 gal lube oil drum Regulation No. 3, Part C, Section II.E.3.aaa --- --- neg. --- --- TK-1074- 80 bbl used oil tank Regulation No. 3, Part C, Section II.E.3.aaa -- --- neg. --- -- Drum Storage Area — 55 gal misc. oil drums Regulation No. 3, Part C, Section II.E.3.aaa -- --- neg. -- --- TK-1148— 85 gal lube oil tank Regulation No. 3, Part C, Section II.E3.aaa --- --- neg. --- - TK-1135-85 gal lube oil tank Regulation No. 3, Part C, Section II.E3.aaa --- --- neg. --- --- TK-1151 — 85 gal lube oil tank Regulation No. 3, Part C, Section II.E3.aaa --- --- neg. --- -- Dehy Day Tank — 55 gal lube oil tank Regulation No. 3, Part C, Section II.E.3.aaa --- --- neg. --- -- TK-1 —500 gal mobile used oil tank Regulation No. 3, Part C, Section II.E3.aaa -- --- neg. -- -- Meter Shed Heaters (x3)-0.01 MMBtu/hr Regulation No. 3, Part C, Section II.E.3.k -- --- neg. -- -- Building Heaters (x2) —0.1 MMBtu/hr Regulation No. 3, Part C, Section II.E.3.k -- --- neg. --- --- Dehy Reboiler H-112 Regulation No. 3, Part C, Section II.E.3.a 0.36 0.30 0.02 -- --- AP -42 Section 1.4, Table 1.4-1 Dehy Reboiler H-113 Regulation No. 3, Part C, Section II.E3.a 0.42 0.35 0.02 -- --- AP -42 Section 1.4, Table 1.4-2 Condenser Combustor Regulation No. 3, Part C, Section II.E.3.a 0.43 1.52 --- --- -- TNRCC Flares and Vapor Oxidizers, Table 4 Flare Factors C-148 vent blowdown Regulation No. 3, Part C, Section II.E.3.a --- --- 0.18 -- --- Engineering Estimate C-135 vent blowdown Regulation No. 3, Part C, Section II.E.3.a --- --- 0.18 --- -- Engineering Estimate C-151 vent blowdown Regulation No. 3, Part C, Section II.E.3.a --- --- 0.18 --- --- Engineering Estimate C-166 vent blowdown Regulation No. 3, Part C, Section II.E.3.a --- --- 0.18 --- -- Engineering Estimate C-174 vent blowdown Regulation No. 3, Part C, Section II.E.3.a -- --- 0.18 -- -- Engineering Estimate C-176 vent blowdown Regulation No. 3, Part C, Section II.E3.a -- --- 0.18 -- -- Engineering Estimate Produced Water Storage Regulation No. 3, Part C, Section II.E3.a --- --- 0.25 13.17 41.38 Engineering Estimate Pressurized Condensate Truck Loadout Regulation No. 3, Part C, Section II.E.3.a --- --- 0.36 -- -- Engineering Estimate Facility Fugitive Emissions Regulation No. 3, Part C, Section II.E.3.a --- --- 0.43 1.21 28.06 EPA Publication No. 453\R-95-017 Table 2-8 Total Insignificant Emissions 1.21 2.18 2.39 14.38 69.44 'There is a blowdown vent for each compressor so each is a separate emission point with estimated emissions of 0.18 tpy VOC each c:11= -1"p - Midstream. March 21, 2019 RECEIVED r.DE G4AR222019 APCD Stationary TpurCeF Ms. Elie Schuchardt Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-Bl Denver, CO 80246-1530 DCP Operating Company, LP 370 17th Street, Suite 2500 Denver, CO 80202 303-605-2039 UPS Label: 1Z F46 915 02 9590 6628 Re: DCP Operating Company, LP; Marla Compressor Station (123/0243) Title V Operating Permit Minor Modification Application (95OPWE020) Natural Gas Compressor Engine C-148 (AIRS 052) Ms. Schuchardt: DCP Operating Company, LP (DCP) is submitting the attached Title V Minor Modification application for the Marla Compressor Station, located in SE Section 28, Township 4N, Range 64W, Weld County, Colorado. DCP is requesting the changes detailed in this application to Title V Operating Permit 95OPWE020. A timely Title V permit renewal application was submitted December 28, 2016 for this facility. This renewal application is currently undergoing review with the Division. A draft Title V permit was issued for DCP review on January 10, 2019. The following is a summary of the changes DCP is requesting in this minor modification application to permit 95OPWE020. Summary of Changes Compressor Engine C-148 (AIRS 052) DCP is requesting a reduced permit limit for controlled NOx emissions from this source. The previous engine C-148 was replaced under AOS provisions in February of 2019. The replacement engine is subject to reduced NOx emission limits under Regulation No. 7, Section XVII.E. This replacement unit was already tested against these lower limits via portable analyzer, and is in compliance. This application serves to correct the existing permit limit in 95OPWE020 to match the lower Regulation 7 limit for this engine. Please see the included Title V permit redlines for the specific updates being requested. This Title V operating permit minor modification application includes the following attachments: A. Responsible Official Certification B. APEN Fees C. Updated APEN (C-148) D. Emission Calculations and Supporting Documentation E. Form APCD-102 F. Redlined Title V Operating Permit 95OPWE020 Conditions If you have any questions or require any additional information about the project, please feel free to contact me at (303) 605-2039 or RShankarana,DCPMidstream.com. Sincerely, DCP Operating Company, LP Roshini Shankaran Senior Environmental Engineer Enclosures Attachment A Responsible Official Minor Modification Certification Marla Compressor Station I have reviewed this Minor Modification application supplied under authority of Regulation No. 3, Part C, Section X (5 CCR 1001-5) in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the proposed modification meets the criteria for use of minor permit modification procedures and request that such procedures by used to process this application. This certification conforms with Regulation No. 3, Part C, Section X.D.3 (5 CCR 1001-5). David M. Jost Vice President of Northern Operations Printed or Typed Name Title 6Oa,v1-1 711- g}-14 3/lG/02Pt4 Signature of Responsible Official Date Attachment B APEN Fees - $191.13 Marla Compressor Station Attachment C Updated APEN Forms C-148 Marla Compressor Station RECEIVED Spark Ignition Engine APEN Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN - updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for spark ignition (e.g. gas -fired) reciprocating internal combustion engines (RICE). If your engine is a compression ignition engine (e.g. diesel -fired) or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. MAR 77 2019 APCD Stationar, Permit Number: 95OPWE020 AIRS ID Number: 123 /0243/052 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Marla Compressor Station Site Location: SE Section 28, T4N, R64W Mailing Address: (Include Zip Code) 370 17th Street Suite 2500 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 4922 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 E -Mail Address2: RShankaran@dcpmidstream.com Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 395021 1 i .vCOLORADO t�.�trsnx Permit Number: 95OPWE020 AIRS ID Number: 123 /02431052 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source O PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,875 must be submitted along with the APEN filing fee. -OR - ❑✓ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment ❑ Change company name O ❑r Change permit limit O Transfer of ownerships O -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacement6 Additional Info ft Notes: Add point to existing permit Other (describe below) 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. s For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 6 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? If yes, provide the Company Equipment Identification No. C-148 / P-102 Yes General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 9/24/2005 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: / /www. colorado. gov/cdphe/ attainment) Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year ❑✓ Yes ❑ No Seasonal use percentage: Dec -Feb: 25% Mar -May: 25% June -Aug: 25% Sept -Nov: 25% Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 (©©�� COLORADO I 2 I lJ.1� Heall ,v8 Fj��tlionn�rrt� Permit Number: 95OPWE020 AIRS ID Number: 123 /0243/ 052 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking Power ❑ Emergency (max. 500 hrs/year) J Compression O Pump Jack ❑ Water Pump ❑ Other: What is the maximum number of hours this engine will be used for emergency back-up power? hours/year Engine Make: Waukesha Engine Model: L7042 GSI Serial Number: 240605 What is the maximum designed horsepower rating? 1,478 hp What is the maximum manufacturer's site -rating? 1,478 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,830 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ❑✓ 4 -Stroke Combustion: ❑ Lean Burn 0 Rich Burn Aspiration: ❑ Natural ❑✓ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes ❑ No If yes, what type of AFRC is in use? 0 OZ Sensor (mV) ❑NOx Sensor (ppm) O Other: Is this engine equipped with a Low-NOx design? ❑ Yes ❑✓ No Engine Dates: What is the manufactured date of this engine? 1 /23/1973 What date was this engine ordered? What is the date this engine was first located to Colorado? 2/16/2009 What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 COLORADO 3 1 tkyarrnen: of Ps.. ficalih S En��s.uwnxn� Permit Number: 95OPWE020 AIRS ID Number: 1 23 /0243/ 052 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.2767 / -104.5475 Operator; Stack ID No. :- . Discharge Height ". Above. Ground Level . (feet) °::.. Temp. F) ,. (° , : Flow Rate . ACFM• (ACFM) Velocity.., t/sec (f. ) .: C-148 25 1,125 6,967 108 Indicate the direction of the Stack outlet: (check one) I]✓ Upward El Horizontal Indicate the stack opening and size: (check one) ❑✓ Circular ® Square/ Rectangle ® Other (describe): Downward Other (describe): Interior stack diameter (inches): Interior stack diameter (inches): 14 ❑ Upward with obstructing raincap Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information .Fuel-Use:Rate-O,100 6 Load" •' - ..... ..,.:.....�.�.r:. .(SCFlhour):��-:;�- . .....::.m -v, ;-Actu . Annual-Fuellise-1 -7,-:•-. -..:w.... • .:. (MMSCFIyear) �. �- �:.:� Re nested Ahnual-Permit Limit:-;:-= 9 ::.:::. (MtY15CFlyear).= 11,347 82.7 99.4 From what year is the actual annual amount? 2018 Indicate the type of fuel used9: n Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) Field Natural Gas Heating value: BTU/scf Propane (assumed fuel heating value of 2,300 BTU/scf) D Landfill Gas Heating Value: BTU/scf OOther (describe): Residue Natural Gas Heating Value (give units): 1,107.20 Btu/scf 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 4 I A COLORADO FcaIlh 5 Enlf:al...1 Permit Number: 95OPWE020 AIRS ID Number: 123 /0243/ 052 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas- Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant • Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.5 SOx NOx NSCR 82% VOC - NSCR 33% CO NSCR 63% Other: NSCR - HAPs Formaldehyde: 76%, Other HAPs: 50% Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2018 .. :.. Criteria Pollutant Emissions inventory. ... .•.. . Requested Annual ,_: _ _e._ : Emission Factor». --: v -.:::v..: Actual Annua(_Ein ssions�° �- _ -.:. m fission t�s�s: c- - Limi .. ,...a..._. ,_ • Uncontrolled - "• .•••• •- :�• "-••- •- _.Basis(., _____.___..____... ,::' ` -.::'Units.:::,.: __:_.._____�.:=�.�Mfg�etc}N��(tons/year)"_; "._. Source_.- =..`�AP=42 `-.,.:�.Emisstons.-: ._ - . " •.. Uncontrolled _...'-Emiss�ons_�._' _._-:.... ._. �—.. Con .._.. ��(tons/yeor)..- . . .. ..... .;'UEmissions�-e.�_..e.� •.__(tons/year)'_ ......._,...._._.._.. Emissions=�,: '--(tonslyear).-�-� ....... _ ....: •.�"",_�:.-.::;�. -•.-----.•-- •• - _._...::_.....:�._ TSP (PM) 1.94E-02 lb/MMBtu AP -42 0.89 0.89 0.98 0.98 PM10 1.94E-02 lb/MMBtu AP -42 0.69 0.89 0.98 0.98 PM2.5 1.94E-02 lb/MMBtu AP -42 0.89 0.89 0.98 0.98 SOx 5.88E-04 Ib/MMBtu AP -42 0.03 0.03 0.03 0.03 NOx 11.0 gap -hr Mfg. 141.68 38.43 156.99 28.54 VOC 1.5 g/hp-hr Mfg. 19.32 12.81 21.41 14.27 CO 8.0 g/hp-hr Mfg. 103.04 38.43 114.18 42.82 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 n Yes ® No lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions Inventory • Chemical Name Chemical Abstract (CAS) ( ) Number • Emission Factor. " . Actual Annual Emissions10 •••. Uncontrolled Basis ' • Units . Source (AP -42, Mfg. etc) Uncontrolled Emissions (pounds/year) Controlled Emissions (pounds/year) Formaldehyde 50000 2.05E-02 lb/MMBtu AP -42 1,875.53 450.13 Acetaldehyde 75070 2.79E-03 tb/MMBtu AP -42 255.26 127.63 Acrolein 107028 Benzene 71432 Other: Methanol 67561 3.06E-03 lb/MMBtu AP -42 279.96 139.98 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 'COLORADO 5I .a+..Enrm,u+,em Permit Number: 95OPWE020 AIRS ID Number: 123 /0243/052 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP02. • 3/21/zoo Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Senior Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: O Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $1,875, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.Rov/cdphe/apcd COLORADO Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 Attachment D Emission Calculations and Supporting Documentation C-148 Marla Compressor Station Engine Emission Calculations Marla Compressor Station DCP Operating Company, LP Waukesha L 7042 GSI Engine C -148/P-102 123/0243/052 4 Stroke, Rich Burn Unit Rating: BSFC: Maximum Heat Input Operating Schedule: Potential FH)/: Maximum Potential Fuel Use: 1,478 hp 7,830 btu/hp-hr 11.57 mmbtu/hr 8,760 hr/yr 1,020 btu/sof 99.4 mmscf/yr Month Fuel Use Heat Value (MMsef/month) (Btu/scf) January 7.54 1115.49 February 6.68 1087.36 March 7.69 1102.07 April 6.70 1098.02 May 6.46 1130.05 June 6.76 1126.54 July 7.17 1098,51 August 7.10 1090.34 September 6.83 1101.58 October 7.33 1078.34 November 6.08 1125.68 December 6.35 1132,39 8.. ,i o o.a'sBOf'a .,_.. ...:,-re. 82.7 1107.20 Criteria Pollutant Emission Calculations Uncontrolled Controlled Pollutant Emission Factors' Potential Emissions (tanlyr) Compliance Factors (Ib/MMBtu) F' kt _ '. Emission Factors` - Potential Emissions (ton/yr) Compliance-«� Factors' (Ib/MMBtu) . n aeg,'p (tanlyr) (ton/yr) NOx 11.0 g/bhp-hr 156.99 _ 3.10 141.68 2.0 g/bhp-hr 28.54 0.84 38,43 VOC 1.5 g/bhp-hr 21.41 0.42 19.32 1.0 g/bhp-hr 14.27 0.28 12.81 CO 8.0 g/bhp-hr 114.18 2.25 103.04 3.0 glbhp-hr 42.82 0.84 38.43 PM ° 1.94E-02 Ib/mmttu 0.98 1.94E-02 0.89 1.94E-02 Ib/mmBtu 0.98 1.94E-02 0.89' SOz° 5.88E-04 lb/mmBtu 0.030 5.88E-04 0.027 5.88E-04 lb/mmStu 0.030 5.88E-04 0.027 ° Uncontrolled emission factors for 110w CO, and VOC from Mfg. h Uncontrolled and Controlled emission factors for PM and SO, from 4 -stroke, Rich -burn (4SRB) engines from AP -42, Chapter 3, Table 3.2-3, (7/00). ° Controlled emission factor for NO: from Colorado Regulation 7 Section XVII.E. This engine was relocated into Colorado on February 16, 2009, which Is after the July 1, 2037 applicability date detailed under this Section. Controlled CO and VOC emission factors converted from Ib/MMBtu compliance factors in Operating Permit 95OPWE020 ° F ''sting permitted comp9ance factors from permit 950PWE020 used for 2018 actual enesHon calculations of Nos CO, and VOC Non -Criteria Reportable Pollutant Calculations Pollutant - HAP Emission factors' - Data Source Uncontrolled Potential Emissions (lb/yr) Uncontrolled Actual Emissions (lb/yr) Control Efficiency % Controlled Potential Emissions (lb/yr) Controlled Actual Emissions (ib/yr) 1,1,2,2-Tetrachloroethane 253E-05 lb/mmBtu EPA 2.56 2.31 50% 1.28 1.16 1,1,2-Trichloroethane 0 1.53E-05 lb/mmBtu EPA 1.55 1.40 50% 0.78 0.70 1,1 Dichloroethane <1.13E-05 lb/mmBfu EPA 0.36 1.03 50% 0.18 0.52 1,2 Dichloroethane <1.13E-05 lb/mmBtu EPA 0.36 1.03 50% 0,18 0.52 1,2 Dichloropropane < 1.30E-05 lb/mmBfu EPA 0.41 1.19 50% 0.20 0,59 1,3 -Butadiene 6.63E-04 Ib/mmBtu EPA 67.21 60.66 50% 33.61 30.33 1,3-Dichloropropene < 1.27E-05 Ib/mm8tu EPA 1.29 1.16 50% 0.64 0.58 Acetaldi:liyde i_ - .' 2.79E-03 Ib/mmBtu EPA 282.85 255.26 - 50% 141.42 127.63 . Acroleln 263E-0316/mmBtu EPA 266.63 240.62 50% 133.31 120.31 Benzene 1.58E-03 Ib/mmBtu EPA 160.18 144.55 50% 80.09 72.28 Carbon Tetrachloride < 1.77E-05 Ib/mmBfu EPA 1.79 1.62 50% 0.90 0.81 Chlerobenzene <1.29E-05 lb/mmBtu EPA 1.31 1.19 50%, 0.65 0.59 Chloroform < 1.37E-05 Ib/mmBtu EPA 1.39 1.25 50% 0.69 0.63 Ethylbenzene < 2.48E -0S lb/mmBtu EPA 2.51 2.27 50% 1.26 1.13 Ethylene Dibromide <2.13E-05 Ib/mmBtu EPA 2.16 1.95 50% 1.08 0.97 Formaldehyde." 2.05E-0216/mmBfu EPA ' 2078.28 1875.53 76% 498.79 450.13 Methanol 3.06E-0316/mmBtu EPA 310.22 279.96 50% 155.11 139.99 Methylene Chloride 4.72E-05 lb/mmBfu EPA 4.18 3.77 50% 2.09 1.88 Naphthalene <9.71E-00 lb/mmBtu EPA 9.84 8,88 50% 4.92 4.44 PAH 1.41E-04 Ib/mmBfu EPA 14.29 12.90 50% 7.15 6.45 Styrene O 1.19E-05 lb/mmBtu EPA 1.21 1.09 50% 0.60 0.54 Toluene 5.58E-04 lb/mmBtu EPA 56.57 51.05 50% 28.28 25.53 Vinyl Chloride c 7.18E-06 lb/mmBfu EPA 0.73 0.66 50% 0.36 0.33 Xylenes(m,p,o) 1.95E-04 lb/mmBtu EPA 19.77 17.84 50% 9.88 8.92 TOTAL 0.0324537 Ib/mmBtu — <3288 <2969 <1103 <997 ° Uncontrolled emission factors from 4 -stroke, Rich -burn (4SRB) anginas frowAP-42. Chapter 3, Table 3.2-3, (7/031 P DCP Operating Company, LP 3/21/2019 Attachment E Form APCD-102 Marla Compressor Station Form APCD-102 Company Name DCP Operating Company, LP Source Name: Marla Compressor Station Source AIRS ID: 123/0243 Colorado Department of Public Health and Environment Air Pollution Control Division Facility Wide Emissions Inventory Form Ver. April, 2015 AIDS ID 1130243/052 123/0243/053 123/0243/054 123/0243059 123/0243/060 1210243/061 121/0141/062 123/0241063 Equipment Description Engine C -148/P-102 Engine C -135/P -Ill Engine C -151/P-104 Engine C -I 66/P-109 Engine C-174/P-110 Engine C -176/P -II I P-112 TEGDehy P-113 TOGDehy Permitted Source Suhlmol OPEN Only-Permll Exempt Sournx • C,nlr,lled Potential to Earn PTE Criteria(TPY) I IIAPs Ibs/yr) Crilerin ITPV) I HAPe (1br/ye) TM' PM10 P012.5 S03 NO, VOC I CO I WHO Metal Aar, 62 Tol ED Xyl n -Ilex Meth 204-T91P TSP POle P00.5 502 NOB VOC CO 111C110 Anlnl Ace, BZ Tol Ell Xyl n -Hex Meth 124-TMP (.D (.0 10 00 1510 21.4 114.2 I{ 2,078 283 26] 160 SJ ] 20 0 IIO 0 10 1.0 1.0 00 28.5 14.1 42.8 199 141 Ill 80 28 I 10 0 155 0 10 1.0 10 00 IS]0 214 114.2 I 20]8 283 007 160 57 I 20 0 310 0 1.0 1.0 1.0 0.0 28.5 14.1 42.8 I 499 141 Ill 60 28 1 10 0 155 0 1.0 1.0 10 00 157.0 21.4 114.2 I 2,078 283 167 I60 5] 3 20 0 310 0 1.0 10 10 00 14.3 10.0 28.5 I 499 141 I]3 80 28 I In 0 155 0 1.1 1.1 1.1 0.0 1]84 24.3 129.8 I 2,171 323 304 IBI 65 1 23 0 " 354 0 I.I I.I 1.1 0.0 102 11.4 324 I 569 161 152 91 32 I II 0 177 0 1.1 1.1 (.1 00 178.4 24.1 129.8 I 2,3]1 ]23 304 1 8 65 1 i] 0 351 0 1.1 1,1 1.1 0.0 16.3 11.4 32.9 I 569 161 152 91 32 1 II 0 177 0 1.1 1.1 1.1 0.0 1784 24,3 129.8 I 2,371 323 304 183 65 3 21 354 0 1.I 1.1 1.1 00 324 16.2 12,4 A 569 161 )52 91 32 1 II 0 177 0 0.0 0.0 00 0.0 0.11 455.51 063 I 0 0 0 44,041 67,470 1619 48,894 30,316 0 0 0.0 00 0.0 0.0 0.10 1062 061 I 0 0 0 1,191 5.044 157 7,371 320 0 0 0.0 0.0 00 00 0.19 300.24 0.87 I 0 0 0 56.441 86.867 1.891 61,211 10,3]9 0 0 00 00 0.0 0.0 0.19 14.26 087 I 0 0 0 1,266 6,611 161 4.904 02] 0 0 63 6.3 63 0.I 1006.6 893.0 1333 I 13,049 1,811 1,711 101,511 154,)01 1,528 114231 25,815 1991 0 63 63 6.3 0.E 116.6 1013 015.0 I 3,004 908 856 7370 11,867 645 8,738 ]4E 996 0 APEX Only Snblolol OPEN Exempt /Insignificant sonreee 0,0 0,0 0.0 0.0 I 0 0 loo 0.0 0.0 0,0 0,0 I 0 Insignificant Acilives (See List) 00 0.0 0.0 00 0.7 12.0 06 I 0 91 0 480 152 0.0 00 0.0 0.0 07 120 06 0 0 91 0 480 152 laalenifscaal S,blutd - 0.0 0.0 0.0 0.0 0.7 12.0 0.6 0 91 0 460 612 0.0 0.0 00 0.0 0.7 12.0 0.6 I 0 0 91 0 480 151 Toial, All Sources- 6.3 6.3 6.1 0.1 100,3 905.0 733.9 : 11,349 1,817 1,713 101601 154,701 7,510 111,131 I 26395 1,145 0 6.3 63 6.1 0.1 1373 114.1 1136 3,104 908 856 8,063 11,867 645 8,718 1,113 1,149 Uncontrolled HAP, Summary (TPY) 4 6.7 I 0.9 I 0.9 I 50.6 I 77,4 I 08 I 56,1 I 33.1 I 1,1 I 0.0 Uncontrolled Total, All HAPe (TPY) `I 110,7 I Footnotes: I. This form should be completed to include both existing sources and all proposed new or modifications to existing emissions sources 2. If the emissions source is new then enter "proposed' under the Permit No. and AIRS ID data columns 3. HAP abbreviations include: OZ = Benzene 224-TMP = 2,2,4-Trimethylpenlone Tol =Toluene Acetal —Acetaldehyde ED = Ethylbeozene Acro — Acrolein Xyl= Xylene n-Hex=n-Hexane HCHO=Formaldehyde Meth= Methanol 4. APED Exempt/Insignificant Sources should be included when warranted, Controlled RAPS Summary (TPY)4 1.6 I 0.5 I 0.4 I 4.0 I 5.9 10.3 I 4.4 I 0.6 I 0.6 I 00 Controlled Total, All OAPs (TOY). 181 Attachment F Proposed Updates to Operating Permit 95OPWE020 Marla Compressor Station SECTION II - Specific Permit Terms 1. C-148/135/151 — Three Waukesha L-7042 GSI, 1,478 HP Engines w/ NSCR (AIRS ID: 052/053/054) C-166/174/176 — Three Waukesha L-7044 GSI, 1,680 HP Engines w/ NSCR (AIRS ID: 059/060/061) Permit Condition Number Limitations Compliance Emission Factor Recordkeeping and Twelve Month Rolling Total Calculation Monitoring Interval Emission & Consumption Limits 052 C 118, Waukesha 1,178 HP Natural Gas Fired Internal Combustion Engine NOx GO 12.8 tons/year 0.81 lb/MMBtu 12.8 tons/y ar 0.81 lb/ MMBtu VOC 44 11.3 tons/y ar 0.28 lb/ MMBtu Monthly Natural Gas Consumption 99.1 MMSCF/year Fuel Mctcr, Twelve Month Rolling Total Monthly Emission & Consumption Limits 052, 053 — C-148, C-135, Waukesha 1,478 HP Natural Gas Fired Internal Combustion Engines NOx CO 1.1 28.5 tons/year 0.56 lb/ MMBtu 42.8 tons/year 0.84 lb/ MMBtu VOC 1.2 14.3 tons/year 0.28 lb/ MMBtu Recordkeeping and Twelve Month Rolling Total Calculation Monthly Natural Gas Consumption 1.3 99.4 MMSCF/year Fuel Meter, Twelve Month Rolling Total Monthly Emission & Consumption Limits 054— C-151, Waukesha 1,478 HP Natural Gas Fired Internal Combustion Engine NOx CO 1.1 14.3 tons/year 0.28 lb/ MMBtu 28.5 tons/year 0.56 Ib/ MMBtu VOC 1.2 10.0 tons/year 0.20 Ib/ MMBtu Recordkeeping and Twelve Month Rolling Total Calculation Monthly Natural Gas Consumption 1.3 99.4 MMSCF/year Fuel Meter, Twelve Month Rolling Total Monthly 5/22/2019 State.co.us Executive Branch Mail - Facility -Wide Inventory for Marla STATE OF COLORADO Schuchardt - CDPHE, Elie <elie.schuchardt@state.co.us> Facility -Wide Inventory for Marla 3 messages Schuchardt - CDPHE, Elie <elie.schuchardt@state.co.us> To: "Cameron, Marie E" <MECameron@dcpmidstream.com> Hi Marie, Tue, May 7, 2019 at 11:03 AM I think there might be a mistake on the facility -wide inventory (form APCD-102) that was sent in with the 3/21/2019 Marla minor mod. For engine C-166 (AIRS 059), I think both the controlled PTE numbers for NOx and VOC are lower than they should be. This might be just a copy/paste error with engine C-174 below, but I did want to double check with you and make sure I've got the correct limits in the permit (I've got 32.4 tpy NOx and 16.2 tpy VOC). Let me know! Thanks so much, Elie Schuchardt Permit Engineer Title V Operating Permit Unit Stationary Sources Program Air Pollution Control Division P 303.692.6332 4300 Cherry Creek Drive South, Denver, CO 80246-1530 elie.schuchardt@state.co.us I www.colorado.gov/cdphe/aped COLORADO Air Pollution Control Division Department of PF.ibltc Health & Environment Are you curious about ground -level ozone in Colorado? Visit our ozone webpage to learn more. Cameron, Marie E <MECameron@dcpmidstream.com> Wed, May 8, 2019 at 2:27 PM To: "Schuchardt - CDPHE, Elie" <elie.schuchardt@state.co.us> Elie- It seems like there was an error, please see the attached APCD-102 form that has been corrected. Marie Cameron Senior Environmental Engineer DCP Midstream 370 17th Street Suite 2500 Denver, CO 80202 P: (303) 605-2029 M: (720) 384-3893 https://mai l.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=al l&permth id=thread-a%a3Ar-959141575845167808&sim pl=msg-a%3Ar-728320396... 1/2 5/22/2019 State.co.us Executive Branch Mail - Facility -Wide Inventory for Marla F: (303) 446-4127 mecameron@dcpmidstream.com [Quoted text hidden] *** WARNING: This email originated from outside of DCP Midstream. Do not click links or open attachments unless you recognize the sender and know the content is safe. Safety and security starts with each of us.*** Form APCD-102 (corrected).pdf 236K Schuchardt - CDPHE, Elie <elie.schuchardt@state.co.us> Thu, May 9, 2019 at 6:45 AM To: "Cameron, Marie E" <MECameron@dcpmidstream.com> Perfect - thanks for checking! And thank you so much for the updated inventory! I'll get this scanned in to our records. Elie Schuchardt Permit Engineer Title V Operating Permit Unit Stationary Sources Program Air Pollution Control Division P 303.692.6332 4300 Cherry Creek Drive South, Denver, CO 80246-1530 elie.schuchardt@state.co.us I www.colorado.gov/cdphe/apcd :COLORADO I Air Pollution Control Division Department of Public Health & Eneironment Are you curious about ground -level ozone in Colorado? Visit our ozone webpage to learn more. [Quoted text hidden] https://mai l.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permthid=thread-a%3Ar-959141575845167808&simpl=msg-a%3Ar-728320396... 2/2 Form APCD-102 Company Name: DCP Operating Company, LP Source Name: Marla Compressor Station Source AIRS ID: 123/0243 Colorado Department of Public Health and Environment Air Pollution Control Division Facility Wide Emissions Inventory Form Ver. April, 2015 AIRS ID Equipment Description 123/0243/052 123/0243/053 123/0243/054 123/0243/059 123/0243/060 123/0243/061 123/0243/062 123/0241/063 Engine O148/P-102 Engine C115/P-103 Engine C-I51/P-104 Engine C -166/P-109 Engine Cl74/P-110 Engine C-i]6/P-III P-112 TOG Dehy P-113 TED Dchy Permitted Source. Subtotal — APEN Only. Permit Exempt S.urae0 Controlled Potential to Evdt (PTE Coital. (17•11 I HAPs Ilm/yr) Criteria (Tell I HAN(Ibe/yr) TSP PM10 PM2.5 502 NO0 VOC CO i IICHO Asel.l Oars 02 Tol EU Xyl n -Her Meth 224,13414TSP PMIO PM2.5 502 HOs VOC CO i 11040 Metal Acre 82 Tel En Xyl n -Her Meth 224-TMP 1.0 10 1.0 Q.0 157.0 211 1141 I 2,028 283 26] 160 St 3 20 0 310 0 1.0 1.0 10 0.0 26.5 14.0 42.6 1 499 141 Ill 80 28 I 10 0 155 0 l.0 1.0 1.0 D.0 157.0 21.4 114.2 I 2,074 283 267 160 57 3 20 0 310 0 1.0 1.0 1.0 0.0 21.5 14.3 42.8 I 499 141 133 80 28 I 10 0 155 0 1.0 1.0 1.0 0.0 157.0 21.4 114.2 l 2,078 283 267 160 5] 3 20 0 310 0 1.0 1.0 1.0 OO 14.3 10.0 283 I 499 141 133 80 28 I 10 0 III 0 1.1 1.1 1.1 0.0 178.4 24.3 1298 1 2,371 323 304 183 65 3 23 0 354 0 1.1 1.1 1.1 0.0 32.4 161 3'_4 i 569 161 152 91 32 I II 0 177 0 1.1 1.1 1.1 U.0 1]6.4 24.3 129.8 I 2,171 300 304 IBJ 65 3 23 0 354 0 1.1 1.1 1.1 0.0 16.2 11.4 12.4 I 369 161 152 91 12 I II 0 177 0 I.I 1.1 1.1 0.0 1764 243 129.8 i 2,371 323 304 183 65 3 23 0 354 0 1.1 1.1 1.1 0.0 32.4 16.2 32.4 i 569 161 152 91 32 1 11 0 177 0 0.0 0.0 0.0 0.0 0.13 455.51 0.61 0 0 0 44,041 67,470 3,619 48,894 15,436 0 0 0.0 0.0 0.0 0.0 0.13 10.62 0.61 i 0 0 0 3,191 5,044 277 3,771 320 0 0 00 0.0 0.0 0.0 0.19 300.24 i 0.47 0 0 0 56,441 06.067 3,093 63,211 10,379 0 0 0.0 0.0 0.0 0.0 0.19 1426 0.47 i 0 0 0 4,266 6,641 361 4,904 423 0 0 6.3 6.3 6.3 0.2 1006.6 093.0 1 733.3 I 13349 1,817 1,713 101,511 154,701 7,328 112,231 25,815 1,993 0 63 63 6.3 0.2 152.8 107.2 213.0 I 3,204 908 056 7,972 11,567 645 8.738 742 996 0 APEN Only Subtotal - APEN Exempt / Insignificant worm 0.0 0.0 0.0 0.0 0.0 to 0.0 0 0 0 0 0.0 0.0 0.0 0.0 0.0 I 0 0 0 0 Insignificant 90/1/0cs (Sac List) 0.0 0.0 0.0 0.0 0.7 12.0 0.6 0 91 0 480 153 0.0 0.0 0.0 0.7 12.0 0.6 1 0 0 91 0 480 152 Iaslgolaeant Subtotal- 0.0 0.0 0.0 0.0 0.7 52.0 0.6 ! 0 0 91 0 0 480 152 0.0 0.0 0.0 0.0 0.7 12.0 0.6 0 0 0 91 0 0 0 450 152 Total. An Severn - 63 63 63 0.2 10073 905.0 733.9 ! 13349 1.817 1.713 100,602 154,701 7,528 112331 26395 2,145 63 63 63 0.2 153.5 119.2 213.6 ! 3,204 908 856 8.063 11,867 645 8.738 1,223 1,149 0 Uncontrolled HAP. Summary MY) -1 6.7 I 0.9 I 0.9 I 50.8 I 77.4 I 3.8 I 56.1 I 13.1 I 1.1 I 0.0 Unwotroued Tol.l. AO RAPS frel0-I 2103 f ComroBed HAP. Sunuo.ry(TPYI=I 1.6 I 03 I OA I 4.0 I 5.9 I 03 I 4.4 I OA I 0.6 I OA Controlled Total. Au HAP. (TM -I 183 I Footnotes: 1. This fonn should be completed to include both existing sources and nil proposed new or modifications to existing emissions sources 2. If the emissions source is new then enter "proposed" under the Permit No. and AIRS ID data columns 3. HAP abbreviations include: BZ = Benzene 224-TMP = 2,2,4-Trimethylpentane Tol= Toluene Arafat = Acetaldehyde EB = Ethylbenzene Acro m Acrolein Xyl = Xylene n -Hen = n -Hexane HCHO = Formaldehyde Meth = Methanol 4. APEN EzempUlnsignifieant Sources should be included when warranted. C p Midstream DCP Operating Company, LP 370 17th Street, Suite 2500 Denver, CO 80202 303-605-2039 July 20, 2018 Sent via UPS Tracking No.: IZ F46 915 02 9329 1653 Ms. Elie Schuchardt Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-Bl Denver, CO 80246-1530 Re: DCP Operating Company, LP; Marla Compressor Station (123/0243) Title V Operating Permit Modification (95OPWE020) P-112 Natural Gas Dehydrator (AIRS 062) P-113 Natural Gas Dehydrator (AIRS 063) C-176 RICE (AIRS 061) Ms. Schuchardt, DCP Operating Company, LP (DCP) is submitting the attached Title V Modification application for the Marla Compressor Station, located in SESE Section 28, Township 4N, Range 64W, Weld County, Colorado. DCP is requesting the changes to Title V Operating Permit 95OPWE020 detailed in this application. A timely renewal application for this facility was submitted December 28, 2016. This renewal application is currently undergoing review with the state. DCP submitted a minor modification application for Operating Permit 95OPWE020 on October 10, 2017, requesting various changes to units P-112 and P-113, including an annual 3.0% control device downtime for the shared enclosed combustor, increased natural gas throughput for unit P- 113, and an increase in the maximum compliance temperature for the condenser used for still vent emissions control for both dehydrators from 140 °F to 160 °F. This modification application requests the removal of the condenser as a primary control device. The condenser itself will not be removed from the facility, but DCP will no longer claim any emission control from the condenser for still vent emissions from either unit P-112 or P-113. The removal of this condenser as a primary control device, along with the associated monitoring and recordkeeping requirements from Operating Permit 95OPWE020, constitutes a significant change in existing monitoring permit limits and conditions for units P-112 and P-113 and this Title V modification is considered significant as a result. DCP has included Colorado Title V Operating Permit forms detailing the specific changes requested in this modification application, along with an updated Compliance Assurance Monitoring (CAM) plan for both units. Additionally, compressor engine C-176 is currently out of compliance with federal New Source Performance Standard (NSPS) Subpart JJJJ performance testing and notification requirements. This engine is fully in compliance with all emission limitations under this Subpart. As part of this application, DCP is submitting a compliance schedule to bring this unit back into compliance with these federal requirements. Summary of Changes • P-112 & P-113 Triethylene Glycol Dehydration Units (AIRS 062 & 063) o Remove the listed condenser as a primary control device for these two AIRS points. Retain the enclosed combustor used for still vent emission control from these two points as the primary control device. • Increase controlled VOC emission limit for P-112 from 8.49 tpy to 10.62 tpy. • Increase controlled VOC emission limit for P-113 from 12.25 tpy to 14.26 tpy. o Update the monitoring and recordkeeping requirements in Operating Permit 95OPWE020 to reflect removal of the condenser as a primary control device. o Update the CAM plan for units P-112 and P-113 to reflect removal of the condenser as a primary control device. • C-176 Waukesha L-7044 Natural Gas Compressor Engine (AIRS 061) o Submit compliance schedule for resolving NSPS Subpart JJJJ non-compliance. No other changes requested as part of this modification application. • Insignificant Activities o DCP is providing an updated list of insignificant activities at this facility as part of this application. APEN and permit exemption citations are included with the updated lists in Attachments D and E, and emissions have been estimated where applicable. Please note that maximum possible operation (while remaining APEN and permit exempt) for activities claiming emission -related exemptions has been assumed to provide a conservative look at potential emission increases from these insignificant activities. Federal Regulatory Applicability • Subpart HH—National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities o Units P-112 and P-113 at this facility are subject to the area source provisions of MACT Subpart HH. There are no changes in the applicable requirements under this subpart for either unit, based on the changes proposed in this Title V Modification application. • Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines o Engine C-176 is subject to applicable requirements under Subpart JJJJ, including emission limitations, required performance testing, recordkeeping and reporting. A compliance plan is included in Attachment E to detail the compliance schedule for this unit. State Regulatory Applicability • Regulation 7, Section XII. Volatile Organic Compound Emissions from Oil and Gas Operations o P-112 and P-113 are subject to the emission reduction requirements, control device operation requirements, and associated monitoring, recordkeeping, and reporting requirements under Colorado Regulation 7, Section XII. DCP will continue to meet all applicable requirements under this section. • Regulation 7, Section XVII. (State Only, except Section XVII.E.3.a. which was submitted as part of the Regional Haze SIP) Statewide Controls for Oil and Gas Operations and Natural Gas -Fired Reciprocating Internal Combustion Engines o Both units are subject to the state -specific emission reduction and control requirements under Colorado Regulation 7, Section XVII. Specifically, the emission reduction requirements under Regulation 7, Section XVII.D require at least a 95% reduction in actual emissions of hydrocarbons. The attached calculations in Attachment D of this application show that DCP will continue to meet this requirement without the additional control provided by the condenser. • There are no changes in state regulatory applicability for engine C-176. DCP will continue to comply with all applicable state requirements for this engine. PSD/NNSR Applicability Marla Compressor Station is located in Weld County. Weld County is currently attainment or unclassifiable for all criteria pollutants with the exception of the 2008 8 -hour ozone standard. A major source in an ozone nonattainment area is a source with a PTE of 100 tpy or more of NOX or VOC. Marla Compressor Station has potential emissions of both NOX and VOC above these thresholds and is considered an existing major stationary source. NNSR is required for major modifications at existing major stationary sources, which are modifications that cause a significant increase in a regulated NSR pollutant. Significant increases in emissions are generally determined by a comparison of either the potential emissions or projected actual emissions from a modification, minus the baseline actual emissions from the modified sources. DCP has conservatively compared the revised potential emissions from the modified sources in this application directly against the Significant Emission Rates (SER) in Colorado Regulation 3, Part D, Section II.A.44, without subtracting actual baseline emissions. As seen below in Table 1, the sum of the updated potential emissions from modified sources does not exceed any SER. This project therefore could not meet the definition of a major modification and no further requirements under the NNSR program apply at this time. Table 1— Project Potential Emissions Potential Emissions AIRS ID Equipment Description NO), (tpy) VOC (tpy) CO (tpy) PM (tpy) 123/0243/062 P-112, 45 MMscfd TEG Dehy 0.13 10.62 0.61 - 123/0243/063 P-113, 55 MMscfd TEG Dehy 0.19 14.26 0.87 - N/A Insignificant Activities 0.69 12.01 0.58 - Total Project Potential Emissions Ambient Air Impact Analysis Thresholds New Source Review Thresholds Trigger New Source Reviews Trigger Modeling? 1.01 36.89 2.06 0.00 40 — 100 5 40 40 100 10 Highest Individual HAP Total HAP 5.9 tpy tpy 18.3 Marla Compressor Station is a synthetic minor source of criteria pollutants (NOx, SO2, VOC, CO, PM, PMio, PM2.5) with respect to PSD permitting (i.e., emissions < 250 tpy) and will remain a synthetic minor source after the emission increases described above. Therefore, Marla is not subject to PSD review at this time. This Title V Operating Permit modification application includes the following attachments: A. APEN Fees B. Modified APENs (P-112, P-113) C. Existing (Unmodified) APENs (C-148, C-135, C-151, C-166, C-174, C-176) D. Emission Calculations and Supporting Documentation E. Colorado Title V Operating Permit Forms F. Facilitywide Emission Summary - Form APCD-102 G. Updated O&M Plan (P-112, P-113) H. Facility Plot Plan I. Updated Compliance Assurance Monitoring (CAM) Plan If you have any questions or require any additional information about the project, please feel free to contact me at (303) 605-2039 or RShankaran@DCPMidstream.com. Sincerely, DCP Operating Company, LP (45) Roshini Shankaran Environmental Engineer Enclosures JUL 232018 Glycol Dehydration Unit APEN - Form APCD-202i, Air Pollutant Emission Notice (APEN) and Application for Construction Permit Alt sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Glycol Dehydration (Dehy) Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE020 AIRS ID Number: 123 / 0243 / 062 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: P-112 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Marla Compressor Station Site Location: SESE Sec 28, T4N, R64W Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 E -Mail Address2: RShankaran@DCPMidstream.com Site Location County: Weld NAICS or SIC Code: 4922 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 'Please'use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-202 - Glycol Dehydration Unit APEN - Revision 02/2017 385463 COLORADO 1I tx xw.na cnm n..m Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 062 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source - OR • MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit El Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) - OR APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: TEG dehydration unit for water removal Facility equipment Identification: For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: P-112 11 / / 2005 / / ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Is this unit located at a stationary source that is considered a Major Source of (HAP) Emissions Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 ❑✓ days/week Yes Yes El ❑✓ weeks/year No No 2 IAy LD COORAO oepaxmnxm D HPNN fi F viweuiwrt� Permit Number: 95OPWE020 AIRS ID Number: 123 /0243/ 062 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: Dehydrator Serial Number: Ethylene Glycol DiEthylene Glycol Glycol Used: ❑ (EG) El (DEG) Glycol Pump Drive: 0 Electric ❑✓ Gas If Gas, injection pump ratio: Custom Custom Model Number: TEG Dehydration Unit Reboiler Rating: 0.85 Pump Make and Model: Kimray 45015 0 MMBTU/hr TriEthylene Glycol (TEG) 0.08 Acfm/gpm 1 # of pumps: Glycol Recirculation rate (gal/min): Max: 6.25 Lean Glycol Water Content: 1.0 Wt.% Requested: 6.25 Dehydrator Gas Throughput: Design Capacity: 45 MMSCF/day Requested: 16,425 MMSCF/year Actual: 3,816 MMSCF/year Inlet Gas: Pressure: 1,000 Water Content: Wet Gas: Flash Tank: Pressure: 45 Cold Separator: Pressure: Stripping Gas: (check one) 0 None ❑ Flash Gas ❑ Dry Gas ❑ Nitrogen Flow Rate: scfm psig Temperature: lb/MMSCF 0 Saturated Dry gas: 7.0 lb/MMSCF psig Temperature: 100 °F 0 NA psig Temperature: °F❑ NA 106 °F Additional Required Information: 0 Attach a Process Flow Diagram Q Attach GRI-GLYCalc 4.0 Input Report a Aggregate Report (or equivalent simulation report/test results) ❑✓ Attach the extended gas analysis (including BTEX Ft n -Hexane, temperature, and pressure) Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 ''COLORADO 3 MW„„ YenTeN Permit Number: 95OPWE020 AIRS ID Number: 123 /0243/ 062 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.2767, -104.5475 PIA w3P 4 tY6 •eio-n�rcb{�.�'�te'��CICrI Nl1Y! 1 n i�I� r�re-e. ?eaas4�f`Et AboG du �{ e e - ve nd s �.� t'n.� h t- a -:t a �, "�.t�fhC h u(te,'-i tires- s.�°-t•,+s�...�s F. 7emp�104 w.af' r s x x rrir�''^s �'�+� Sfg �rci"'5� e� ii(.�jF}: {I `"�L,� :4:., _>i _.,.�C -,'� ,_„° x...,r.t'. Ratel6cr n rir I3 �: f �k f'�"'�`� : s. EJ iF� sri•.:S �k �'�....ti z �°`.��k ,) ,><�. K₹" �.-s 'S�n.'�(�t�$ �1 „--.,1 4is ';`tlk .<. r_,.1+.,�<. S-112 Indicate the direction of the stack outlet: (check one) EJ Upward ❑ Horizontal El Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): ❑ Upward with obstructing raincap ❑ Square/rectangle Interior stack width (inches): Interior stack depth. (inches): ❑ Other (describe): Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 QQ COLOR ADO 4 I L�, m� ero-��,�. Permit Number: 95OPWE020 AIRS ID Number: 123 /0243/ 062 [Leave blank unless APCD has already assigned a permit # and MRS ID] Section 6 - Control Device Information ❑ Condenser: Used for control of: Type: Make/Model: Maximum Temp Average Temp Requested Control Efficiency ❑� VRU: Used for control of: Flash Tank Vapors Size: Make/Model: Requested Control Efficiency 1 00.0 % VRU Downtime or Bypassed 0.0 ❑ Combustion Device: * Used for control of: Still Vent Stream Rating: MMBtu/hr Type: Enclosed Combustor Make/Model: Cimarron Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: 95.0 98.0 Waste Gas Heat Content Btu/scf Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating 0.05 MMBtu/hr Closed ❑ Loop System: Used for control of: Description: System Downtime O Other: Used for control of: Description: Control Efficiency Requested 0 * ECD combustion device used for still vent control has a 3.0% annual downtime for maintenance and repairs. Still vent emissions will vent to atmosphere during periods of ECD downtime. Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 grCOLORADO PM Permit Number: 95OPWE020 AIRS ID Number: 123 /0243' 062 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 2 Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Overall Requested Control Efficiency (% reduction in emissions) Sox NOx CO VOC Vapor Recovery Unit / Enclosed Combustor 100% /95% HAPs Vapor Recovery Unit / Enclosed Combustor 100% / 95% Other: From what year is the following reported actual annual emissions data? 2017 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission actor Emission•; Factol _,Units.:, Emission actor Source _, (AP -42, . _ .Mfg. etc).. c a atlua n�..c..� -� is o s Be j i�₹e i Isam ua11'e�mT -- Al liOrbtrPitDcl . (Tons/yea"r) Controlled5 .f (Tons/year): , Uncontrolled ,-- (Tons/yea). ,Controlled° :(Tons/year),: PM SOx NOx 0.068 lb/MMBtu AP -42 -- - 0.13 0.13 CO 0.31 lb/MMBtu AP -42 -- -- 0.61 0.61 VOC 55.5 Ib/MMscf GLYCaIc 165.02 1.28 455.51 10.62 Benzene 2.7 Ib/MMscf GLYCaIc 6.83 0.25 22.02 1.60 Toluene 4.1 lb/MMscf GLYCaIc 6.64 0.21 33.74 2.52 Ethylbenzene 0.2 Ib/MMscf GLYCaIc 0.28 0.01 1.81 0.14 Xylenes 3.0 lb/MMscf GLYCaIc 2.67 0.06 24.45 1.89 n -Hexane 0.9 lb/MMscf GLYCaIc 2.49 0.03 7.72 0.16 2'2'4 Trimethylpentane 0.005 lb/MMscf GLYCaIc neg. neg. 0.04 0.001 Other: a Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 COLORADO 6 I H.alth entclPuttic LLiiiiAA.- : Hwtthbxnrwn, nU Cr, Permit Number: 95OPWE020 AIRS ID Number: 123 /0243/ 062 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Legally Authorized Person (not a vendor or consultant) Roshini Shankaran lIZON Date Senior Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: 0✓ Draft permit prior to issuance �✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 Q COLORADO HW(h6Enrvvmune.x Glycol Dehydration Unit APEN - Form APCD-202 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Glycol Dehydration (Dehy) Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/cdphe/apcd. This -emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE020 AIRS ID Number: 123 / 0243 / 063 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: P-113 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Marla Compressor Station Site Location: SESE Sec 28, T4N, R64W Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 E -Mail Address2: RShankaran@DCPMidstream.com Site Location County: Weld NAICS or SIC Code: 4922 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via a -mail to the address provided. • RECEIVED Form APCD-202 - Glycol Dehydration Unit APEN - Revision 02/2017 JUL 2 3 Z01B APCD Stationary Snurces COLORADO 1 I Av Dapa.martearrw xwo s snwxmm«u 385464 Permit Number: 95OPWE020 AIRS ID Number: 123 /0243/ 063 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source -OR - 0 MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit El Transfer of ownership3 ❑ Other (describe below) - OR O APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: TEG dehydration unit for water removal Facility equipment Identification: For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: P-113 11 / / 2005 / / Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Is this unit located at a stationary source that is considered a Major Source of (HAP) Emissions Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 days/week Yes Yes weeks/year No No 2 A�"� COLORADO - °ep"""'mxorromm Permit Number: 95OPWE020 AIRS ID Number: 123 /0243/ 063 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: Dehydrator Serial Number: Glycol Used: Custom Custom Ethylene Glycol (EG) Model Number: TEG Dehydration Unit Reboiler Rating: 0.75 ❑ DiEthylene Glycol (DEG) Glycol Pump Drive: p Electric ❑ Gas If Gas, injection pump ratio: Pump Make and Model: Kerr Triplex PD MMBTU/hr ❑ TriEthylene Glycol (TEG) # of pumps: Glycol Recirculation rate (gal/min): Lean Glycol Water Content: Max: 8.20 1.0 Wt.% Requested: 8.20 Acfm/gpm 1 Dehydrator Gas Throughput: Design Capacity: 55 MMSCF/day Requested: 20,075 MMSCF/year Actual: 14,306 MMSCF/year Inlet Gas: Pressure: 1,000 Water Content: Wet Gas: Flash Tank: Pressure: 55 Cold Separator: Pressure: Stripping Gas: (check one) ❑✓ None ❑ Flash Gas ❑ Dry Gas ❑ Nitrogen Flow Rate: scfm psig Temperature: 106 ° F lb/MMSCF ❑✓ Saturated Dry gas: 7.0 lb/MMSCF psig Temperature: 160 °F ❑ NA psig Temperature: °F ✓❑ NA Additional Required Information: • Attach a Process Flow Diagram ❑✓ . Attach GRI-GLYCaIc 4.0 Input Report Et Aggregate Report (or equivalent simulation report/test results) • Attach the extended gas analysis (including BTEX a n -Hexane, temperature, and pressure) Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 COLORADO 3 I�.lme°ialPublic if.Yi66 &MM .M Permit Number: 95OPWE020 AIRS ID Number: 123 /0243/ 063 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.2767, -104.5475 ' s -fir 3ar x's 7 '�``&xs` ' 7emp. �,xv " F Aa e�ylx�7r� .fit x^ Op to ark�R o Above�G w l �a S-113 Indicate the direction of the stack outlet: (check one) 0 Upward ❑ Horizontal ❑ Downward ❑ Other (describe): 0 Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): 0 Other (describe): Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 4 I Hearn Emu* COLORADO Permit Number: 95OPWE020 AIRS ID Number: 123 /0243/ 063 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information ❑ Condenser: Used for control of: Type: Make/Model: Maximum Temp Average Temp Requested Control Efficiency ❑✓ VRU: Used for control of: Flash Tank Vapors Size: Make/Model: Requested Control Efficiency 100.0 % VRU Downtime or Bypassed 0.0 ❑ Combustion Device: * Used for control of: Still Vent Stream Rating: MMBtu/hr Type: Enclosed Combustor Make/Model: Cimarron Requested Control Efficiency: 95.0 % Manufacturer Guaranteed Control Efficiency 98.0 % Minimum Temperature: Waste Gas Heat Content Btu/scf Constant Pilot Light: ❑✓ Yes ❑ No Pilot burner Rating 0.05 MMBtu/hr Closed ❑ Loop System: Used for control of: Description: System Downtime O Other: Used for control of: Description: Control Efficiency Requested * ECD combustion device used for stilt vent control has a 3.0% annual downtime for maintenance and repairs. Still vent emissions will vent to atmosphere during periods of ECD downtime. Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 COLORADO 5 I Haidth .t , PM Permit Number: 95OPWE020 AIRS ID Number: 123 /02431 063 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes 0 No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): ,Overall Requested Control Efficiency (% reduction i-emissions Control Equipment Description sox NO), CO VOC Vapor Recovery Unit / Enclosed Combustor 100%1 95% HAPs Vapor Recovery Unit / Enclosed Combustor 100% / 95% Other: From what year is the following reported actual annual emissions data? 2017 Use the following table to report the criteria pollutant emissions from source: A Pollutant Uncontrolled Emission ;; Factor _ Emission Factor: Hmts_.._ Emission 4:40r -,=,"Ac _ c-- Source __ (AP -42;_ _-Mfg_-etc)_. x � n i l eerrmi asst°n a s 4 "-,�'�,-'� �l Annual � tssions � ,� - � . Uncontrolled __Controlled5 (Tons/year):.. .(Tons/Year),-- Uncontrolled _ .(Tons/year)„ C-ontrolied.' .(Tons/year);,; PM SOx NO„ 0.068 Ib/MMBtu AP -42 -- -- 0.19 0.19 CO 0.31 Ib/MMBtu AP -42 -- -- 0.87 0.87 VOC 29.9 Ib/MMscf GLYCalc 126.17 1.45 300.24 14.26 Benzene 2.8 Ib/MMscf GLYCaIc 12.03 0.20 28.22 2.13 Toluene 4.3 lb/MMscf GLYCaIc 11.86 0.09 43.43 3.32 Ethylbenzene 0.2 lb/MMscf GLYCalc 0.51 0.001 2.34 0.18 Xylenes 3.1 Ib/MMscf GLYCaIc 5.14 0.01 31.61 2.45 n -Hexane 0.5 Ib/MMscf GLYCalc 2.26 0.03 5.19 0.21 Trimethylpentane thylp 0.002 Ib/MMscf GLYCaIc neg. neg. 0.02 0.001 Other: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 ,COLORADO 61 •v rib s Permit Number: 95OPWE020 AIRS ID Number: 123 /0243/ 063 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Legally Authorized Person (not a vendor or consultant) Roshini Shankaran Name (please print) -4 I2o/rg Date Senior Environmental Engined Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance l Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 COLORADO 7 I bepafm.t& cnt of P YYY �th6E, trn...M Attachment C Existing (Unmodified) APEN Forms C-148 C-135 C-151 C-166 C-174 C-176 Marla Compressor Station Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 /052 [Leave blank unless APED has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: DCP Operating Company, LP Maria Compressor Station Site Location: SE Section 28, T4N, R64W Mailing Address: (Include Zip Code) 370 17th Street Suite 2500 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 4922 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 E -Mail Address2: RShankaran@dcpmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 1 riff ter �n�u eaUnmmam 385465 Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 052 [Leave blank unless APCD has already assigned a permit tt and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR- Q MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - E1 APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Et Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. C-148 / P-102 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 9/24/2005 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: / /www. colorado. gov/cdphe/attainment) Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year 0 Yes ❑ No Seasonal use percentage: Dec -Feb: 25% Mar -May: 25% June -Aug: 25% Sept -Nov: 25% Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 V COLORADO 2 A ; °a° o Luc F,,.,,,,,e r.fl1,nnmcnl Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 052 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: D Primary and/or Peaking ❑ Pump O Water Pump O Emergency Back-up ❑ Other: 0 Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha Engine Model: L7042 GSI Serial Number6: 232481 hours/year What is the maximum designed horsepower rating? 1,478 hp What is the engine displacement? 9.58 l/cyl What is the maximum manufacturer's site -rating? 1,478 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,830 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke 0 4 -Stroke Combustion: O Lean Burn 0 Rich Burn Ignition Source: 0 Spark O Compression Aspiration: ❑ Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? El Yes ❑ No If yes, what type of AFRC is in use? 1 O2 Sensor (mV) ❑NOx Sensor (ppm) Is this engine equipped with a Low-NOx design? ❑ Yes ❑✓ No Engine Dates: What is the manufactured date of this engine? 8/25/1972 What date was this engine ordered? 1972 O Other: What is the date this engine was first located to Colorado? 05/06/2004 What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? 1972 What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 3 na�ndawu HaINBLrsi�a�mm� Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 052 [Leave blank unless APCD has already assigned a permit It and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.2767 / -104.5475 Fs. E4- perat r Stec lb �O 2 f _'. i,--s 'i-a N �tschar a diet ht Bove Ground Level F_�et 3 jTempJ . � ( F JY K h X+ p�, 'Ya�i *¢ s uy �Su d iow Ra te CFM� f S5 -'�, t 4a � x �/e oc�, fi t ec _ C-148 25 1,125 6,967 108 Indicate the direction of the Stack outlet: (check one) Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/Rectangle O Other (describe): Interior stack diameter (inches): 14 ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information 'UelUse Rate o =w , ctyai Annual Fue Uses MM F/ e r y Requested Annual Permit Li t . ear 11,347 82.9 99.4 From what year is the actual annual amount? 2017 Indicate the type of fuel used8: ❑✓ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑ Field Natural Gas Heating value: BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. II: Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 pp COLORADO 4 Im• NxaiiE� B EnWiMRTW11( Formaldehyde TSP (PM) Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 /052 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Overall Requested Control Efficiency (% reduction in emissions PM10 PM 2.5 SOX NOx VOC NSCR 73% NSCR 33% CO NSCR 63% Other: NSCR - HAPs Formaldehyde: 76%, Other HAPs: 50% Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Uncontrolled Bassi' lb/MMBtu Criteria Pollutant Emissions. Inventory..; Source (AP -42, Mfg. etc) Uncontrolled ---- Emissions =.(Tons/year) ontrolled7. Emissions Tonsfyear) TSP (PM) 1.94E-02 AP -42 0.90 0.90 0.98 ontrolled missions (Tons%year) 0.98 PM 10 PM 2.5 1.94E-02 Ib/MMBtu AP -42 0.90 0.90 0.98 0.98 1.94E-02 lb/MMBtu AP -42 0.90 0.90 0.98 0.98 SOX NOx VOC 5.88E-04 lb/MMBtu AP -42 0.03 0.03 0.03 0.03 11.0 g/hp-hr Mfg. 143.63 38.96 156.99 42.82 1.5 g/hp-hr Mfg. 19.59 12.99 21.41 14.27 CO 8.0 g/hp-hr Mfg. 104.46 38.96 114.18 42.82 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: ❑✓ Yes ❑ No Non-Cri€eria Reportable Pollutant Emissions Inventory emical Abstract. ,. Service (CAS) Number mission Factor ctual Annual Emission, Uncontrolled Basis .:.' Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds year, Controlled Emissions (Pounds/year) 50000 2.05E-02 lb/MMBtu AP -42 1901.39 456.33 Acetaldehyde 75070 107028 2.79E-03 lb/MMEitu AP -42 258.77 129.39 Acrolein Benzene 71432 Other: Methanol 67561 3.06E-03 lb/MMBtu AP -42 283.82 141.91 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 5 IglCOLORADO irt.n„ Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 052 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application incomplete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. Signature of Legally Authorized Person (not a vendor or consultant) Roshini Shankaran Date Senior Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance O Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-201 Reciprocating Internal Combustion Engine APEN - Revision 1/2017 Akiff cotbkano Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 /053 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Marla Compressor Station Site Location: SE Section 28, T4N, R64W Mailing Address: (Include Zip code) 370 17th Street Suite 2500 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 4922 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 E -Mail Addressz• RShankaran@dcpmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1 /2017 1 L I�®COC:=C: e am „ewwru� - x»annu enmw.Iman. 385466 Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 053 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR - ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit E Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info a Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. C-135 / P-103 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 09/25/2001 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: //www. colorado. gov/cd phe /attainment ) Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Q Yes ❑ No Seasonal use percentage: Dec -Feb: 25% Mar -May: 25% June -Aug: 25% Sept -Nov: 25% Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 2 lAoepnncwrtak NNN HuaW B inw aamem Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 053 [Leave blank unless APCD has already assigned a permit # and AIRS ID) Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: ❑✓ Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha Engine Model: L7042 GSI hours/year Serial Number6: C-10605/1 What is the maximum designed horsepower rating? 1,478 hp What is the engine displacement? 9.58 l/cyl What is the maximum manufacturer's site -rating? 1,478 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,830 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ❑✓ 4 -Stroke Combustion: ❑ Lean Burn ❑✓ Rich Burn Ignition Source: ❑✓ Spark ❑ Compression Aspiration: ❑ Natural ❑✓ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes ❑ No If yes, what type of AFRC is in use? ✓❑ OZ Sensor (mV) LINO Sensor (ppm) ❑ Other: Is this engine equipped with a Low-NOX design? ❑ Yes r❑ No Engine Dates: What is the manufactured date of this engine? 6/22/1992 What date was this engine ordered? Before 6/22/1992 What is the date this engine was first located to Colorado? Before 8/2003 What is the date this engine was first placed in service/operation? Before 8/2003 What is the date this engine commenced construction? After 6/22/1992 What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1 /2017 3 AVCOLORADO Nm1416 Enuftonmem Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 053 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information .etigraphl.cat Coordinates latitude/Longitude or UTM).; 40.2767 / -104.5475 (dlbt'r� x +Y s Opera to�� Stack 1D }fib � Discharge Height �"��,� Above Ground =eve A fee r�L'h,y.N'. , " k � ��.�Temp��-�-. �' z� t (* �K.FIo� ete 0 �� x �(eloc �e C-135 25 1,125 6,967 108 Indicate the direction of the Stack outlet: (check one) O Upward ❑ Downward ❑ Horizontal ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 14 ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information '•' yFuel Use Rate @'l0 s` .. �{. hl.- J B P jl pa v�,zk { Actual Annual Fuel Use r[+r,/ 'p rvr". j ': .7≥aJ i ears Y RequestedAnnual Fermi Lir t7 11,347 82.13 99.4 From what year is the actual annual amount? 2017 Indicate the type of fuel used8: El Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑ Field Natural Gas Heating value: BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 Awr.COLORADO 4 I �aw .. Naw+ti B Emn4mnmmi Formaldehyde TSP (PM) Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 /053 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Overall Requested Control Efficiency reduction in emissions) PM10 PM 2.5 SOX NOx VOC NSCR 82% NSCR 33% CO NSCR 63% Other: NSCR - HAPs Formaldehyde: 76%, Other HAPs: 50% Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Pollutant TSP (PM) 1.94E-02 lb/MMBtu riteria,PollutantEmissionsInventory,;.,:. Source Mfg. etc) uai Annua Emissions9 Uncontrolled Emissions (Tons/year) AP -42 0.89 0.89 ncontrolled Emissions (Tons/year) 0.98 ontroiled Emissions ons/ye-Olr) 0.98 PM10 PM2.5 1.94E-02 lb/MMBtu AP -42 0.89 0.89 0.98 0.98 1.94E-02 Ib/MMBtu AP -42 0.89 0.89 0.98 0.98 SOX NOX VOC 5.88E-04 lb/MMBtu AP -42 0.03 0.03 0.03 0.03 11.0 g/hp-hr Mfg. 142.33 25.74 156.99 28.54 1.5 g/hp-hr Mfg. 19.41 12.87 21.41 14.27 CO 8.0 g/hp-hr Mfg. 103.51 38.60 114.18 42.82 Does the emissions source have any uncontrolled actual emissions of non -criteria Yes pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: ❑ No on -Criteria Reportable Pollutant Emissions Inventory Chemica Abstract >, Service (CAS) Number ." mission Factor`' Actual Annual`Emissions9 Uncontrolled Basis lb/MMBtu Source (AP -42, Mfg. etc) ncontrolled i Emissions (Pounds/year) Controlled Emissions (Pounds/year) 50000 2.05E-02 AP -42 1884.19 452.21 Acetaldehyde 75070 2.79E-03 lb/MMBtu AP -42 256.43 128.22 Acrolein 107028 71432 Benzene Other: Methanol 67561 3.06E-03 lb/MMBtu AP -42 281.25 140.62 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 5 1 .NF HWN B £nssnnmen� Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 053 [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GPM, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Senior Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an Increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Form APCD-2O-1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 keg 'ewe* COLORADO Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 /054 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Marla Compressor Station Site Location: SE Section 28, T4N, R64W Mailing Address: (Include Zip code) 370 17th Street Suite 2500 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 4922 Permit Contact: Roshini Shankaran Phone Number: E -Mail Address2: 303-605-2039 RShankaran@dcpmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 AyDen...eat Public . COLORADO Hwl. b Eamomma»t 385467 Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 054 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) El STATIONARY source ❑ PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR- El MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership' ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info a Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. C-151 / P-104 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 06/23/2005 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: //www.colorado.gov/cdphe/attainment) Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year ❑✓ Yes ❑ No Seasonal use percentage: Dec -Feb: 25% Mar -May: 25% June -Aug: 25% Sept -Nov: 25% Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 :COLORADO 2 1 • V ten. •� ' HWI � B El1V:mnmun; Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 /054 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: ❑✓ Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha Engine Model: L7042 GSI Serial Number': 230355 hours/year What is the maximum designed horsepower rating? 1,478 hp What is the engine displacement? 9.58 l/cyl What is the maximum manufacturer's site -rating? 1,478 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,830 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ❑✓ 4 -Stroke Combustion: El Lean Burn ❑✓ Rich Burn Ignition Source: ❑✓ Spark ❑ Compression Aspiration: ❑ Natural ❑✓ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑✓ Yes ❑ No If yes, what type of AFRC is in use? ❑✓ OZ Sensor (mV) ❑NOx Sensor (ppm) Is this engine equipped with a Low-NOx design? ❑ Yes ❑✓ No Engine Dates: What is the manufactured date of this engine? 05/26/1972 ❑ Other: What date was this engine ordered? Prior to 200'1 What is the date this engine was first located to Colorado? before 2001 What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? before 2001 What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 3 VF H:41.12.87-mrittAtmeol ACOLORADO Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 054 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.2767 / -104.5475 rat Qperator Stack D. 0, i Discharge Height' Above. Ground Level Temp c F) r Flov Rath {ACFM) t . yQloca y A (fec q. ..._ .* , r" _ ... .4_ .. ..,i .. .R ,.A...'"�, a ?..E,w. r+ rtf 2": o 54.... �� ._ ,. . C-151 25 1,125 6,967 108 Indicate the direction of the Stack outlet: (check one) ❑r Upward ❑ Horizontal ❑ Downward O Other (describe): Indicate the stack opening and size: (check one) ✓❑ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 14 ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel :Use Rate @ 100% Load e L SC / iour a h s" {f ' a Actual Annual FuelUs (MMSCF/year) � Requested Annual Permit Limit', MMSC /yea ) .,,..,x 11,573 82.90 99.4 From what year is the actual annual amount? 2017 Indicate the type of fuel used8: ❑✓ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑ Field Natural Gas Heating value: BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 4 I ��COLORADO a.Fro, Formaldehyde TSP (PM) Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 054 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM10 PM2-5 SOX NOx VOC NSCR 91% NSCR 53% CO NSCR 75% Other: NSCR - HAPs Formaldehyde: 76%, Other HAPs: 50% Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Criteria Pol utant Emissions Inventory Uncontrolled asis ':'- lb/MMBtu Source (AP 42, Mfg...etc) Uncontrolled , Emissions Controlled .- Emissions (Tons/year)..-_ nested Annual Permit Emission Limits) Uncontrolled -, Emissions (Ions/year)_._ Controlled_ Emissions (Tonsyenr).' TSP (PM) 1.94E-02 AP -42 0.90 0.90 0.98 0.98 PM10 PM2.5 1.94E-02 lb/MMBtu AP -42 0.90 0.90 0.98 0.98 1.94E-02 lb/MMBtu AP -42 0.90 0.90 0.98 0.98 SOX NOx VOC 5.88E-04 Ib/MMBtu AP -42 0.03 0.03 0.03 0.03 11.0 g/hp-hr Mfg. 143.72 12.99 156.99 14.27 1.5 g/hp-hr Mfg. 19.60 9.28 21.41 9.99 CO 8.0 g/hp-hr Mfg. 104.53 25.99 114.18 28.54 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: ❑✓ Yes ❑ No on -Criteria Reportable Pollutant Emissions Inventory Chemical Abstract Service (CAS) Number. mission Factor Actual 'Annual :Emissions9`' Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds/year) 50000 2.05E-02 lb/MMBtu AP -42 1902.58 456.62 Acetaldehyde 75070 2.79E-03 lb/MMBtu AP -42 258.94 129.47 Acrolein 107028 Benzene 71432 Other: Methanol 67561 3.06E-03 Ib/MMBtu AP -42 283.99 142.00 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 51AV HnaY6 Z t,, mamom Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 054 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. Signature of Legally Authorized Person (not a vendor or consultant) Roshini Shankaran Date Senior Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $1,500, if applicable to: ' Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-201 Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 6 AV Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 /059 ) JUL 232O12, [Leave blank unless APCD has already assigned a permit ik and AIRS ID) Section 1 - Administrative Information Company Name': Site Name: DCP Operating Company, LP Marla Compressor Station Site Location: SE Section 28, T4N, R64W Mailing Address: (Include Zip code) 370 17th Street Suite 2500 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 4922 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 E -Mail Address2: RShankaran@dcpmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 Aviv COLORADO 1 IAZIVn I��Uc HnM, t, E»uf ,,0p 0r� 385468 Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 059 [Leave blank unless APCD has already assigned a permit At and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR- O MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership' ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ▪ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info a Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. C-166 / P-109 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 9/25/2OO1 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.Rov/cdphe/attainment) Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year ID Yes ❑ No Seasonal use percentage: Dec Feb: 25% Mar -May: 25% June -Aug: 25% Sept -Nov: 25% Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 AWINrr :COLORADO 2I -V a c �TexW�wnmeoc Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 059 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: ❑✓ Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha Engine Model: L7042 GSI hours/year Serial Number6: C-13852/1 What is the maximum designed horsepower rating? 1,680 hp What is the engine displacement? 9.58 l/cyt What is the maximum manufacturer's site -rating? 1,680 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,860 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke E 4 -Stroke Combustion: ❑ Lean Burn ✓❑ Rich Burn Ignition Source: ❑✓ Spark ❑ Compression Aspiration: ❑ Natural Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ✓❑ Yes ❑ No If yes, what type of AFRC is in use? ri 02 Sensor (mV) ❑NOX Sensor (ppm) Is this engine equipped with a Low-NOx design? ❑ Yes ❑✓ No Engine Dates: What is the manufactured date of this engine? 8/21/2001 ❑ Other: What date was this engine ordered? Before 1/2002 What is the date this engine was first located to Colorado? Before 1/2002 What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? Before 1/2002 What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 3 •kyCODO L011," Win, Ha�iel,6 EnvtM ('t Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 059 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates .'' (Latitude/Longitude or UTM) " 40.2767 / -104.5475 O'er " t� perato Jtack (0 .. r�,.t DischargeHeight , Above Ground Lever ;•a� (Feet) Temp a...... ri Flow- ate a/�i,� �'�SE e oct C-166 40 1,152 9,662 205 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) r❑ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 14 ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information ueel Use, ate @ 100% Load � SCF/haur ' ... Actual Annual Fuel Use (z41i11SCF/year Requested Annual Permit Limits -:. SCF yea f 12,947 96.7 113.4 From what year is the actual annual amount? 2017 Indicate the type of fuel useds: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) O Field Natural Gas Heating value: 1,000 BTU/scf 0 Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 4 COLORADO AO'"mo I �' Naa1W b Envignmono,=� , Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 /059 Formaldehyde TSP (PM) [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): verall Requested Control Efficiency % reduction in emissions, PM 10 PM2,5 SOX NOX VOC NSCR 82% NSCR 33% CO NSCR 75% Other: NSCR - HAPs Formaldehyde: 76%, Other HAPs: 50% Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 riteria Pollutant Emissions Inventory TSP (PM) 1.94E-02 lb/MMBtu AP -42 ncontrolled missions �ons/yeur) ;, 1.05 equested,Annual Permit; :. Emission Limit(s)7 1.05 1.12 1.12 PM10 PM2,5 1.94E-02 lb/MMBtu AP -42 1.05 1.05 1.12 1.12 1.94E-02 lb/MMBtu AP -42 1.05 1.05 1.12 1.12 SOX NOX VOC 5.88E-04' 11.0 Ib/MMBtu g/hp-hr AP -42 Mfg. 0.03 166.99 0.03 30.31 0.03 178.45 0.03 32.45 1.5 g/hp-hr Mfg. 22.77 15.15 24.33 16.22 CO 8.0 g/hp-hr Mfg. 121.45 30.31 129.78 32.45 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: ❑✓ Yes ❑ No Non -Criteria Reportable Pollutant Emissions Inventory Chemical Abstract Service (CAS) Number 2.05E-02 lb/MMBtu mission Factor ctual Annual:Emissionst Source (AP -42, Mfg.' etc) ncontrolled Emissions Pounds/year) 532.57 50000 AP -42 2219.06 Acetaldehyde 75070 2.79E-03 lb/MMBtu AP -42 302.01 151.00 Acrolein 107028 71432 2.63E-02 lb/MMBtu AP -42 284.69 142.34 Benzene Other: Methanol 67561 3.06E-03 lb/MMBtu AP -42 331.24 165.62 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 :COLORADO 5 1 ,�,e�alk Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 059 (Leave blank unless APCD has already assigned a permit II and AIRS ID) Section 8 - Applicant Certification I hereby certify that alt information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. Signature of Legally Authorized Person (not a vendor or consultant) Roshini Shankaran 1.Z6/?fji g Date Senior Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: O Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change In fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 M toL0A0 I6 CVVSS77 en..t..saw.rr Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 /060 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Marla Compressor Station Site Location: SE Sec 28, T4N, R64W Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 4922 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 E -Mail Address2: RShankaran@dcpmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 407 COLORADO FNu1,h6E»aYwnrooN 385469 Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 060 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source LI PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR- ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership" ❑ Other (describe below) - OR • APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Et Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. C -174/P-110 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 12/2001 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.Rov/cdphe/attainment) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 25 Q Yes ❑ No hours/day 7 days/week 52 weeks/year Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 2 IAN' no Neap or,v,mnmvn+ Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 060 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: ❑✓ Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha Engine Model: L-7044 GSI hours/year Serial Number': 5283700815 What is the maximum designed horsepower rating? 1,680 hp What is the engine displacement? 9.58 l/cyl What is the maximum manufacturer's site -rating? 1,680 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,860 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ❑✓ 4 -Stroke Combustion: ❑ Lean Burn 0 Rich Burn Ignition Source: E Spark ❑ Compression Aspiration: ❑ Natural ❑✓ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑✓ Yes ❑ No If yes, what type of AFRC is in use? ✓❑ 02 Sensor (mV) ❑NOx Sensor (ppm) ❑ Other: Is this engine equipped with a Low-NOx design? ❑ Yes 0 No Engine Dates: What is the manufactured date of this engine? August 2010 What date was this engine ordered? 2011 What is the date this engine was first located to Colorado? 2018 What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? 2010 What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 3 �mulA H.AI[R B £lwitmlmaN Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 060 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information eographicalCoordinates Latitude/Longitude or UTM) 40.2767, -104.5478 d eratar r r Stank ID Nb Discharge: Height f Above Ground Level ` reef ) �S... �:.^r-.? �k % ems. Temp p. ' . ( F) FRx .++t 5:��-.d.. b ;,...-� �`�`i:. ✓.4 Mn �` Flo Rater M ;firs t�4 T"$- _.. .......w.e. v .✓`x'a. �`:.L....� �*>.. # -2 •^t.11 -5� c ate deity t/sec fxx n`. . C -174/P-110 40 1,152 9,662 205 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward ❑ Downward ❑ Horizontal ❑ Other (describe): Indicate the stack opening and size: (check one) 0 Circular 0 Square/Rectangle D Other (describe): Interior stack diameter (inches): 12 O Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information uei lase Rate @ f00'4'Coact'Actual 4:. k ,�„ SIbaur i AnnualFuel Use L Ya.t,- (MMGFI years ` . , . a Requested Annual Pe mil Limit § MS year F . 12,947 94.9 113.4 From what year is the actual annual amount? 2017 Indicate the type of fuel used8: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ✓❑ Field Natural Gas Heating value: 1,000 BTU/scf ❑ Propane (assumed fuel heating value of 1,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating internal Combustion Engine APEN - Revision 1/2017 COLORADO 4 lIkirr ors HWR�BFaYu3tpnmaBv Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 060 Formaldehyde TSP (PM) [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑r Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): IverallRequested Control Efficiency reduction inemis`sions PM10 PM2.5 SOx NOx VOC NSCR 91% NSCR 53% CO NSCR 75% Other: Formaldehyde, HAPs 76% for formaldehyde, 50% for other HAPs Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Criteria Pollutant Emissions Inventory Pollutant TSP (PM) 1.94E-02 Ib/MMBtu AP -42 uested.Annual P;e-mi :mission Limit(s)7 :.' ncontrolled Emissions ons/year) 1.03 1.12 1.12 1.03 PM10 PM2.5 1.94E-02 lb/MMBtu AP -42 1.03 1.03 1.12 1.12 1.94E-02 lb/MMBtu AP -42 1.03 1.03 1.12 1.12 SOx NOx VOC 5.88E-04 lb/MMBtu AP -42 0.031 0.031 0.034 0.034 11.0 g/hp-hr Manufacturer 163.84 29.74 178.45 16.22 1.5 g/hp-hr Manufacturer 22.34 14.87 24.33 11.36 CO 8.0 g/hp-hr Manufacturer 119.16 29.74 129.78 32.45 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: ❑✓ Yes ❑ No on -Criteria Reportable Pollutant E:missions Inventory Chemical Abstract , ervice '(CAS) Number mission Factoi Actual Annual Emissions$ Uncontrolled Basis lb/MMBtu Source '. (AP -42, Mfg. etc) ncontrolied`. Emissions (Pounds/year) 520 50000 2.05E-02 AP -42 2,166.67 Acetaldehyde 75070 107028 71432 2.79E-03 Ib/MMBtu AP -42 280 140 Acrolein Benzene 2.63E-03 Ib/MMBtu AP -42 280 140 Other. Methanol 67561 3.06E-03 lb/MMBtu AP -42 320 160 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO H,eo BL1wit,aTh,I Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 /060 [Leave blank unless APCD has already assigned a permit x and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GPM, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. Signature of Legally Authorized Person (not a vendor or consultant) Roshini Shankaran 6 ( f2t Date Senior Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, Increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-2O1 Reciprocating Internal Combustion Engine APEN Revision 1/2017 QQ COLORADO 6 Fm V Reciprocating Internal Combustion jut. 2 3 2018 Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 /061 [Leave blank unless APCD has already assigned a permit # and AIRS ID) Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Maria Compressor Station Site Location: SE Sec. 28, T4N, R64W Mailing Address: (Include Zip Code) 370 17th Street Suite 2500 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 4922 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 E -Mail Address2: rshankaran@dcpmidstream.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORA0o 1 I OaaWalt,' t4tatRffiHc al� h Enwtaamevl. 385470 Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 061 [Leave blank unless APCD has already assigned a permit ft and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR- Q MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit 2 Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) -OR - ❑ APEN submittal for update only {Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - 111 APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Et Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? yes If yes, provide the Company Equipment Identification No. C-176 / P-111 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 02/2003 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: / /www.colorado. gov/cdphe /attainment) Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year E Yes ❑ No Seasonal use percentage: Dec -Feb: 25% Mar -May: 25% June -Aug: 25% Sept -Nov: 25% Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 2 l 'COLORADO urp.,roaa,: of pwncc F cte a LTv3maT+ec Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 061 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: 0 Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha hours/year Engine Model: L7044 GSI Serial Number': C-17976/1 What is the maximum designed horsepower rating? 1,680 hp What is the engine displacement? 0.265 l/cyl What is the maximum manufacturer's site -rating? 1,680 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,860 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke El 4 -Stroke Combustion: ❑ Lean Burn E Rich Burn Ignition Source: 0 Spark ❑ Compression Aspiration: ❑ Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? M Yes ❑ No If yes, what type of AFRC is in use? 0 O2 Sensor (mV) ❑NOX Sensor (ppm) ❑ Other: Is this engine equipped with a Low-NOX design? ❑ Yes ❑✓ No Engine Dates: What is the manufactured date of this engine? 03/27/2008 What date was this engine ordered? 12/2007 What is the date this engine was first located to Colorado? N/A What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? 03/2008 What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 3 11`4111.== ' Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 1061 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information eographical Coordinates ahtude/Longitude or UTM) 4,458,467.15 / 538,468.97 era tc r tdCk 1D�2'lO+ " _ tGi+ 4 F ischar e'Hei D r � t Above' Ground t eve r 4 - :. �, j J ' * "� T m P 3 d' br -Y lour Rater Y r {AGFM Ie oc!ty te i a Ese ) raR S. td �.-.,h�.ry ..., rur xMs. ,n. � ..,+i. ny.. ,...-, ;..N .rv... ..v. n.. � .,.. �..... i.. .��..2t_ . �...�-.3i �t.a f4!. �tSaxt d C176/P111 40 1,152 9,662 205 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward ❑ Downward ❑ Horizontal ❑ Upward with obstructing raincap ❑ Other (describe): Indicate the stack opening and size: (check one) Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 12 Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information (=Fuel Use Rate @ 100% oad rs3fii ., f{ LFJho�rt) � �� -. � � Actual Annual Fuel Use T S{„ j'4 F h.,� ��. ?{Mh1SCF7year� ��. Requeste'Annual Permit Limit' ¢. 3 Tfi"fyT � M7VI,S e�'�'�_�� 12,947 96.1 113.4 From what year is the actual annual amount? 2017 Indicate the type of fuel used8: ❑✓ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑ Field Natural Gas Heating value: BTU/scf ❑ Propane (assumed fuel heatingvalue of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 '-COLORADO 4I Chemical Name Formaldehyde TSP (PM) Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 /061 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Primary Control Equipment Description Overall Requested Control Efficiency % reduction in emissions) PM10 PM2.5 SOX NOX VOC NSCR 82% NSCR 33% CO NSCR 75% Other: NSCR (HAPs) 76% (Formaldehyde), 50% (Other HAPs) Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Criteria Pollutant Emissions Inventory Pollutant TSP (PM) Uncontrolled Basis` Source Mfg. etc) Uncontrolled, Emisslons ;(Tons/year) .. Controlled .____Emissions _ (Tons/year) equested Annual Permit Emission Limit(s)7 Uncontrolled Emissions (Tons/year) Controlled Emissions (Ton.s/year) 1.94E-02 Ib/MMBtu AP -42 1.04 , 1.04 1.12 1.12 PM10 PM2.5 1.94E-02 Ib/MMBtu AP -42 1.04 1.04 1.12 1.12 1.94E-02 lb/MMBtu AP -42 1.04 1.04 1.12 1.12 SOX NOX VOC 5.88E-04 lb/MMBtu AP -42 0.03 0.03 0.03 0.03 11.0 g/hp-hr Mfg. 166.05 30.14 178.45 32.45 1.5 g/hp-hr Mfg. 22.64 15.07 24.33 16.22 CO 8.0 g/hp-hr Mfg. 120.76 30.14 129.78 32.45 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: ❑✓ Yes ❑ No Non -Criteria Reportable Pollutant Emissions Inventory Chemical Abstract Service (CAS) Number 50000 Emission Factor Actual Annual .Emissions':' Uncontrolled Basis 2.05E-02 Units Ib/MMBtu Source (AP -42, Mfg. etc) AP -42 ncontrolled Emissions (Pounds/ year) 2,206.59 Controlled Emissions (Pounds/year) 529.58 Acetaldehyde 75070 107028 71432 2.79E-03 Ib/MMBtu AP -42 300.31 150.16 Acrolein 2.63E-03 lb/MMBtu AP -42 283.09 141.54 Benzene Other: 67561 (Methanol) 3.06E-03 lb/MMBtu AP -42 329.37 164.69 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. COLORADO Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 5 I •&'„ ee .pro t, Permit Number: 95OPWE02O MRS ID Number: 123 /0243 /061 (Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Name (please print) Senior Environmental Engineer Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with 5152.90 and the General Permit for more information or assistance call: registration fee of 51,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-5S-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: {303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO fr....� i iii p.e... e,,..... Attachment D Emission Calculations and Supporting Documentation Marla Compressor Station Natural Gas Dehydration Marla Compressor Station DCP Operating Company, LP Source ID Description Manufacturer Model Serial # Start Date Operation Wet Gas Temperature Wet Gas Pressure Wet Gas Water Content Dry Gas Flow Rate Dry Gas Water Content Lean Glycol Water Content Lean Glycol Flow Rate Cold Separator? Cold Separator Temperature Cold Separator Pressure Glycol Pump Make 8 Model Glycol Pump Type Glycol Pump Gas Flow Rate Flash Tank? Flash Tank Temperature Flash Tank Pressure Flash Tank Control VRU Downtime P112 Dehydration Unit Custom TEG Dehydration Unit Custom Nov -05 8760 hr/yr 106 deg F 1000 psig Saturated IbH2O/MMscf 45 MMscfd 7.0 IbH2O/MMscf 1.0 wt % H20 6.25 gpm N Y/N N/A deg F N/A psig Kimray45015 Gas Elec. or Gas 0.08 acfm/gpm Y Y/N 100 deg F 45 psiq 100.00% Recycled to Inlet 0.00% Routed to ECD Stripping Gas? What is Stripping Gas? Stripping Gas Flow Rate Condenser?' Condenser Temperature Condenser Pressure Combustor? Combustor Ambient Air Temp Combustor Excess Oxygen Combustor Destruction Efficiency Combustor Downtime Total Emissions from GRI-GLYCaIc 4.0 N Y/N N/A scfm N Y/N deg F psia Y Y/N 60 deg F 0 % 95.00% 3.00% Uncontrolled Pollutant CAS Number Uncontrolled Emissions Controlled Emissions (lb/hr) (lb/yr) (1p1) +20% (tpy) (lb/hr) (Ib/yr) (tpy) +20% (tpy) VOC 86.7 759178 379.59 455.51 2.0 17699 8.85 10.62 n -hexane 110-54-3 1.47 12863 6.43 7.72 0.03 266 0.13 0.16 Benzene 71-43-2 4.19 36701 18.35 22.02 0.30 2659 1.33 1.60 Toluene 108-88-3 6.42 56225 28.11 33.74 0.48 4204 2.10 2.52 Ethylbenzene 100-41-4 0.34 3016 1.51 1.81 0.03 231 0.12 0.14 Xylene 1330-20-7 4.65 40745 20.37 24.45 0.36 3142 1.57 1.89 2,2,4 - Timethylpentane 540-84-1 0.01 68 0.03 0.04 .0.00 1 0.00 0.001 Total HAP 17.08 149618 74.81 89.77 1.20 10503 5.25 6.30 Notes: The uncontrolled values include both flash and overhead still vent streams. The flash stream is controlled with a VRU @ 100% control. *The still vent stream is routed through a condenser (acting as a secondary control device), then to an enclosed combustor (ECD). Controlled emissions only consider control from the ECD Pollutant CAS Number Uncontrolled Emissions Flash Emissions' Still Vent Emissions' Total Dehy Emissions2 Emission Factors (tpy) (tpy) (tpy) (lb/yr) (lb/MMscf) VOC 266.86 112.73 379.59 55.5 n -Hexane 110-54-3 - 4.74 1.70 6.43 12863 0.9 Benzene 71.43-2 1.41 16.94 18.35 36701 2.7 Toluene 108-88-3 1.34 26.77 28.11 56225 4.1 Ethylbenzene 100-41-4 0.04 1.47 1.51 3018 0.2 Xylene 1330-20-7 0.36 20.01 20.37 40745 3.0 2,2,4-Timethylpentane 540-84-1 0.02 0.01 0.03 68 0.005 Total HAP 7.91 _ 66.90 74.81. 10.9 1.Flash emissions and still vent emissions (uncontrolled potential to emit) obtained from GlyCalc report dated July 2018. 2. Total dehy emissions calculated as a sum of Flash and St'll Vent emissions. Still Vent Emissions Pollutant CAS Number Still Vent ECD Uptime Emissions 3 Still Vent ECD Downtime Emissions 4 Total Still Vent Emissions 5 (tpy) (tpy) (tpy) VOC 5.468 3.382 8.85 n -Hexane 110-54-3 0.082 0.051 0.13 Benzene 71-43-2 0.821 0.508 1.33 Toluene 108-88-3 1.299 0.803 2.10 Ethylbenzene 100-41-4 0,071 0.044 0.12 Xylene 1330-20-7 0.971 0.600 1.57 2,2,4-Trimethylpentane 540-84-1 0.000 0.000 0.00 Total HAP 3.245 2.007 5.25 3. Still Vent ECD control emissions refer to still vent emissions controlled by the enclosed combustor (during 97% annual uptime). 4. ECD downtime emissions refer to emissions during a maximum of 3% enclosed combustor downtime for maintenance and malfunctions. 5. Total still vent emissions is a sum of still vent ECD control and ECD downtime emissions. Total Controlled Emissions (PTE) Pollutant CAS Number Dehy Emissions' Dehy Emissions +20% Buffer Overall System Control' (tpy) (tpy) VOC 8.85 10.62 97.7% n -Hexane 110-54-3 0.13 0.16 Benzene 71-43-2 1.33 1.60 Toluene 108-88-3 2.10 2.52 Ethylbenzene 100-41-4 0.12 0.14 Xylene 1330-20-7 1.57 1.89 2,2,4-Trimethylpentane 540-84-1 0.00 0.00 Total HAP 5.25 6.30 6. Total controlled dehydrator emissions calculated as a sum of controlled still vent emissions, combined with emissions during control device downtime 7. DCP is adding a 20% buffer to controlled emissions for variability in gas analysis and other actual parameters. 8. Demonstrating an overall system control of 95%, calculated as [100% - Total Controlled Dehy VOC Emissions/Total Uncontrolled Dehy Emissions] Natural Gas Dehydration Condenser Vent Stream Detail from GRI-GLYCaIc 4.0 Description Vent Flow Rate Hours of operation Annual Flow Rate Condenser Vent Stream 202.00 scf/hr 8760 hr/yr 1.770 MMscf/yr Component Vol % . Mol Fraction Pure Component Mol Weight (Ib/Ib-mol) Component Fraction Mol Weight (lb/lb-mol) Component Mass Fraction Pure Component Heat Value (Btu/scf) Component Fraction Heat Value (Btu/scf) Water 39.60 0.396 18.02 7.14 0.1352 0 0.0 Carbon Dioxide 6.14 0.0614 44.01 - 2.70 0.0512 0 0.0 Hydrogen Sulfide 0.00 0 34,1 0.00 0.0000 0 0.0 Nitrogen 0.02 0.000198 28 . 0.01 0.0001 0 0.0 Methane 5.95 0.0595 16.04 0.95 0.0181 1010.0 60.1 Ethane 5.49 0.0549 30.07 1.65 0.0313 1769.6 97.2 Propane 6.63 0.0663 44.10 2.92 0.0554 2516.1 166.8 i-Butane 1.49 0.0149 58.12 0.87 0.0164 3251.9 48.5 n -Butane 5,13 0,0513 58.12 2.08 0.0666 3262.3 167.4 i-Pentane - 1.30 0.0130 72.15 0.94 0,0178 4000.9 52.0 n -Pentane 1.96 0.0196 72.15 1.41 0.0268 4008.9 78.6 Cyclopentane 0.54 0.0054 70.13 0.38 0.0072 3763.9 20.4 n -Hexane 0.78 0.0078 86.18 0.67 0.0126 4755.9 36.9 Cyclohexane 1.19 0.0119 84.16 1.00 0.0190 4481.5 53.3 Other Hexanes 0.89 0.0089 86.18 0.76 0.0145 4755.9 42.2 Heptanes 1.15 0.0115 100.20 1.15 0.0218 5502.5 63.3 Methylcyclohexane 1.05 0.0105 98.19 1.03 0.0195 5215.7 54.8 2,2,4-Trimethylpentane 0.003 0.0000 114.23 0.00 0.0001 6231.7 0.2 Benzene 7.97 0.0797 78.11 6.23 0.1179 3741.8 298.2 Toluene 8.72 0.0872 - 92.14 8.03 0.1522 4475.0 390.2 Ethylbenzene 0.262 0.0028 106.17 0.30 0.0057 5222.2 14.7 Xytenes 3.62 0.0362 318.50 11.53 0.2184 5208.8 188.6 Octanes + 0.119 0.0012 114.23 0.14 0.0026 6248.9 7.4 100.02 1.0002 52.80 1.00 1841 9. An additional GLYCalc run was performed including the condenser used as a secondary control device on unit P-112, to determine the waste gas flowrate and heat content going to the enclosed combustor. The primary GLYCalc run for this unit omits the condenser, to ensure that no condenser control is claimed in the overall emission calculations. Both the primary GLYCalc run, and an abridged version -of the additional GLYCalc run, have been included in Attachment C of this application. P112 / P113 Glycol Dehy Calculations Uncontrolled Emissions Uncontrolled Emissions are taken directly from GLYCaIc. Emission Factor lb = Uncontrolled Emissions tons * 2,000 lb * day * 1 year MMscf year ton Dehy Throughput MMscf 365 days Regen / Still Vent Emissions ECD Uptime Emissions tons = Uncontrolled Regen Emissions tons * ( 1- ECD downtime percentage) * ( 1- ECD Control Efficiency) year year Regen / Still Vent is controlled with ECD that has a control efficiency of 95%. ECD has a 3.0% annual downtime associated with maintenance and repairs, during which emissions for the still vent, vent to atmosphere. ECD Downtime Emissions tons = Uncontrolled Regen Emissions tons * ( ECD Downtime Percentage) year year Still Vent emissions are vented to atmosphere during 3.0% annual ECD downtime. Total Regen Emissions = ECD uptime emissions + ECD downtime emissions Total Dehy Emissions Total Dehy Emissions = Total Regen Emissions Overall Control Efficiency = 1- Total Dehy VOC Emissions P-112 (Inputs Report, no condenser).txt GRI-GLYCalc VERSION 4.0 - SUMMARY OF INPUT VALUES Case Name: Marla P112 File Name: \\dennas00\Data\Environmental\Air\Colorado\Marla\2018-06 TV Sig Mod - Remove TEG Condenser\02. Emissions\GLYCalc\P112\P112 (6-2017 EGA).ddf Date: July 02, 2018 DESCRIPTION: Description: 45.0 MMscfd TEG Dehydrator Marla Inlet EGA dated 6/2017 6.25 gpm TEG recirculation rate Annual Hours of Operation: 8760.0 hours/yr WET GAS: Temperature: 106.00 deg. F Pressure: 1000.00 psig Wet Gas Water Content: Saturated Component Conc. (vol %) Carbon Dioxide 2.5100 Nitrogen 0.2400 Methane 70.3768 Ethane 14.7764 Propane 7.0924 Isobutane 0.9641 n -Butane 2.3007 Isopentane 0.5291 n -Pentane 0.5997 Cyclopentane 0.0256 n -Hexane 0.1242 Cyclohexane 0.0314 Other Hexanes 0.1973 Heptanes 0.0948 Methylcyclohexane 0.0278 2,2,4-Trimethylpentane 0.0006 Benzene 0.0187 Toluene 0.0197 Ethylbenzene 0.0008 Xylenes 0.0079 C8+ Heavies 0.0620 DRY GAS: Flow Rate: 45.0 MMSCF/day Water Content: 7.0 lbs. H2O/MMSCF LEAN GLYCOL: Glycol Type: TEG Water Content: Flow Rate: PUMP: 1.0 wt% H2O 6.3 gpm Glycol Pump Type: Gas Injection Page 1 P-112 (Inputs Report, no condenser).txt Gas Injection Pump Volume Ratio: 0.080 acfm gas/gpm glycol FLASH TANK: Flash Control: Recycle/recompression Temperature: 100.0 deg. F Pressure: 45.0 psig Page 2 P-112 (Aggregate Report, no condenser).txt GRI-GLYCalc VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name: Marla P112 File Name: \\dennas00\Data\Envirornnental\Air\Colorado\Marla\2018-06 TV Sig Mod - Remove TEG Condenser\02. Emissions\GLYCalc\P112\P112 (6-2017 EGA).ddf Date: July 02, 2018 DESCRIPTION: Description: 45.0 MMscfd TEG Dehydrator Marla Inlet EGA dated 6/2017 6.25 gpm TEG recirculation rate Annual Hours of Operation: 8760.0 hours/yr EMISSIONS REPORTS: UNCONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.5074 12.177 2.2223 Ethane 0.8783 21.079 3.8469 Propane 1.5657 37.576 6.8576 Isobutane 0.4668 11.204 2.0447 n -Butane 1.6095 38.627 7.0495 Isopentane 0.5179 12.430 2.2684 n -Pentane 0.7927 19.025 3.4721 Cyclopentane 0.2149 5.156 0.9410 n -Hexane 0.3872 9.293 1.6960 . Cyclohexane 0.6009 14.422 2.6321 Other Hexanes 0.4350 10.439 1.9052 Heptanes 0.7463 17.912 3.2689 Methylcyclohexane 0.6776 16.263 2.9680 2,2,4-Trimethylpentane 0.0021 0.052 0.0094 Benzene 3.8671 92.810 16.9379 Toluene 6.1130 146.711 26.7748 Ethylbenzene 0.3353 8.046 1.4685 Xylenes 4.5696 109.669 20.0147 O8+ Heavies 2.8368 68.082 12.4250 Total Emissions 27.1239 650.974 116.8028 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions FLASH GAS EMISSIONS 27.1239 25.7383 15.2742 14.8849 650.974 617.719 366.582 357.237 118.8028. 112.7337 66.9012 65.1958 Note: Flash Gas Emissions are zero with the Recycle/recompression control option. FLASH TANK OFF GAS Component lbs/hr lbs/day tons/yr Methane 84.3855 2025.252 369.6085 Ethane 38.3781 921.075 168.0962 Propane 28.5222 684.533 124.9272 Isobutane 5.2748 126.595 23.1036 n -Butane 13.4073 321.776 58.7242 Page 1 P-112 (Aggregate Report, no condenser).txt Isopentane 3.5910 86.185 15.7287 n -Pentane 4.3027 103.266 18.8460 Cyclopentane 0.3028 7.266 1.3261 n -Hexane 1.0812 25.949 4.7358 Cyclohexane 0.4321 10.370 1.8925 Other Hexanes 1.6519 39.647 7.2355 Heptanes 0.9474 22.738 4.1496 Methylcyclohexane 0.3573 8.575 1.5649 2,2,4-Trimethylpentane 0.0057 0.136 0.0248 Benzene 0.3226 7.741 1.4128 Toluene 0.3055 7.332 1.3382 Ethylbenzene 0.0090 0.216 0.0395 Xylenes 0.0817 1.961 0.3579 C8+ Heavies 0.3317 7.961 1.4530 Total Emissions 183.6906 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions EQUIPMENT REPORTS: 183.6906 60.9270 1.8057 0.7188 4408.574 804.5648 4408.574 1462.248 43.337 17.251 804.5648 266.8602 7.9089 3.1484 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: Calculated Dry Gas Dew Point: 1.25 4.35 lbs. H2O/MMSCF Temperature: 106.0 deg. F Pressure: 1000.0 psig Dry Gas Flow Rate: 45.0000 MMSCF/day Glycol Losses with Dry Gas: 2.2992 lb/hr Wet Gas Water Content: Saturated Calculated Wet Gas Water Content: 69.88 lbs. H2O/MMSCF Calculated Lean Glycol Recirc. Ratio: 3.05 gal/lb H2O Remaining Absorbed Component in Dry Gas in Glycol Water 6.22% 93.78% Carbon Dioxide 99.81% 0.19% Nitrogen 99.98% 0.02% Methane 99.98% 0.02% Ethane 99.96% 0.04% Propane 99.94% 0.06% Isobutane 99.93% 0.07% n -Butane 99.91% 0.09% Isopentane 99.92% 0.08% n -Pentane 99.90% 0.10% Cyclopentane 99.55% 0.45% n -Hexane 99.86% 0.14% Cyclohexane 99.35% 0.65% Other Hexanes 99.89% 0.11% Heptanes 99.78% 0.22% Methylcyclohexane 99.37% 0.63% 2,2,4-Trimethylpentane 99.91% 0.09% Benzene 94.33% 5.67% Toluene 92.98% 7.02% Page 2 P-112 (Aggregate Report, no condenser).txt Ethylbenzene 91.93% 8.07% Xylenes C8+ Heavies FLASH TANK 88.91% 11.09% 99.53% 0.47% Flash Control: Recycle/recompression Flash Temperature: 100.0 deg. F Flash Pressure: 45.0 psig Component Left in Removed in Glycol Flash Gas Water 99.85% 0.15% Carbon Dioxide 8.11% 91.89% Nitrogen 0.57% 99.43% Methane 0.60% 99.40% Ethane 2.24% 97.76% Propane 5.20% 94.80% Isobutane 8.13% 91.87% n -Butane 10.72% 89.28% Isopentane 12.77% 87.23% n -Pentane 15.74% 84.26% Cyclopentane 41.73% 58.27% n -Hexane 26.56% 73.44% Cyclohexane 59.29% 40.71% Other Hexanes 21.20% 78.80% Heptanes 44.24% 55.76% Methylcyclohexane 66.62% 33.38% 2,2,4-Trimethylpentane 27.95% 72.05% Benzene 92.68% 7.32% Toluene 95.61% 4.39% Ethylbenzene 97.65% 2.35% Xylenes C8+ Heavies REGENERATOR 98.47% 1.53% 90.54% 9.46% No Stripping Gas used in regenerator. Remaining Distilled Component in Glycol Overhead Water 22.24% 77.76% 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 1.48% 98.52% n -Pentane 1.37% 98.63% Cyclopentane 0.92% 99.08% n -Hexane 0.96% 99.04% Cyclohexane 4.49% 95.51% Other Hexanes 2.15% 97.85% Heptanes 0.71% 99.29% Methylcyclohexane 4.98% 95.02% 2,2,4-Trimethylpentane 2.22% 97.78% Benzene 5.28% 94.72% Toluene 8.12% 91.88% Ethylbenzene 10.51% 89.49% Page 3 P-112 (Aggregate Report, no condenser).txt Xylenes C8+ Heavies STREAM REPORTS: 13.01% 86.99% 10.61% 89.39% WET GAS STREAM Temperature: 106.00 deg. F Pressure: 1014.70 psia Flow Rate: 1.88e+006 scfh Component Conc. Loading (vol%) (lb/hr) Water 1.47e-001 1.31e+002 Carbon Dioxide 2.51e+000 5.46e+003 Nitrogen 2.40e-001 3.32e+002 Methane 7.03e+001 5.58e+004 Ethane 1.48e+001 2.20e+004 Propane 7.08e+000 1.55e+004 Isobutane 9.63e-001 2.77e+003 n -Butane 2.30e+000 6.61e+003 Isopentane 5.28e-001 1.89e+003 n -Pentane 5.99e-001 2.14e+003 Cyclopentane 2.56e-002 8.87e+001 n -Hexane 1.24e-001 5.29e+002 Cyclohexane 3.14e-002 1.31e+002 Other Hexanes 1.97e-001 8.41e+002 Heptanes 9.47e-002 4.70e+002 Methylcyclohexane 2.78e -a002 1.35e+002 2,2,4-Trimethylpentane 5.99e-004 3.39e+000 Benzene 1.87e-002 7.22e+001 Toluene 1.97e-002 8.97e+001 Ethylbenzene 7.99e-004 4.20e+000 Xylenes 7.89e-003 4.15e+001 C8+ Heavies 6.19e-002 5.22e+002 Total Components 100.00 1.15e+005 DRY GAS STREAM Temperature: 106.00 deg. F Pressure: 1014.70 psia Flow Rate: 1.88e+006 scfh Component Conc. Loading (vol%) (lb/hr) Water 9.17e-003 8.16e+000 Carbon Dioxide 2.51e+000 5.45e+003 Nitrogen 2.40e-001 3.32e+002 Methane 7.04e+001 5.58e+004 Ethane 1.48e+001 2.20e+004 Propane 7.09e+000 1.55e+004 Isobutane 9.64e-001 2.77e+003 n -Butane 2.30e+000 6.60e+003 Isopentane 5.29e-001 1.89e+003 n -Pentane 5.99e-001 2.14e+003 Cyclopentane 2.55e-002 8.84e+001 n -Hexane 1.24e-001 5.28e+002 Cyclohexane 3.12e-002 1.30e+002 Other Hexanes 1.97e-001 8.40e+002 Page 4 P-112 (Aggregate Report, no condenser).txt Heptanes 9.46e-002 4.69e+002 Methylcyclohexane 2.76e-002 1.34e+002 2,2,4-Trimethylpentane 6.00e-004 3.38e+000 Benzene 1.76e-002 6.81e+001 Toluene 1.83e-002 8.34e+001 Ethylbenzene 7.36e-004 3.86e+000 Xylenes 7.03e-003 3.69e+001 C8+ Heavies 6.17e-002 5.20e+002 Total Components 100.00 1.15e+005 LEAN GLYCOL STREAM Temperature: 106.00 deg. F Flow Rate: 6.25e+000 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9.89e+001 3.48e+003 Water 1.00e+000 3.52e+001 Carbon Dioxide 2.94e-011 1.03e-009 Nitrogen 1.84e-013 6.49e-012 Methane 8.63e-016 3.04e-016 Ethane 1.26e-007 4.44e-006 Propane 1.05e-008 3.69e-007 Isobutane 1.69e-009 5.93e-008 n -Butane 4.25e-009 1.50e-007 Isopentane 2.21e-004 7.76e-003 n -Pentane 3.13e-004 1.10e-002 Cyclopentane 5.67e-005 1.99e-003 n -Hexane 1.07e-004 3.77e-003 Cyclohexane 8.04e-004 2.83e-002 Other Hexanes 2.71e-004 9.54e-003 Heptanes 1.51e-004 5.30e-003 Methylcyclohexane 1.01e-003 3.55e-002 2,2,4-Trimethylpentane 1.39e-006 4.88e-005 Benzene 6.12e-003 2.15e-001 Toluene 1.54e-002 5.41e-001 Ethylbenzene 1.12e-003 3.94e-002 Xylenes 1.94e-002 6.83e-001 C8+ Heavies 9.57e-003 3.37e-001 Total Components 100.00 3.52e+003 RICH GLYCOL AND PUMP GAS STREAM Temperature: 106.00 deg. F Pressure: 1014.70 psia Flow Rate: 6.99e+000 gpm NOTE: Stream has more than one phase. Component Conc. Loading (wt%) (lb/hr) TEG 8.99e+001 3.48e+003 Water 4.10e+000 1.58e+002 Carbon Dioxide 4.59e-001 1.78e+001 Nitrogen 1.34e-002 5.16e-001 Methane 2.19e+000 8.49e+001 Ethane 1.01e+000 3.93e+001 Propane 7.78e-001 3.01e+001 Isobutane 1.48e-001 5.74e+000 n -Butane 3.88e-001 1.50e+001 Isopentane 1.06e-001 4.12e+000 Page 5 P-112 (Aggregate Report, no condenser).txt n -Pentane 1.32e-001 5.11e+000 Cyclopentane 1.34e-002 5.20e-001 n -Hexane 3.81e-002 1.47e+000 Cyclohexane 2.74e-002 1.06e+000 Other Hexanes 5.42e-002 2.10e+000 Heptanes 4.39e-002 1.70e+000 Methylcyclohexane 2.77e-002 1.07e+000 2,2,4-Trimethylpentane 2.03e-004 7.86e-003 Benzene 1.14e-001 4.41e+000 Toluene 1.80e-001 6.96e+000 Ethylbenzene 9.92e-003 3.84e-001 Xylenes 1.38e-001 5.33e+000 C8+ Heavies 9.06e-002 3.51e+000 Total Components 100.00 3.87e+003 FLASH TANK OFF GAS STREAM Temperature: 100.00 deg. F Pressure: 59.70 psia Flow Rate: 3.07e+003 scfh Component Conc. Loading (vol%) (lb/hr) Water 1.61e-001 2.35e-001 Carbon Dioxide 4.59e+000 1.63e+001 Nitrogen 2.27e-001 5.14e-001 Methane 6.51e+001 8.44e+001 Ethane 1.58e+001 3.84e+001 Propane 8.00e+000 2.85e+001 Isobutane 1.12e+000 5.27e+000 n -Butane 2.85e+000 1.34e+001 Isopentane 6.16e-001 3.59e+000 n -Pentane 7.38e-001 4.30e+000 Cyclopentane 5.34e-002 3.03e-001 n -Hexane 1.55e-001 1.06e+000 Cyclohexane 6.35e-002 4.32e-001 Other Hexanes 2.37e-001 1.65e+000 Heptanes 1.17e-001 9.47e-001 Methylcyclohexane 4.50e-002 3.57e-001 2,2,4-Trimethylpentane 6.13e-004 5.66e-003 Benzene 5.11e-002 3.23e-001 Toluene 4.10e-002 3.06e-001 Ethylbenzene 1.05e-003 9.01e-003 Xylenes 9.52e-003 8.17e-002 C8+ Heavies 2.41e-002 3.32e-001 Total Components 100.00 2.01e+002 FLASH TANK GLYCOL STREAM Temperature: 100.00 deg. F Flow Rate: 6.55e+000 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9.49e+001 3.48e+003 Water 4.31e+000 1.58e+002 Carbon Dioxide 3.93e-002 1.44e+000 Nitrogen 8.02e-005 2.94e-003 Methane 1.38e-002 5.07e-001 Ethane 2.39e-002 8.78e-001 Propane 4.27e-002 1.57e+000 Isobutane 1.27e-002 4.67e-001 Page 6 P-112 (Aggregate Report, no condenser).txt n -Butane 4.39e-002 1.61e+000 Isopentane 1.43e-002 5.26e-001 n -Pentane 2.19e-002 8.04e-001 Cyclopentane 5.91e-003 2.17e-001 n -Hexane 1.07e-002 3.91e-001 Cyclohexane 1.72e-002 6.29e-001 Other Hexanes 1.21e-002 4.45e-001 Heptanes 2.05e-002 7.52e-001 Methylcyclohexane 1.94e-002 7.13e-001 2,2,4-Trimethylpentane 5.99e-005 2.20e-003 Benzene l.11e-001 4.08e+000 Toluene 1.81e-001 6.65e+000 Ethylbenzene 1.02e-002 3.75e-001 Xylenes 1.43e-001 5.25e+000 C8+ Heavies 8.65e-002 3.17e+000 Total Components 100.00 3.67e+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: 2.74e+003 scfh Component Conc. Loading (vol%) (lb/hr) Water 9.45e+001 1.23e+002 Carbon Dioxide 4.53e-001 1.44e+000 Nitrogen 1.45e-003 2.94e-003 Methane 4.38e-001 5.07e-001 Ethane 4.04e-001 8.78e-001 Propane 4.91e-001 1.57e+000 Isobutane l.11e-001 4.67e-001 n -Butane 3.83e-001 1.61e+000 Isopentane 9.93e-002 5.18e-001 n -Pentane 1.52e-001 7.93e-001 Cyclopentane 4.24e-002 2.15e-001 n -Hexane 6.22e-002 3.87e-001 Cyclohexane 9.88e-002 6.01e-001 Other Hexanes 6.98e-002 4.35e-001 Heptanes 1.03e-001 7.46e-001 Methylcyclohexane 9.55e-002 6.78e-001 2,2,4-Trimethylpentane 2.60e-004 2.15e-003 Benzene 6.85e-001 3.87e+000 Toluene 9.18e-001 6.11e+000 Ethylbenzene 4.37e-002 3.35e-001 Xylenes 5.95e-001 4.57e+000 C8+ Heavies 2.30e-001 2.84e+000 Total Components 100.00 1.52e+002 Page 7 P-112 (Inputs Report, with condenser).txt GRI-GLYCalc VERSION 4.0 - SUMMARY OF INPUT VALUES Case Name: Marla P112 - Condenser Added for Still Vent BTU content ONLY File Name: \\dennas00\Data\Environmental\Air\Colorado\Marla\2018-06 TV Sig Mod - Remove TEG Condenser\02. Emissions\GLYCalc\P112\P112 (6-2017 EGA, + condenser).ddf Date:. July 02, 2018 DESCRIPTION: Description: 45.0 MMscfd TEG Dehydrator Marla Inlet EGA dated 6/2017 6.25 gpm TEG recirculation rate Condenser.` for Still Vent B'TU content' ONLY Annual Hours of Operation: 8760.0 hours/yr WET GAS: Temperature: 106.00 deg. F Pressure: 1000.00 psig Wet Gas Water Content: Saturated Component Conc. (vol %) Carbon Dioxide 2.5100 Nitrogen 0.2400 Methane 70.3768 Ethane 14.7764 Propane 7.0924 Isobutane 0.9641 n -Butane 2.3007 Isopentane 0.5291 n -Pentane 0.5997 Cyclopentane 0.0256 n -Hexane 0.1242 Cyclohexane 0.0314 Other Hexanes 0.1973 Heptanes 0.0948 Methylcyclohexane 0.0278 2,2,4-Trimethylpentane 0.0006 Benzene 0.0187 Toluene 0.0197 Ethylbenzene 0.0008 Xylenes 0.0079 C8+ Heavies 0.0620 DRY GAS: Flow Rate: 45.0 MMSCF/day Water Content: 7.0 lbs. H20/MMSCF LEAN GLYCOL: Glycol Type: TEG Water Content: Flow Rate: PUMP: 1.0 wt% H2O 6.3 gpm Glycol Pump Type: Gas Injection Page 1 P-112 (Inputs Report, with condenser).txt Gas Injection Pump Volume Ratio: 0.080 acfm gas/gpm glycol FLASH TANK: Flash Control: Recycle/recompression Temperature: 100.0 deg. F Pressure: 45.0 psig REGENERATOR OVERHEADS CONTROL DEVICE: Control Device: Condenser Temperature: Pressure 12_0 psia Page 2 P-112 (Aggregate Report, with condenser).txt GRI-GLYCalc VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name: Marla P112 - Condenser Added for Still Vent BTU content ONLY File Name: \\dennas00\Data\Environmental\Air\Colorado\Marla\2018-06 TV Sig Mod - Remove TEG Condenser\02. Emissions\GLYCalc\P112\P112 (6-2017 EGA, + condenser).ddf Date: July 02, 2018 DESCRIPTION: Description: 45.0 MMscfd TEG Dehydrator Marla Inlet EGA dated 6/2017 6.25 gpm TEG recirculation rate Condenser, for. Still Vent BTU content ONLY Annual Hours of Operation: 8760.0 hours/yr EMISSIONS REPORTS: CONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.5071 12.171 2.2213 Ethane 0.8768 21.044 3.8406 Propane 1.5548 37.316 6.8102 Isobutane 0.4611 11.067 2.0198 n -Butane 1.5844 38.025 6.9395 Isopentane 0.4984 11.962 2.1831 n -Pentane 0.7534 18.081 3.2997 Cyclopentane 0.2025 4.860 0.8869 n -Hexane 0.3550 8.521 1.5550 Cyclohexane 0.5325 12.781 2.3325 Other Hexanes 0.4064 9.754 1.7801 Heptanes 0.6113 14.671 2.6774 Methylcyclohexane 0.5456 13.094 2.3896 2,2,4-Trimethylpentane 0.0018 0.042 0.0077 Benzene 3.3091 79.418 14.4938 Toluene 4.2732 102.557 18.7167 Ethylbenzene 0.1590 3.816 0.6965 Xylenes 2.0427 49.024 8.9470 C8+ Heavies 0.1076 2.584 0.4715 Total Emissions 18.7828 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions UNCONTROLLED REGENERATOR EMISSIONS 18.7828 17.3988 10.1408 9.7840 450.788 82.2687 450.788 417.572 243.379 234.816 82.2687 76.2069 44.4166 42.8539 Component lbs/hr lbs/day tons/yr Methane 0.5074 12.177 2.2223 Ethane 0.8783 21.079 3.8469 Propane 1.5657 37.576 6.8576 Isobutane 0.4668 11.204 2.0447 n -Butane 1.6095 38.627 7.0495 Isopentane 0.5179 12.430 2.2684 n -Pentane 0.7927 19.025 3.4721 Cyclopentane 0.2149 5.156 0.9410 n -Hexane 0.3872 9.293 1.6960 Cyclohexane 0.6009 14.422 2.6321 Other Hexanes 0.4350 10.439 1.9052 Page 1 P-112 '(Aggregate Report, with condenser).txt Propane 4.27e-002 1.57e+000 Isobutane 1.27e-002 4.67e-001 n -Butane 4.39e-002 1.61e+000 Isopentane 1.43e-002 5.26e-001 n -Pentane 2.19e-002 8.04e-001 Cyclopentane 5.91e-003 2.17e-001 n -Hexane 1.07e-002 3.91e-001 Cyclohexane 1.72e-002 6.29e-001 Other Hexanes 1.21e-002 4.45e-001 Heptanes 2.05e-002 7.52e-001 Methylcyclohexane 1.94e-002 7.13e-001 2,2,4-Trimethylpentane 5.99e-005 2.20e-003 Benzene l.11e-001 4.08e+000 Toluene 1.81e-001 6.65e+000 Ethylbenzene 1.02e-002 3.75e-001 Xylenes 1.43e-001 5.25e+000 CB+ Heavies 8.65e-002 3.17e+000 Total Components 100.00 3.67e+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: 2.74e+003 scfh Component Conc. Loading (vol%) (lb/hr) Water 9.45e+001 1.23e+002 Carbon Dioxide 4.53e-001 1.44e+000 Nitrogen 1.45e-003 2.94e-003 Methane 4.38e-001 5.07e-001 Ethane 4.04e-001 8.78e-001 Propane 4.91e-001 1.57e+000 Isobutane l.11e-001 4.67e-001 n -Butane 3.83e-001 1.61e+000 Isopentane 9.93e-002 5.18e-001 n -Pentane 1.52e-001 7.93e-001 Cyclopentane 4.24e-002 2.15e-001 n -Hexane 6.22e-002 3.B7e-001 Cyclohexane 9.88e-002 6.01e-001 Other Hexanes 6.98e-002 4.35e-001 Heptanes 1.03e-001 7.46e-001 Methylcyclohexane 9.55e-002 6.78e-001 2,2,4-Trimethylpentane 2.60e-004 2.15e-003 Benzene 6.85e-001 3.87e+000 Toluene 9.18e-001 6.11e+000 Ethylbenzene 4.37e-002 3.35e-001 Xylenes 5.95e-001 4.57e+000 C8+ Heavies 2.30e-001 2.84e+000 Total Components 100.00 1.52e+002 CONDENSER VENT'.'GAS STREAM, Page 8 P-112 (Aggregate Report, with condenser).txt Temperature: 160.0,0 deg_ F Pressure: 12:00psia? Flow Rate:; 2.02e+002 scfh Component Conc.Loading (vole) (lb/hr),: Water 3.96e+001,379e+00.0=- Carbon Dioxide 6.14e+000, L 44e+00'0'- Nitrogen.1.98e-002 2?94e ,003` Methane.5-;95e+000-5.-07e001. Ethane 5.49e+000'8.77e=0Ql Propane` „63e+000,,,1 55e+.000' Isobutane=1.49e+000 4'.61e=001'; n=Butane.5.13e+000 158e+000' Isopentane'l.3'0e+0-00 4.98e --00l n -Pentane 1,96e+000 7`53e-0011 Cyclopentaie'5.43e-001 2.02e-001 n -Hexane 7.75t-001,3.SSe-001? Cyclohexane 1..19e+000. 5`.33e-.00-1 Other;'Hexanes'-8.87'n-001 4.06e=001-. Heptanes' 1.15e+000 6'.11e 001` Wethylcyclohexane 1 05 e+000 5, 46e -00l 2 2 4 Trimethylpentane 2 89e OD3.1_76e=003_*; Benzene 7,9rt7e+000 3r.31e+0.0D Toluene 8.72e+000;4�=.27e+000: Ethylbenene 2.82e 001, 1;59er00:T- • rxylene,s.3.62e+-00'0 2.,04e+000`r C8+ Heavies -1.19e-001 1t08e-001 TotalComponents 100 00 2"_4De+QO1 CONDENSER PRODUCED WATER STREAM Temperature: 160.00 deg. F Flow Rate: 2.39e-001 gpm Component Conc. Loading (wt%) (lb/hr) (ppm) Water 9.99e+001 1.19e+002 999352. Carbon Dioxide 3.16e-003 3.77e-003 32. Nitrogen 2.20e-007 2.63e-007 0. Methane 6.67e-005 7.96e-005 1. Ethane 1.23e-004 1.47e-004 1. Propane 2.76e-004 3.29e-004 3. Isobutane 4.28e-005 5.10e-005 0. n -Butane 1.87e-004 2.23e-004 2. Isopentane 3.92e-005 4.68e-005 0. n -Pentane 6.22e-005 7.42e-005 1. Cyclopentane 1.03e-004 1.23e-004 1. n -Hexane 2.26e-005 2.70e-005 0. Cyclohexane 1.69e-004 2.01e-004 2. Other Hexanes 2.14e-005 2.56e-005 0. Heptanes 2.06e-005 2.46e-005 0. Methylcyclohexane 8.01e-005 9.56e-005 1. 2,2,4-Trimethylpentane 4.07e-008 4.85e-008 0. Benzene 2.44e-002 2.92e-002 244. Toluene 2.43e-002 2.90e-002 243. Ethylbenzene 6.46e-004 7.71e-004 6. Xylenes 1.10e-002 1.31e-002 110. C8+ Heavies 9.98e-007 1.19e-006 0. Total Components 100.00 1.19e+002 1000000. Page 9 PROJECT NO. : COMPANY NAME : ACCOUNT NO. : PRODUCER . LEASE NO. : NAME/DESCRIP : ***FIELD DATA"` SAMPLE PRES. : COMMENTS : Componet Helium Hydrogen Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methycyclohexane 2,2,4 Trimethylpentane Benzene Toluene Ethylbenzene Xylenes C8+ Heavies Subtotal Oxygen/Argon Total EXTENDED NATURAL GAS ANALYSIS (*DHA) GLYCALC INFORMATION 201706129 DCP MIDSTREAM MARLA TEG DEHY INLET 915 NO PROBE SPOT ANALYSIS NO. : ANALYSIS DATE: SAMPLE DATE : CYLINDER NO. : SAMPLED BY : SAMPLE TEMP. : AMBIENT TEMP.: Mole % Wt % 0.00 0.00 0.00 0.00 2.51 4.74 0.24 0.29 70.37680 48.44640 14.7764 19.0658 7.0924 13.4201 0.9641 2.4046 2.3007 5.7381 0.5291 1.6381 0.5997 1.8566 0.0256 0.0770 0.1242 0.4593 0.0314 0.1134 0.1973 0.7258 0.0948 0.4056 0.0278 0.1171 0.0006 0.0030 0.0187 0.0627 0.0197 0.0779 0.0008 0.0036 0.0079 0.0360 0.0620 0.3189 100.00000 100.00000 0.00 0.00 100.00000 100.00000 07 JULY 05, 2017 14:34 JUNE 28, 2017 12:05 1943 MATT PICKETT The data presented herein has been acquired by means of current analytical techniques and represents the judicious conclusion EMPACT Analytical Systems, Inc. Results of the analysis can be affected by the sampling conditions, therefore, are only warranted through proper lab protocol. E/IB4CT assumes no responsibfity for interpretation or any consequences from application of the reported information and is the sole liability of the user. The reproduction it any media of this reported information may not be made, in portion or as a whole, without the written permission of EMPACT Analytical Systems, Inc. EMPACT Analytical Systems Inc. 365 S Main St Brighton, CO 80601 303-637-0150 Natural Gas Dehydration Marla Compressor Station DCP Operating Company, LP Source ID Description Manufacturer Model Serial it Start Date Operation _ Wet Gas Temperature Wet Gas Pressure Wet Gas Water Content Dry Gas Flow Rate Dry Gas Water Content Lean Glycol Water Content Lean Glycol Flow Rate Cold Separator? Cold Separator Temperature Cold Separator Pressure Glycol Pump Make & Model Glycol Pump Type Glycol Pump Gas Flow Rate Flash Tank? Flash Tank Temperature Flash Tank Pressure Flash Tank Control VRU Downtime P113 Dehydration Unit Custom TEG Dehydration Unit Custom Nov -05 8760 hr/yr 106 deg F 1000 psiq Saturated IbH2O/MMscf 55 MMscfd 7.0 IbH2O/MMscf 1.0 wt% H2O 8.20 gpm N Y/N N/A deg F N/A psig Kerr Triplex PD Electric Elec. or Gas N/A acfrn/qpm Y Y/N 160 deg F 55 psig 100.00% Recycled to Inlet 0.00% Routed. to ECD Stripping Gas? What is Stripping Gas? Stripping Gas Flow Rate Condenser?' Condenser Temperature Condenser Pressure Combustor? Combustor Ambient Air Temp Combustor Excess Oxygen Combustor Destruction Efficiency Combustor Downtime Total Emissions from GRI-GLYCaIc 4.0 N Y/N N/A scfm N Y/N deg F psia Y Y/N 60 deg F 0 % 95.00% 3.00% Uncontrolled Pollutant CAS Number Uncontrolled Emissions Controlled Emissions (lb/hr) (Ib/yr) (tpy) +20% (tpy) (lb/hr) (Ib/yr) (tpy) +20% (tpy) VOC 57.1 500408 250.20 300.24 2.7 23768 11.88 14.26 n -hexane 110-54-3 0.99 8649 4.32 5.19 0.04 352 0.18 0.21 Benzene 71-43-2 5.37 47034 23.52 28.22 0.41 3555 1.78 2.13 Toluene 108-88-3 8.26 72389 36.19 43.43 0.63 5534 2.77 3.32 Ethylbenzene 100-41-4 0.44 3893 1.95 2.34 0.03 301 0.15 0.18 Xylene 1330-20-7 6.01 52676 26.34 31.61 '0.47 4087 2.04 2.45 2,2,4-Trimethylpentane 540-84-1 0.00 37 0.02 0.02 0.00 1 0.00 0.001 Total HAP 21.08 184678 92.34 110.81 1.58 13830 6.92 8.30 Notes: The uncontrolled values include both flash and overhead still vent streams. The flash stream is controlled with a VRU @ 100% control. "The still vent stream is routed through a condenser (acting as a secondary control device), then to an enclosed combustor (ECD-1). Controlled emissions only consider control from ECD-1 Pollutant CAS Number Uncontrolled Emissions Flash Emissions' Still Vent Emissions' Total Dehy Emissions' Emission Factors (tpy) (tpy) (tpy) (Ib/yr) (lb/MMscf) VOC 98.82 151.39 250.20 29.9 n -Hexane 110-54-3 2.08 2.24 4.32 8649 0.5 Benzene 71-43-2 0.87 22.65 23.52 47034 2.8 Toluene 108-88-3 0.95 35.25 36.19 72389 4.3 Ethylbenzene 100-41-4 0.03 1.91 1.95 3893 0.2 Xylene 1330-20-7 0.31 26.03 26.34 52676 3.1 2,2,4 - Trimethylpentane 540-84-1 0.01 0.01 0.02 37 0.002 Total HAP 4.25 88.09 92.34 11.0 1.Flash emissions and still vent emissions (uncontrolled potential to emit) obtained from GlyCalc report dated July 2018. 2. Total dehy emissions calculated as a sum of Flash and Still Vent emissions. Still Vent Emissions Pollutant CAS Number Still Vent ECD Uptime Emissions' Still Vent ECD Downtime Emissions 4 Total Still Vent Emissions 5 (tpy) . (tpy) (tpy) VOC 7.342 4.542 11.88 n -Hexane 110-54-3 0.109 0.067 0.18 Benzene 71-43-2 1.098 0.679 1.78 Toluene 108-88-3 1.709 1.057 2.77 Ethylbenzene 100-41.4 0.093 0.057 0.15 Xylene 1330-20-7 1.262 0.781 2.04 2,2,4-Trimethylpentane 540-84-1 0.000 0.000 0.00 Total HAP 4.272 2.643 6.92 3. Still Vent ECD control emissions refer to still vent emissions controlled by the enclosed combustor (during 97% annual uptime). 4. ECD downtime emissions refer to emissions during a maximum of 3% enclosed combustor downtime for maintenance and malfunctions. 5. Total still vent emissions is a sum of still vent ECD control and ECD downtime emissions. Total Controlled Emissions (PTE[ Pollutant CAS Number Dehy Emissions' Dehy Emissions +20% Duffel' Overall System Control' (tpy) (tpy) VOC 11.88 14.26 95.3 n -Hexane 110-54-3 0.18 0.21 Benzene 71-43-2 1.78 2.13 Toluene 108-88-3 2.77 3.32 Ethylbenzene 100-41-4 0.15 0.18 Xylene 1330-20-7 2.04 2.45 2,2,4-Trimethylpentane 540-84-1 0.00 0.00 Total HAP 6.92 8.30 6. Total controlled dehydrator emissions calculated as a sum of controlled still vent emissions, combined with emissions during control device downtime 7. DCP is adding a 20% buffer to controlled emissions for variability in gas analysis and other actual parameters. 8. Demonstrating an overall system control of 95%, calculated as [100% - Total Controlled Dehy VOC Emissions / Total Uncontrolled Dehy Emissions] Natural Gas Dehydration Condenser Vent Stream Detail from GRI-GLYCaic 4.0 Description Vent Flow Rate Hours of operation Annual Flow Rate Condenser Vent Stream 326.00 scf/hr 8760 hr/yr 2.856 MMscf/yr Component Vol % Mol Fraction Pure Component Mol Weight (Ib/Ib-mol) Component Fraction Mol Weight (Ib/Ib-mol) Component Mass Fraction Pure Component Heat Value (Btu/scf) Component Fraction Heat Value (Btu/scf) Water 39.60 0.396 18.02 7.14 0.1347 0 0.0 Carbon Dioxide 10.30 0.103 44.01 4.53 0.0855 0 0.0 Hydrogen Sulfide 0.00 0 34.1 0.00 0.0000 0 0.0 Nitrogen 0.01 0.000141 28 0.00 0.0001 0 0.0 Methane 3.54 0.0354 16.04 0.57 0.0107 1010.0 35.8 Ethane 5.66 0.0566 30.07 1.70 0.0321 1769.6 100.2 Propane 6.84 0.0684 44.10 3.02. 0.0569 2516.1 172.1 i-Butane 1.45 0.0145 58.12 0.84 0.0159 3251.9 47.2 n -Butane 5.21 0.0521 58.12 3.03 0.0571 3262.3 170.0 i-Pentane 1.12 0.0112 72.15 0.81 0.0152 4000.9 44.8 n -Pentane 1.76 0.0178 72.15 1.28 0.0242 4008.9 71.4 Cyclopentane 0.60 0.0060 70.13 0.42 0.0079 3763.9 22.5 n -Hexane 0.66 0.0066 86.18 0.57 0.0107 4755.9 31.2 Cyclohexane 1.17 0.0117 84.16 0.98 0.0186 4481.5 52.4 Other Hexanes 0.74 0.0074 86.18 0.63 0.0120 4755.9 35.0 Heptanes 0.96 0.0096 100.20 0.96 0.0181 5502.5 52.8 Methylcyclohexane 0.98 0.0098 98.19 0.96 0.0181 5215.7 50.9 2,2,4-Trimethylpentane 0.002 0.0000 114.23 0.00 0,0000 6231,7 4.1 Benzene 7.00 0.0700 78.11 5.47 0.1032 3741.8 261.9 Toluene 8.12 0.0812 92.14 . 7.48 0.1412 4475.0 363.4 Ethylbenzene 0.294 0.0029 106.17 0.31 0.0059 5222.2 15.4 Xylenes 3.81 0.0381 . 318.50 12.13 0.2290 5208.8 198.5 Octanes + 0.129 0.0013 114.23 0.15 0.0028 6248.9 8.1 99.96 0.9996 52.99 1.00 1733 9. An additional GLYCaic run was performed including the condenser used as a secondary control device on unit P-113, to determine the waste gas flowrate and heat content going to the enclosed combustor. The primary GLYCaic run for this unit omits the condenser, to ensure that no condenser control is claimed in the overall emission calculations. Both the primary GLYCaic run, and an abridged version of the additional GLYCaic run, have been Included in Attachment C of this application. Emissions from Insignificant Activities Marla Compressor Station DCP Operating Company, LP 1�: x' Jill!.._,. 1 1 J.. a,: fl)d Z �Y); z , ( � 1* i1t W IY t o t l F$5n�tFc2� 1,000 gal, Methanol tank Regulation No. 3, tart C, Section II.E.3.a. -- — 0.02 -- -- 38.48 TANKS 4.0.9d 100 bbl, Methanol tank Regulation No. 3, Part C, Section II.E.3.a. -- — 0.06 — -- 113.96 TANKS 4.0.9d 1,000 gal Lube oil tank Regulation No. 3, Part C, Section II.E.3.aaa -- -- neg. -- -- -- 210 bbl, Lube oil tank Regulation No. 3, Part C, Section II.E.3.aaa -- --- neg. — --- -- 1,000 gal TEG glycol tank . Regulation No. 3, Part C, Section II.E.3.a. — -- neg. -- -- --- 1,000 gal Norkool glycol tank Regulation No. 3, Part C, Section II.E,3.e. — -- neg. -- --- --- 20 bbl slop oil tank Regulation No. 3, Part C, Section II.E.3.aaa --- -- neg. --- -- -- 30,000 gal Pressurized Condensate Storage Tank Regulation No. 3, Pert C, Section II.E.3.a. -- -- neg. -- — 30,000 gal Pressurized Condensate Storage Tank Regulation No. 3, Part C, Section II.E.3.a. -- -- neg. --- — -- Pressurized Condensate Truck Loadout Regulation No. 3, Part C, Section II.E.3.a. — --- 0.33 -- -- -- Engineering Estimate Dehy Reboiler H-112 - 0.85 MMBtu/hr Regulation No. 3, Part C, Section II.E.3.k. 0.36 0.31 0.02 -- -- 13.74 AP -42 Section 1.4, Table 1.4-1 Dehy Reboiler H-113 - 0.75 MMBtu/hr Regulation No. 3, Part C, Section II.E.3.k. 0.32 0.27 0.02 --- -- 12.12 AP -42 Section 1.4, Table 1.4-2 20 bbl, Stormwater tank - Regulation No. 3, Part C, Section II.E.3.a. — -- neg. -- -- --- 80 bbl, Stormwater tank Regulation No. 3, Part C, Section II.E.3.a. — — neg. --- -- 80 bbl, Stormwater tank Regulation No. 3, Part C, Section II.E.3.a. -- --- neg. — -- 80 bbl, Stormwater tank Regulation No. 3, Part C, Section II.E.3.a. — — neg. -- -- -- 80 bbl, Stormwater tank Regulation No. 3, Part C, Section II.E.3.a. -- -- neg. -- -- 80 bbl, Produced Water Tank Regulation No. 3, Part C, Section ll.E.3.uu. -- --- 0.16 8.58 26.98 35.57 PS Memo 09-02 80 bbl, Produced Water Tank Regulation No. 3, Part C, Section II.E.3.uu. — -- 0.16 8.58 26.98 35.57 PS Memo 09-02 80 bbl, Produced Water Tank Regulation No. 3, Part C, Section II.E.3.uu. --- --- 0.16 8.58 26.98 35.57 PS Memo 09-02 80 bbl, Produced Water Tank Regulation No. 3, Part C, Section II.E.3.uu. -- --- 0.16 8.58 26.98 35.57 PS Memo 09-02 110 bbl, Produced Water Tank Regulation No. 3, Part C, Section II.E.3.uu. -- -- 0.22 11.80 37.10 48.90 PS Memo 09-02 C-148 vent blowdown Regulation No. 3, Part C, Section II.E.3.a. --- — 0.99 4.53 33.18 37.71 Engineering Estimate C-135 vent blowdown Regulation No. 3, Part C, Section ll.E.3.a. — --- 0.99 4.53 33.18 37.71 Engineering Estimate C-151 vent blowdown Regulation No. 3, Part C, Section II.E.3.a. --- --- 0.99 4.53 33.18 37.71 Engineering Estimate C-166 vent blowdown Regulation No. 3, Part C, Section II.E.3.a. -- — 0.99 4.53 33.18 37.71 Engineering Estimate C-174 vent blowdown Regulation No. 3, Part C, Section II.E.3.a. — — 0.99 4.53 33.18 37.71 Engineering Estimate C-176 vent blowdown Regulation No. 3, Part C, Section II.E.3.a. -- — 0.99 4.53 33.18 37.71 Engineering Estimate 8" Launcher --> Mewbourn Regulation No. 3, Part C, Section II.E.3.a. --- — 0.99 4.24 32.92 37.16 Engineering Estimate 16" Launcher --> Enterprise Regulation No. 3, Part C, Section II.E.3.a. — -- 0.99 4.26 33.10 37.36 Engineering Estimate 12" Launcher --> Mewbourn Regulation No. 3, Part C, Section II.E.3.a. -- -- 0.96 4.11 31.94 36.05 Engineering Estimate 10" Inlet Reciever Regulation No. 3, Part C, Section II.E.3.a. --- — 0.33 1.50 10.96 12.45 Engineering Estimate 8" Inlet Reciever Regulation No. 3, Part C, Section II.E.3.a. — -- 0.26 1.20 8.77 9.97 Engineering Estimate 8" Inlet Reciever Regulation No. 3, Part C, Section II.E.3.a. -- 0.26 1.20 8.77 9.97 Engineering Estimate Facility Fugitive Emissions Regulation No. 3, Part C, Section II.E.3.a — -- 0.95 1.34 9.84 — EPA Publication No. 453\R-95-017 Table 2-8 Total Emissions from Insignificant Sources: 0.69 0.58 12.01 91.15 480.42 738.70 Enclosed Combustor Emissions Marla Compressor Station DCP Operating Company, LP Enclosed Combustor Pilot Gas: 50 scf/hr Assist Gas: 100 scf/hr Total Natural Gas Usage: 150 scf/hr Fuel Heating Value: 1,020 BTU/SCF Hours per Year: 8,760 hr/yr Fuel Use: - 1.31 MMSCF/yr Overheads Flow Rate (P-112): 1.77 MMSCF/yr Overheads Flow Rate (P-113): 2.86 MMSCF/yr Pilot + Assist Gas usage split equally between P-112 and P-113 670 3,257 3,927 Total MMBTU/yr P-112 MMBTU/yr pilot & assist gas MMBTU/yr from P-112 condenser vent 670 4,950 5,620 Total MMBTU/yr P-113 MMBTU/yr pilot & assist gas MMBTU/yr from P-113 condenser vent Criteria Pollutant Emission Calculations Emission Factors (Ib/mmbtu) Emissions (P112) (ton/yr) Emissions (P113) (ton/yr) Pollutant NOx 0.068 0.13 0.19 CO 0.31 0.61 0.87 1. AP -42 Table 13.5-1 ECD Emission Calculations: Assist & Pilot Gas Heat Input: MMBtu = Fuel Use MMscf * FHV Btu yr yr scf P-112 and P-113 share a single ECD; the combustion emissions from assist/pilot gas are split equally between each Regenerator Overhead Stream Heat Input MMBtu = (P112 / P113 Condenser Vent Rate MMscf * P112 / P113 CondenserHHV Btu ) yr yr scf Condenser Vent Rates and HHVs determined from individual GLYCaIc Runs, dated July 2018. EXTENDED NATURAL GAS ANALYSIS (*DHA) GLYCALC INFORMATION PROJECT NO. : 201706129 COMPANY NAME : DCP MIDSTREAM ACCOUNT NO. : PRODUCER : LEASE NO. : NAME/DESCRIP : MARLA TEG DENY INLET ***FIELD DATA*** SAMPLE PRES. : COMMENTS : Componet Helium Hydrogen Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methycyclohexane 2,2,4 Trimethylpentane Benzene Toluene Ethylbenzene Xylenes C8+ Heavies Subtotal Oxygen/Argon Total 915 NO PROBE SPOT ANALYSIS NO.: 07 ANALYSIS DATE: JULY 05, 2017 14:34 SAMPLE DATE : JUNE 28, 2017 12:05 CYLINDER NO.: 1943 SAMPLED BY MATT PICKETT Mole % 0.00 0.00 2.51 0.24 70.37680 14.7764 7.0924 0.9641 2.3007 0.5291 0.5997 0.0256 0.1242 0.0314 0.1973 0.0948 0.0278 0.0006 0.0187 0.0197 0.0008 0.0079 0.0620 100.00000 0.00 SAMPLE TEMP. : AMBIENT TEMP.: Wt% 0.00 0.00 4.74 0.29 48.44640 19.0658 13.4201 2.4046 5.7381 1.6381 1.8566 0.0770 0.4593 0.1134 0.7258 0.4056 0.1171 0.0030 0.0627 0.0779 0.0036 0.0360 0.3189 100.00000 0.00 100.00000 100.00000 The data presented herein has been acquired by means of current analytical techniques and represents the judicious conclusion EMPACT Analytical Systems, inc. Results of the analysis can be affected by the sampling conditions, therefore, are only warranted through proper lab protocol EIIPACT assumes no responsibility for interpretation or any consequences from application of the reported information and is the sole liability of the user. The reproduction in any media of this reported information may not be made. in portion or as a whole, without the written permission of EMPACT Analytical Systems, Inc. EMPACT Analytical Systems Inc. 365 S Main St Brighton, CO 80601 303-637-0150 P-113 (Aggregate Report, with condenser).txt Temperature: 160.00 deg. :F Pressure:12.00 psia Flow Rate:, 3.26e+002, scfh Component; Conc 5° (vol%) Loading (lb/hr) Water 3.96e+001 6.13e+000 Carbon Dioxide 1.03e+001 3.91e+000` Nitrogen .1.41e -002.3.40e-003. Methane 3.54e+000 4.89e-001. Ethane 5.66e+000.1.46e+000. Propane 6.84e+000 2;60e+000• Isobutane l.45e+000 7,25e-001 n -.Butane 5.21e+000 2.60e+000 Isopentane 1_12e+000 6.94e-001 n -Pentane 1.78e+000 1.10e+000: Cyclopentane 5.99e-001 3.61e-001 n -Hexane 6.57e-001 487e-001: Cyclohexane 1.17e+00O 8.48e-001; Other Hexanes 7.35e -0.01_5.45e -.001: Heptanes 9:59e-001 8.26e-001; Methylcyclohexane 9 75e-0al 8.23e-001. 2' 2, 4 ,Trmethylpentane_ 1,....9.6.e.7'003 1.93e-003 Benzene 7.00e+000 4.70e+000 Toluene 8.12e+000 6.44e+000' Ethylbenzene 2.94e.-001 2.68e-001 Xylenes 3.81e+000 3.48e+000 C8+ Heavies 1.29e-001 1.89e-001 Total Components 100.00 3.87e+001 CONDENSER PRODUCED WATER STREAM Temperature: 160.00 deg. F Flow Rate: 2.89e-001 gpm Component Conc. Loading (wt%) (lb/hr) (ppm) Water 9.99e+001 1.45e+002 999371. Carbon Dioxide 5.32e-003 7.70e-003 53. Nitrogen 1.57e-007 2.27e-007 0. Methane 3.97e-005 5.74e-005 0. Ethane 1.27e-004 1.83e-004 1. Propane 2.84e-004 4.12e-004 3. Isobutane 4.15e-005 6.01e-005 0. n -Butane 1.90e-004 2.74e-004 2. Isopentane 3.38e-005 4.89e-005 0. n -Pentane 5.62e-005 8.14e-005 1. Cyclopentane 1.14e-004 1.65e-004 1. n -Hexane 1.92e-005 2.77e-005 0. Cyclohexane 1.66e-004 2.40e-004 2. Other Hexanes 1.78e-005 2.57e-005 0. Heptanes 1.72e-005 2.49e-005 0. Methylcyclohexane 7.47e-005 1.08e-004 1. 2,2,4-Trimethylpentane 2.76e-008 3.99e-008 0. Benzene 2.15e-002 3.11e-002 215. Toluene 2.27e-002 3.28e-002 227. Ethylbenzene 6.73e-004 9.74e-004 7. Xylenes 1.16e-002 1.68e-002 116. C8+ Heavies 1.09e-006 1.57e-006 0. Total Components 100.00 1.45e+002 1000000. Page 9 P-113 (Aggregate Report, with condenser).txt Propane 5.42e-002 2.61e+000 Isobutane 1.52e-002 7.30e-001 n -Butane 5.47e-002 2.63e+000 Isopentane 1.50e-002 7.20e-001 n -Pentane 2.39e-002 1.15e+00O Cyclopentane 7.84e-003 3.77e-001 n -Hexane 1.08e-002 5.17e-001 Cyclohexane 1.97e-002 9.48e-001 Other Hexanes 1.21e-002 5.80e-001 Heptanes 1.95e-002 9.38e-001 Methylcyclohexane 2.05e-002 9.85e-001 2,2,4-Trimethylpentane 4.66e-005 2.24e-003 Benzene 1.13e-001 5.45e+000 Toluene 1.82e-001 8.76e+000 Ethylbenzene 1.02e-002 4.89e-001 Xylenes 1.42e-001 6.84e+000 C8+ Heavies 7.01e-002 3.37e+000 Total Components 100.00 4.80e+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: 3.40e+003 scfh Component Conc. Loading (vol%) (lb/hr) Water 9.34e+001 1.51e+002 Carbon Dioxide 9.95e-001 3.92e+000 Nitrogen 1.35e-003 3.40e-003 Methane 3.40e-001 4.89e-001 Ethane 5.44e-001 1.46e+000 Propane 6.60e-001 2.61e+000 Isobutane 1.40e-001 7.30e-001 n -Butane 5.05e-001 2.63e+000 Isopentane 1.10e-001 7.10e-0,01 n -Pentane 1.75e-001 1.13e+000 Cyclopentane 5.95e-002 3.74e-001 n -Hexane 6.63e-002 5.12e-001 Cyclohexane 1.21e-001 9.11e-001 Other Hexanes 7.34e-002 5.67e-001 Heptanes 1.04e-001 9.31e-001 Methylcyclohexane 1.07e-001 9.38e-001 2,2,4-Trimethylpentane 2.12e-004 2.17e-003 Benzene 7.39e-001 5.17e+000 Toluene 9.75e-001 8.05e+000 Ethylbenzene 4.59e-002 4.37e-001 Xylenes 6.25e-001 5.94e+000 C8+ Heavies 1.91e-001 2.92e+000 Total Components 100.00 1.91e+002 CONDENSER VENT?=GAS STREAM _ Page 8 P-113 (Aggregate Report, with condenser).txt GRI-GLYCalc VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name: Marla P113 - Condenser Added for Still Vent BTU content ONLY File Name: \\dennas00\Data\Environmental\Aisr\Colorado\Marla\2018-06 TV Sig Mod - Remove TEG Condenser\02. Emissions\GLYCalc\P113\P113 (6-2017 EGA, + condenser).ddf Date: July 02, 2018 DESCRIPTION: Description: 55.0 MMscfd TEG Dehydrator Marla Inlet EGA dated 6/2017 8.20 gpm TEG recirculation rate Condenser for Still Vent BTU content ONLY Annual Hours of Operation: 8760.0 hours/yr EMISSIONS REPORTS: CONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.4887 11.728 2.1404 Ethane 1.4635 35.123 6.4100 Propane 2.5956 62.295 11.3688 Isobutane 0.7249 17.398 3.1751 n -Butane 2.6039 62.493 11.4051 Isopentane 0.6942 16.660 3.0404 n -Pentane 1.1018 26.443 4.8259 Cyclopentane 0.3613 8.672 1.5826 n -Hexane 0.4868 11.682 2.1320 Cyclohexane 0.8478 20.347 3.7133 Other Hexanes 0.5450 13.080 2.3871 Heptanes 0.8264 19.833 3.6195 Methylcyclohexane 0.8232 19.757 3.6056 2,2,4-Trimethylpentane 0.0019 0.046 0.0084 Benzene 4.7043 112.904 20.6050 Toluene 6.4366 154.478 28.1922 Ethylbenzene 0.2682 6.436 1.1745 Xylenes 3.4832 83.597 15.2565 C8+ Heavies 0.1894 4.546 0.8297 Total Emissions 28.6466 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions UNCONTROLLED REGENERATOR EMISSIONS 28.6466 26.6945 15.3810 14.8923 687.519 125.4723 687.519 640.668 369.143 357.415 125.4723 116.9218 67.3686 65.2262 Component lbs/hr lbs/day tons/yr Methane 0.4868 11.732 2.1411 Ethane 1.4649 35.158 6.4163 Propane 2.6062 62.549 11.4152 Isobutane 0.7301 17.523 3.1979 n -Butane 2.6278 63.068 11.5099 Isopentane 0.7097 17.032 3.1084 n -Pentane 1.1343 27.223 4.9681 Cyclopentane 0.3741 8.979 1.6387 n -Hexane 0.5122 12.293 2.2435 Cyclohexane 0.9105 21.853 3.9882 Other Hexanes 0.5672 13.612 2.4842 Page 1 P-113 (Inputs Report, with condenser).txt FLASH TANK: Flash Control: Recycle/recompression Temperature: 160.0 deg. F Pressure: 55.0 psig REGENERATOR OVERHEADS CONTROL DEVICE: Control De�ice:'Condenser- Temperature:' 360.0 -deg.!. FI Pressure:', 12 O'psa^ Page 2 P-113 (Inputs Report, with condenser).txt GRI-GLYCalc VERSION 4.0 - SUMMARY OF INPUT VALUES Case Name: Marla P113 - Condenser Added for Still Vent BTU content ONLY File Name: \\dennas00\Data\Environmental\Air\Colorado\Marla\2018-06 TV Sig Mod - Remove TEG Condenser\02. Emissions\GLYCalc\P113\P113 (6-2017 EGA, + condenser).ddf Date: July 02, 2018 DESCRIPTION: Description: 55.0 MMscfd TEG Dehydrator Marla Inlet EGA dated 6/2017 8.20 gpm TEG recirculation rate -Condenser,for Still Vent BTU content ONLY; Annual Hours of Operation: 8760.0 hours/yr WET GAS: Temperature: Pressure: 106.00 deg. F 1000.00 psig Wet Gas Water Content: Saturated Component Conc. (vol %) Carbon Dioxide 2.5100 Nitrogen 0.2400 Methane 70.3768 Ethane 14.7764 Propane 7.0924 Isobutane 0.9641 n -Butane 2.3007 Isopentane 0.5291 n -Pentane 0.5997 Cyclopentane 0.0256 n -Hexane 0.1242 Cyclohexane 0.0314 Other Hexanes 0.1973 Heptanes 0.0948 Methylcyclohexane 0.0278 2,2,4-Trimethylpentane 0.0006 Benzene 0.0187 Toluene 0.0197 Ethylbenzene 0.0008 Xylenes 0'.0079 C8+ Heavies 0.0620 DRY GAS: Flow Rate: 55.0 MMSCF/day Water Content: 7.0 lbs. H2O/MMSCF LEAN GLYCOL: Glycol Type: TEG Water Content: Flow Rate: PUMP: 1.0 wt% H2O 8.2 gpm Glycol Pump Type: Electric/Pneumatic Page 1 P-113 (Aggregate Report, no condenser).txt GRI-GLYCalc VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name: Marla P113 File Name: \\dennas00\Data\Environmental\Air\Colorado\Marla\2018-06 TV Sig Mod Remove TEG Condenser\02. Emissions\GLYCalc\P113\P113 (6-2017 EGA).ddf Date: July 02, 2018 DESCRIPTION: Description: 55.0 MMscfd TEG Dehydrator Marla Inlet EGA dated 6/2017 8.20 gpm TEG recirculation rate Annual Hours of Operation: 8760.0 hours/yr EMISSIONS REPORTS: UNCONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.4888 11.732 2.1411 Ethane 1.4649 35.158 6.4163 Propane 2.6062 62.549 11.4152 Isobutane 0.7301 17.523 3.1979 n -Butane 2.6278 63.068 11.5099 Isopentane 0.7097 17.032 3.1084 n -Pentane 1.1343 27.223 4.9681 Cyclopentane 0.3741 8.979 1.6387 n -Hexane 0.5122 12.293 2.2435 Cyclohexane 0.9105 21.853 3.9882 Other Hexanes 0.5672 13.612 2.4842 Heptanes 0.9315 22.355 4.0799 Methylcyclohexane 0.9381 22.514 4.1088 2,2,4-Trimethylpentane 0.0022 0.052 0.0095 Benzene 5.1702 124.085 22.6455 Toluene 8.0474 193.138 35.2476 Ethylbenzene 0.4371 10.490 1.9144 Xylenes 5.9429 142.631 26.0301 C8+ Heavies 2.9221 70.130 12.7987 Total Emissions 36.5173 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions FLASH GAS EMISSIONS 36.5173 34.5636 20.1120 19.5976 876.416 159.9459 876.416 829.526 482.689 470.343 159.9459 151.3885 88.0907 85.8376 Note: Flash Gas Emissions are zero with the Recycle/recompression control option. FLASH TANK OFF GAS Component lbs/hr lbs/day tons/yr Methane 11.4210 274.103 50.0238 Ethane 10.9376 262.502 47.9066 Propane 9.3182 223.636 40.8136 Isobutane 1.8702 44.885 8.1916 n -Butane 5.3071 127.371 23.2453 Page 1 P-113 (Aggregate Report, no condenser(.txt Isopentane 1.3228 31.747 5.7938 n -Pentane 1.7463 41.912 7.6490 Cyclopentane 0.1502 3.604 0.6578 n -Hexane 0.4751 11.402 2.0810 Cyclohexane 0.2195 5.269 0.9616 Other Hexanes 0.6774 16.257 2.9669 Heptanes 0.4613 11.071 2.0204 Methylcyclohexane 0.1871 4.489 0.8193 2,2,4-Trimethylpentane 0.0021 0.049 0.0090 Benzene 0.1990 4.776 0.8717 Toluene 0.2163 5.192 0.9475 Ethylbenzene 0.0073 0.176 0.0321 Xylenes 0.0703 1.688 0.3081 C8+ Heavies 0.3310 7.945 1.4500 Total Emissions 44.9199 Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions EQUIPMENT REPORTS: 44.9199 22.5613 0.9702 0.4930 1078.077 196.7490 1078.077 196.7490 541.472 98.8186 23.284 4.2493 11.832 2.1594 ABSORBER NOTE: Because the Calculated Absorber Stages was below the minimum allowed, GRI-GLYCalc has set the number o£ Absorber Stages to 1.25 and has calculated a revised Dry Gas Dew Point. Calculated Absorber Stages: 1.25 Calculated Dry Gas Dew Point: 4.13 lbs. H2O/MMSCF Temperature: 106.0 deg. F Pressure: 1000.0 psig Dry Gas Flow Rate: 55.0000 MMSCF/day Glycol Losses with Dry Gas: 2.8098 lb/hr Wet Gas Water Content: Saturated Calculated Wet Gas Water Content: 69.88 lbs. H2O/MMSCF Calculated Lean Glycol Recirc. Ratio: 3.26 gal/lb H2O Remaining Absorbed Component in Dry Gas in Glycol Water 5.89% 94.11% Carbon Dioxide 99.80% 0.20% Nitrogen 99.98% 0.02% Methane 99.98% 0.02% Ethane 99.95% 0.05% Propane 99.94% 0.06% Isobutane 99.92% 0.08% n -Butane 99.90% 0.10% Isopentane 99.91% 0.09% n -Pentane 99.89% 0.11% Cyclopentane. 99.52% 0.48% n -Hexane 99.85% 0.15% Cyclohexane 99.29% 0.71% Other Hexanes 99.88% 0.12% Heptanes 99.76% 0.24% Methylcyclohexane 99.32% 0.68% 2,2,4-Trimethylpentane 99.90% 0.10% Benzene 93.92% 6.08% Toluene 92.46% 7.54% Page 2 (1% P-113 (Aggregate Report, no condenser).txt Ethylbenzene 91.34% 8.66% Xylenes C8+ Heavies FLASH TANK 88.13% 11.87% 99.49% 0.51% Flash Control: Recycle/recompression Flash Temperature: 160.0 deg. F Flash Pressure: 55.0 psig Component Left in Removed in Glycol Flash Gas Water 99.89% 0.11% Carbon Dioxide 28.88% 71.12% Nitrogen 3.98% 96.02% Methane 4.10% 95.90% Ethane 11.81% 88.19% Propane 21.86% 78.14% Isobutane 28.08% 71.92% n -Butane 33.12% 66.88% Isopentane 35.24% 64.76% n -Pentane 39.68% 60.32% Cyclopentane 71.50% 28.50% n -Hexane 52.12% 47.88% Cyclohexane 81.19% 18.81% Other Hexanes 46.12% 53.88% Heptanes 67.04% 32.96% Methylcyclohexane 84.04% 15.96% 2,2,4-Trimethylpentane 52.11% 47.89% Benzene 96.48% 3.52% Toluene 97.59% 2.41% Ethylbenzene 98.52% 1.48% Xylenes 98.98% 1.02% C8+ Heavies 91.05% 8.95% REGENERATOR No Stripping Gas used in regenerator. Remaining Distilled Component in Glycol Overhead Water 23.44% 76.56% 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 1.42% 98.58% n -Pentane 1.26% 98.74% Cyclopentane 0.70% 99.30% n -Hexane 0.96% 99.04% Cyclohexane 3.94% 96.06% Other Hexanes 2.17% 97.83% Heptanes 0.75% 99.25% Methylcyclohexane 4.76% 95.24% 2,2,4-Trimethylpentane 2.88% 97.12% Benzene 5.18% 94.82% Toluene 8.10% 91.90% Ethylbenzene 10.57% 89.43% Page 3 I P-113 (Aggregate Report, no condenser(.txt Xylenes C8+ Heavies STREAM REPORTS: 13.08% 86.92% 13.22% 86.78% WET GAS STREAM Temperature: 106.00 deg. F Pressure: 1014.70 psia Flow Rate: 2.30e+006 scfh Component Conc. Loading (vol%) (lb/hr) Water 1.47e-001 1.60e+002 Carbon Dioxide 2.51e+000 6.67e+003 Nitrogen 2.40e-001 4.06e+002 Methane 7.03e+001 6.82e+004 Ethane 1.48e+001 2.68e+004 Propane 7.08e+000 1.89e+004 Isobutane 9.63e-001 3.39e+003 n -Butane 2.30e+000 8.08e+003 Isopentane 5.28e-001 2.31e+003 n -Pentane 5.99e-001 2.61e+003 Cyclopentane 2.56e-002 1.08e+002 n -Hexane 1.24e-001 6.47e+002 Cyclohexane 3.14e-002 1.60e+002 Other Hexanes 1.97e-001 1.03e+003 Heptanes 9.47e-002 5.74e+002 Methylcyclohexane 2.78e-002 1.65e+002 2,2,4-Trimethylpentane 5.99e-004 4.14e+000 Benzene 1.87e-002 8.83e+001 Toluene 1.97e-002 1.10e+002 Ethylbenzene 7.99e-004 5.13e+000 Xylenes 7.89e-003 5.07e+001 C8+ Heavies 6.19e-002 6.38e+002 Total Components 100.00 1.41e+005 DRY GAS STREAM Temperature: Pressure: Flow Rate: 106.00 deg. F 1014.70 psia 2.29e+006 scfh Component Conc. Loading (vol%) (lb/hr) Water 8.69e-003 9.46e+000 Carbon Dioxide 2.51e+000 6.66e+003 Nitrogen 2.40e-001 4.06e+002 Methane 7.04e+001 6.82e+004 Ethane 1.48e+001 2.68e+004 Propane 7.09e+000 1.89e+004 Isobutane 9.64e-001 3.38e+003 n -Butane 2.30e+000 8.07e+003 Isopentane 5.29e-001 2.30e+003 n -Pentane 5.99e-001 2.61e+003 Cyclopentane 2.55e-002 1.08e+002 n -Hexane 1.24e-001 6.46e+002 Cyclohexane 3.12e-002 1.59e+002 Other Hexanes 1.97e-001 1.03e+003 Page 4 j P-113 (Aggregate Report, no condenser).txt Heptanes 9.46e-002 5.73e+002 Methylcyclohexane 2.76e-002 1.64e+002 2,2,4-Trimethylpentane 6.00e-004 4.14e+000 Benzene 1.76e-002 8.29e+001 Toluene 1.82e-002 1.01e+002 Ethylbenzene 7.31e-004 4.69e+000 Xylenes 6.96e-003 4.47e+001 CB+ Heavies 6.17e-002 6.35e+002 Total Components 100.00 1.41e+005 LEAN GLYCOL STREAM Temperature: 106.00 deg. F Flow Rate: 8.19e+000 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9.89e+001 4.57e+003 Water 1.00e+000 4.62e+001 Carbon Dioxide 2.94e-011 1.36e-009 Nitrogen 1.85e-013 8.56e-012 Methane 8.67e-018 4.00e-016 Ethane 1.27e-007 5.85e-006 Propane 1.05e-008 4.85e-007 Isobutane 1.69e-009 7.80e-008 n -Butane 4.26e-009 1.97e-007 Isopentane 2.21e-004 1.02e-002 n -Pentane 3.14e-004 1.45e-002 Cyclopentane 5.71e-005 2.63e-003 n -Hexane 1.08e-004 4.96e-003 Cyclohexane 8.09e-004 3.74e-002 Other Hexanes 2.72e-004 1.26e-002 Heptanes 1.52e-004 7.00e-003 Methylcyclohexane 1.02e-003 4.69e-002 2,2,4-Trimethylpentane 1.40e-006 6.44e-005 Benzene 6.12e-003 2.83e-001 Toluene 1.54e-002 7.09e-001 Ethylbenzene 1.12e-003 5.17e-002 Xylenes 1.94e-002 8.94e-001 C8+ Heavies 9.65e-003 4.45e-001 Total Components 100.00 4.62e+003 RICH GLYCOL STREAM Temperature: 106.00 deg. F Pressure: 1014.70 psia Flow Rate: 8.70e+000 gpm NOTE: Stream has more than one phase. Component Conc. Loading (wt%) (lb/hr) TEG 9.39e+001 4.56e+003 Water 4.06e+000 1.97e+002 Carbon Dioxide 2.80e-001 1.36e+001 Nitrogen 1.76e-003 8.54e-002 Methane 2.45e-001 1.19e+001 Ethane 2.55e-001 1.24e+001 Propane 2.45e-001 1.19e+001 Isobutane 5.35e-002 2.60e+000 n -Butane 1.63e-001 7.94e+000 Isopentane 4.20e-002 2.04e+000 Page 5 P-113 (Aggregate Report, no condenser).txt n -Pentane 5.96e-002 2.90e+000 Cyclopentane 1.08e-002 5.27e-001 n -Hexane 2.04e-002 9.92e-001 Cyclohexane 2.40e-002 1.17e+000 Other Hexanes 2.59e-002 1.26e+000 Heptanes 2.88e-002 1.40e+000 Methylcyclohexane 2.41e-002 1.17e+000 2,2,4-Trimethylpentane 8.84e-005 4.29e-003 Benzene 1.16e-001 5.65e+000 Toluene 1.85e-001 6.97e+000 Ethylbenzene 1.02e-002 4.96e-001 Xylenes 1.42e-001 6.91e+000 C8+ Heavies 7.61e-002 3.70e+000 Total Components 100.00 4.86e+003 FLASH TANK OFF GAS STREAM Temperature: Pressure: Flow Rate: 160.00 deg. F 69.70 psia 6.53e+002 scfh Component Conc. Loading (vol%) (lb/hr) Water 7.14e-001 2.21e-001 Carbon Dioxide 1.28e+001 9.66e+000 Nitrogen 1.70e-001 8.20e-002 Methane 4.14e+001 1.14e+001 Ethane 2.11e+001 1.09e+001 Propane 1.23e+001 9.32e+000 Isobutane 1.87e+000 1.87e+000 n -Butane 5.31e+000 5.31e+000 Isopentane 1.07e+000 1.32e+000 n -Pentane 1.41e+000 1.75e+000 Cyclopentane 1.24e-001 1.50e-001 n -Hexane 3.21e-001 4.75e-001 Cyclohexane 1.52e-001 2.20e-001 Other Hexanes 4.57e-001 6.77e-001 Heptanes 2.68e-001 4.61e-001 Methylcyclohexane 1.11e-001 1.87e-001 2,2,4-Trimethylpentane 1.05e-003 2.06e-003 Benzene 1.48e-001 1.99e-001 Toluene 1.37e-001 2.16e-001 Ethylbenzene 4.01e-003 7.32e-003 Xylenes 3.65e-002 7.03e-002 C8+ Heavies 1.13e-001 3.31e-001 Total Components 100.00 5.49e+001 FLASH TANK GLYCOL STREAM Temperature: 160.00 deg. F Flow Rate: 8.58e+000 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9.50e+001 4.56e+003 Water 4.10e+000 1.97e+002 Carbon Dioxide 8.17e-002 3.92e+000 Nitrogen 7.07e-005 3.40e-003 Methane 1.02e-002 4.69e-001 Ethane 3.05e-002 1.46e+000 Propane 5.42e-002 2.61e+000 Isobutane 1.52e-002 7.30e-001 Page 6 P-113 (Aggregate Report, no condenser).txt n -Butane 5.47e-002 2.63e+000 Isopentane 1.50e-002 7.20e-001 n -Pentane 2.39e-002 1.15e+000 Cyclopentane 7.84e-003 3.77e-001 n -Hexane 1.08e-002 5.17e-001 Cyclohexane 1.97e-002 9.48e-001 Other Hexanes 1.21e-002 5.80e-001 Heptanes 1.95e-002 9.38e-001 Methylcyclohexane 2.05e-002 9.85e-001 2,2,4-Trimethylpentane 4.66e-005 2.24e-003 Benzene 1.13e-001 5.45e+000 Toluene 1.82e-001 8.76e+000 Ethylbenzene 1.02e-002 4.89e-001 Xylenes 1.42e-001 6.84e+000 C8+ Heavies 7.01e-002 3.37e+000 Total Components 100.00 4.80e+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: 3.40e+003 scfh Component Conc. Loading (vol%( (lb/hr) Water 9.34e+001 1.51e+002 Carbon Dioxide 9.95e-001 3.92e+000 Nitrogen 1.35e-003 3.40e-003 Methane 3.40e-001 4.89e-001 Ethane 5.44e-001 1.46e+000 Propane 6.60e-001 2.61e+000 Isobutane 1.40e-001 7.30e-001 n -Butane 5.05e-001 2.63e+000 Isopentane 1.10e-001 7.10e-001 n -Pentane 1.75e-001 1.13e+000 Cyclopentane 5.95e-002 3.74e-001 n -Hexane 6.63e-002 5.12e-001 Cyclohexane 1.21e-001 9.11e-001 Other Hexanes 7.34e-002 5.67e-001 Heptanes 1.04e-001 9.31e-001 Methylcyclohexane 1.07e-001 9.38e-001 2,2,4-Trimethylpentane 2.12e-004 2.17e-003 Benzene 7.39e-001 5.17e+000 Toluene 9.75e-001 8.05e+000 Ethylbenzene 4.59e-002 4.37e-001 Xylenes 6.25e-001 5.94e+000 CB+ Heavies 1.91e-001 2.92e+000 Total Components 100.00 1.91e+002 Page 7 P-113 (Inputs Report, no condenser).txt GRI-GLYCalc VERSION 4.0 - SUMMARY OF INPUT VALUES Case Name: Marla P113 File Name: \\dennas00\Data\Environmental\Air\Colorado\Marla\2018-06 TV Sig Mod - Remove TEG Condenser\02. Emissions\GLYCalc\P113\P113 (6-2017 EGA).ddf Date: July 02, 2018 DESCRIPTION: Description: 55.0 MMscfd TEG Dehydrator Marla Inlet EGA dated 6/2017 8.20 gpm TEG recirculation rate Annual Hours of Operation: 8760.0 hours/yr WET GAS: Temperature: Pressure: 106.00 deg. F 1000.00 psig Wet Gas Water Content: Saturated Component Conc. (vol %) Carbon Dioxide 2.5100 Nitrogen 0.2400 Methane 70.3768 Ethane 14.7764 Propane 7.0924 Isobutane 0.9641 n -Butane 2.3007 Isopentane 0.5291 n -Pentane 0.5997 Cyclopentane 0.0256 n -Hexane 0.1242 Cyclohexane 0.0314 Other Hexane's 0.1973 Heptanes 0.0948 Methylcyclohexane 0.0278 2,2,4-Trimethylpentane 0.0006 Benzene 0.0187 Toluene 0.0197 -Ethylbenzene 0.0008 Xylenes 0.0079 C8+ Heavies 0.0620 DRY GAS: Flow Rate: 55.0 MMSCF/day Water Content: 7.0 lbs. H2O/MMSCF LEAN GLYCOL: Glycol Type: TEG Water Content: Flow Rate: PUMP: 1.0 wt% H2O 8.2 gpm Glycol Pump Type: Electric/Pneumatic Page 1 P112 / P113 Glycol Dehy Calculations Uncontrolled Emissions Uncontrolled Emissions are taken directly from GLYCaIc. Emission Factor lb = Uncontrolled Emissions tons * 2,000 lb * day * 1 year MMscf year ton Dehy Throughput MMscf 365 days Regen / Still Vent Emissions ECD Uptime Emissions tons = Uncontrolled Regen Emissions tons * ( 1- ECD downtime percentage) * ( 1- ECD Control Efficiency) year year Regen /Still Vent is controlled with ECD that has a control efficiency of 95%. ECD has a 3.0% annual downtime associated with maintenance and repairs, during which emissions for the still vent, vent to atmosphere. ECD Downtime Emissions tons = Uncontrolled. Regen Emissions tons * ( ECD Downtime Percentage) year year Still Vent emissions are vented to atmosphere during 3.0% annual ECD downtime. Total Regen Emissions = ECD uptime emissions + ECD downtime emissions Total Dehy Emissions Total Dehy Emissions = Total Regen Emissions Overall Control Efficiency = 1- Total Dehv VOC Emissions Attachment E Colorado Title V Operating Permit Forms Marla Compressor Station Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division FACILITY IDENTIFICATION SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-100 Rev 06-95 1. Facility name and mailing address Name Street or Route City, State, Zip Code Marla Compressor Station 370 17th Street, Suite 2500 Denver, Colorado 80202 2. Facility location (No P.O. Box) Street Address SESE Section 28, T4N, R64W City, County, Zip Code South of Kersey (Kersey, Weld County, CO 80644) 3. Parent corporation Name Street or Route City, State, Zip Code Country (if not U.S.) DCP Operating Company, LP 370 17th Street, Suite 2500 Denver, Colorado 80202 4. Responsible official Name Title Telephone David M. Jost Vice President of Northern Operations 970-378-6345 5. Permit contact person (If Different than 4) Name Title Telephone Roshini Shankaran Senior Environmental Engineer 303-605-2039 6. Facility SIC code: 4922 7. Facility identification code: CO 123-0243 8. Federal Tax I. D. Number: 841041166 9. Primary activity of the operating establishment: Natural Gas Liquids Processing and Compression 10. Type of operating permit ❑ New x Modified ❑ Renewal 11. Is the facility located in a "nonattainment" area: X Yes ❑ No If "Yes", check the designated "non -attainment" pollutant(s): ❑ Carbon Monoxide x Ozone ❑ PM10 ❑ Other (specify) 12. List all (Federal and State) air pollution permits (including grandfathered units), plan approvals and exemptions issued to this facility. List the number, date and what unit/process is covered by each permit. For a Modified Operating Permit, do not complete this item. 1 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division FACILITY PLOT PLAN FORM 2000-101 Rev 06-95 Facility Name: Marla Compressor Station Facility Identification Code: CO 123-0243 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. Please see the updated Facility Plot Plan, included as Attachment H to this application. 1. A plant layout (plan view) including all buildings occupied by or located on the site of the facility and any outdoor process layout. 2. The maximum height of each building (excluding stack height). 3. The location and coded designation of each stack. Please ensure these designations correspond to the appropriate stacks listed on the other permit forms in this application. The drawings need not be to scale if pertinent dimensions are annotated, including positional distances of structures, outdoor processes and free standing stacks to each other and the property boundaries. 4. The location of property boundary lines. 5. Identify direction "North" on all submittals. Are there any outdoor storage piles on the facility site with air pollution emissions that need to be reported? Yes x No If "Yes", what is the material in the storage pile(s)? Are there any unpaved roads or unpaved parking lots on the facility site? x Yes No List the name(s) of any neighboring state(s) within a 50 mile radius of your facility: Wyoming 2 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SOURCE AND SITE DESCRIPTIONS FORM 2000-102 Rev 06-95 Facility Name: Marla Compressor Station Facility Identification Code: CO 123-0243 The operating permit must be prepared and submitted on forms supplied by the Division. Use of this form is required for all operating permit applications. The Division will not consider or act upon your application unless each form used has been entirely completed. Completion of the information in the shaded area of this form is optional. Use "NA" where necessary to identify an information request that does not apply and is not in the optional shaded area. 1.Briefly describe the existing Unit(s) to be permitted. Attach copies of Form 2000-700 as needed to provide the information. Process flowsheets or line diagrams showing major features and locations of air pollution control equipment can be most effective in showing the location and relationships of the units. Providing mass flowrates/balances at critical points on the diagrams is very helpful when developing an understanding of the processes involved. The Marla Compressor Station uses six (6) gas -fired internal combustion engines to drive compressors to transmit natural gas gathered from field laterals to a primary pipeline. These engines are controlled through non -selective catalytic reduction (NSCR). The station also includes two (2) triethylene glycol dehydrator units that contact "dry" triethylene glycol with the natural gas stream to remove the moisture. The "wet" glycol mixture is regenerated in a still for reuse in the process. These units are equipped with individual condensers and a shared enclosed combustor device (ECD) for VOC control. Liquids from the dehydrators are routed to the pressurized slug catchers. Each dehydrator's flash tank vapors are captured by a vapor recovery unit and routed back into the inlet stream. Regenerator still vent vapors are routed to the condensers before being sent to the combustor device. No emission control from the condensers is claimed for either dehydration unit. Other equipment on site includes two pressurized bullet condensate storage tanks, pressurized liquid loadout to tank trucks, produced water storage, engine blowdown emissions, PIGGING activities, facility fugitive emissions, reboilers for the two dehydrators, and various other small storage tanks. All of these sources are considered insignificant activities. Please see the supplemental Form -700 attached to Form 2000-102b, as well as the attached list in Attachment D for details on these activities, and the applicable insignificant activity citations. Emissions for these sources have been estimated, where applicable. 2.Site Location and Description (Include instructions needed to drive to remote sites not identified by street addresses) Site location: SESE Section 28, T4N, R64W Directions from Denver, CO: Take 1-76 North out of the Denver Metro area, go approximately 3 miles past the town of Hudson and exit 1-76 at CO Road 49 and proceed north. Travel north on CO Road 49 for approximately 10 miles and turn east on CO Road 34. Proceed east bound on CO road 34 for 2 miles, turn north on CO Road 53. Proceed north on CO Road 53 for 3 miles and turn east on CO Road 40, proceed for one mile, Marla Compressor Station is at the NW corner of CO Road 40 & CO Road 55. 3. Safety Equipment Identify safety equipment required for performing an inspection of the facility: Protection x Hard Hat x Safety shoes x Hearing Protection Gloves x Other, specify Fire retardant clothing 3 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SOURCE DESCRIPTION - APENS FORM 2000-102A Rev 06-95 Facility Name: Marla Compressor Station Facility Identification Code: CO 123-0243 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) Attachment C contains copies of the following APENs- Source ID AIRS ID Description APEN Date C-148 / P-102 052 Waukesha Model L-7042 GSI Natural Gas Fired Internal Combustion Reciprocating Engine, 4 -cycle, Standard Rich Burn, Serial No. 232481, 1,478 HP, powering a natural gas compressor 6/26/2018 C-135 / P-103 053 Waukesha Model L-7042 GSI Natural Gas Fired Internal Combustion Reciprocating Engine, 4 -cycle, Standard Rich Burn, Serial No. C-10605/1, 1,478 HP, powering a natural gas compressor 6/26/2018 C-151 / P-004 054 Waukesha Model L-7042 GSI Natural Gas Fired Internal Combustion Reciprocating Engine, 4 -cycle, Standard Rich Burn, Serial No. 230355, 1,478 HP, powering a natural gas compressor 6/26/2018 C-166 / P-109 059 Waukesha Model L-7044 GSI Natural Gas Fired Internal Combustion Reciprocating Engine, 4 -cycle, Standard Rich Burn, Serial No. C-13852/1, 1,680 HP, powering a natural gas compressor 6/26/2018 C-174 / P-110 060 Waukesha Model L-7044 GSI Natural Gas Fired Internal Combustion Reciprocating Engine, 4 -cycle, Standard Rich Bum, Serial No. 5283700815, 1,680 HP, powering a natural gas compressor 6/26/2018 C-176 / P-111 061 Waukesha Model L-7044 GSI Natural Gas Fired Internal Combustion Reciprocating Engine, 4 -cycle, Standard Rich Burn, Serial No. C-17976/1, 1,680 HP, powering a natural gas compressor 6/26/2018 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 ❑ Yes x No ❑ Filing Fee Enclosed 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: x Yes ❑ No x Filing Fee Enclosed New permit application enclosed: ❑ Yes x No Permit modification application enclosed: x Yes ❑ No Attachment B contains copies of the following APENs• P-112 062 45.0 MMscfd Natural Gas Dehydration System using triethylene glycol, maximum glycol recirculation rate of 6.25 gallons/minute Submitted with this application P-113 063 55.0 MMscfd Natural Gas Dehydration System using triethylene glycol, maximum glycol recirculation rate of 8.20 gallons/minute 4 Operating Permit Application SOURCE DESCRIPTION - INSIGNIFICANT ACTIVITIES Colorado Department ofPublic Health and Environment Air Pollution Control Division FORM 2000-102B Rev 06-95 Facility Name: Marla Compressor Station Facility Identification Code: CO 123-0243 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 form used has been entirely completed. Please see included Supplemental Form 700 for complete list of Insignificant Activities 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 I.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). Petroleum industry flares, not associated with refineries, combusting natural gas containing no H2S except in trace (less than 500 ppmw) amounts, approved by the Colorado Oil and Gas Conservation Commission and having uncontrolled emissions of any pollutant of less than five tons per year. Chemical storage tanks or containers that hold less than 500 gallons, and which have a daily throughput less than 25 gallons. Landscaping and site housekeeping devices equal to or 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. x 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. 5 x Crude oil or condensate storage tanks with a capacity of 40,000 gallons or less. ❑ 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 PS IA). 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 6 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTR SUPPLEMENTAL INFORMATION FORM 2000-700 09-94 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. This form supplements Form 2000 — 102B for Emission Unit Insignificant Sources Source Description Insignificant Per 1,000 gal methanol tank Regulation No. 3, Part C, Section II.E.3.a 100 bbl methanol tank Regulation No. 3, Part C, Section II.E.3.a TK-8 —1,000 gal lube oil tank Regulation No. 3, Part C, Section II.E.3.aaa TK-8A— 210 bbl lube oil tank Regulation No. 3, Part C, Section II.E.3.aaa 1,000 gal TEG glycol tank Regulation No. 3, Part C, Section II.E.3.a 1,000 gal Norkool glycol tank Regulation No. 3, Part C, Section II.E.3.a 20 bbl slop oil tank Regulation No. 3, Part C, Section II.E.3.aaa 30,000 gal Pressurized Condensate Storage Tank Regulation No. 3, Part C, Section II.E.3.a 30,000 gal Pressurized Condensate Storage Tank Regulation No. 3, Part C, Section II.E.3.a Pressurized Condensate Truck Loadout Regulation No. 3, Part C, Section II.E.3.a 0.85 MMBtu/hr Dehy Reboiler H-112 Regulation No. 3, Part C, Section II.E.3.k 0.75 MMBtu/hr Dehy Reboiler H-113 Regulation No. 3, Part C, Section II.E.3.k 20 bbl Stormwater tank Regulation No. 3, Part C, Section II.E.3.a 80 bbl Stormwater tank Regulation No. 3, Part C, Section II.E.3.a 80 bbl Stormwater tank Regulation No. 3, Part C, Section II.E.3.a 80 bbl Stormwater tank Regulation No. 3, Part C, Section II.E.3.a 80 bbl Stormwater tank Regulation No. 3, Part C, Section II.E.3.a TK-0515 - 80 bbl produced water tank Regulation No. 3, Part C, Section II.E.3.uu TK-0516 - 80 bbl produced water tank Regulation No. 3, Part C, Section H.E.3.uu TK-0175 - 80 bbl produced water tank Regulation No. 3, Part C, Section II.E.3.uu TK-1080 - 80 bbl produced water tank Regulation No. 3, Part C, Section II.E.3.uu 110 bbl produced water tank Regulation No. 3, Part C, Section II.E.3.uu C-148 vent blowdown Regulation No. 3, Part C, Section II.E.3.a C-135 vent blowdown Regulation No. 3, Part C, Section II.E.3.a C-151 vent blowdown Regulation No. 3, Part C, Section II.E.3.a C-166 vent blowdown Regulation No. 3, Part C, Section II.E.3.a C-174 vent blowdown _ Regulation No. 3, Part C, Section II.E.3.a C-176 vent blowdown Regulation No. 3, Part C, Section II.E.3.a Pigging Activities (< 1 tpy VOC emissions per PIG) Regulation No. 3, Part C, Section II.E.3.a Facility Fugitive Emissions Regulation No. 3, Part C, Section II.E.3.a 1 P-112: 45.0 MMscfd TEG Natural Gas Dehydrator AIRS: 123 / 0243 / 062 Operating Permit Application STACK IDENTIFICATION Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-200 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-112 3a. Construction Permit Number: 01WE0506 4. Exhausting Unit(s), use Unit identification code from appropriate Form(s) 2000-300, 301, 302, 303, 304, 305, 306, 307 2000-300 2000-301 2000-304 2000-305 2000-302 2000-303 2000-306 2000-307 P-112 5. Stack identified on the plot plan required on Form 2000-101 X No Change in Equipment Location 6. Indicate by checking: X This stack has an actual exhaust point. The parameters are entered in Items 7-13. This stack serves to identify fugitive emissions. Skip items 7-13. Go to next form. When stack height Good Engineering Practice (GEP) exceeds 65 meters (Colorado Air Quality Reg 3.A.VIII.D) data entry is required for Item 7. 7Discharge height aboveground. level_ (feet; *****Complete the appropriate Air Permit Application Forms(s) 2000-300, 301, 302, 303, 304,***** 305, 306, or 307 for each Unit exhausting through this stack. Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE GLYCOL DEHYDRATION UNIT FORM 2000-307 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-112 4. Dehydrator (Unit) code: P-112 5. Unit description: Triethylene glycol dehydrator for dehydration of inlet wet gas stream 6. Indicate the dehydrator control technology status. ❑ Uncontrolled X Controlled If the dehydrator is controlled, enter the control device number(s) from the appropriate forms: 2000-400 ECD 2000-403 7. Manufacturer: Custom 8. Model & serial number: TEG Dehydration Unit Serial Number: Custom 9. Regenerator heater design rate or maximum continuous rating (mmB TU/hr): 0.85 10. Date first placed in service: November 2005 Date of last modification: October 2017 11. Flash Tank: X Yes ❑ No Flash tank vented to: ❑ atmosphere X recycled 12. Glycol Circulation rate: 6.25 gallons per minute (maximum) gallon per pound of H2O OR 13. Pipeline Capacity: (mmscf/day): 45.0 14. Glycol Type: X Triethylene Glycol ❑ Ethylene Glycol ❑ Other (specify) 15. Glycol Make-up Rate (gallons/year): 16. Computer model input & output printout attached X Glycalc 4.0 results 17. Gas Pressure (psi): 1,000 18. Gas Temperature (°F): 106 19. Gas composition test results Test date: 06/28/2017 VOC BTEX HEXANE value units value units value units 12.097 mol% 0.047 mol% 0.124 mol% *****For this emissions unit, identify the method of compliance demonstration by completing Form 2000-500, ***** DESCRIPTION OF METHODS USED FOR DETERMINING COMPLIANCE. Attach Form 2000-500 and its attachment(s) to this form. ***** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** NOTE: THE SPECIALIZED APEN FOR A GLYCOL DEHYDRATION UNIT MUST BE COMPLETED AND SUBMITTED IF THE STILL VENT EMISSIONS HAVE NOT BEEN REPORTED BEFORE NOTE: COMPLETION OF INFORMATION IN SHADED AREA OF THIS FORM IS OPTIONAL Operating Penn it Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station CONTROL EQUIPMENT - MISCELLANEOUS 2. Facility identification code: CO 123-0243 FORM 2000-400 Rev 06-95 3. Stack identification code: P-112 4. Unit identification code: P-112 5. Control device code: Enclosed Combustor (ECD) 6. Manufacturer and model number: Cimarron 7. Date placed in service: November 2005 Date of last modification: October 2017 8. Describe the device being used. Attach a diagram of the system. The emissions from the P-112 still vent are routed to an enclosed combustor (ECD). Emissions from the flash tank are routed back to the inlet stream. Enclosed combustor shared by units P-112 and P-113 9. List the pollutants to be controlled by this equipment and the expected control efficiency for EITHER the outlet pollutant each pollutant on the table below. 0 Documentation attached concentration OR the control efficiency must be provided. Pollutant VOC HAPs Outlet pollutant concentration gr/acf ppmv Control Efficiency (%) 95% 95% iscuss how the collected material wall be handledfor reuse or disposal are a ma revention and abatemen with the application." _T cation control systeem plan include, but`no Operating Permit Application COMPLIANCE CERTIFICATION - MONITORING AND REPORTING FORM 2000-500 Colorado Department of DESCRIPTION OF METHODS USED Rev 06-95 Public Health and Environment FOR DETERMINING COMPLIANCE Air Pollution Control Division All applicants are required to certify compliance with all applicable air pollution permit requirements by including a statement within the permit application of the methods used for determining compliance. This statement must include a description of the monitoring, recordkeeping, and reporting requirements and test methods. In addition, the application must include a schedule for compliance certification submittals during the permit term. These submittals must be no less frequent than annually, and may need to be more frequent if specified by the underlying applicable requirement or by the Division. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-112 4. Unit identification code: TEG Dehydrator 5. For this Unit the following method(s) for determining compliance with the requirements of the permit will be used (check all that apply and attach the appropriate form(s) to this form). Continuous Emission Monitoring (CEM) - Form 2000-501 Pollutant(s): Periodic Emission Monitoring Using Portable Monitors - Form 2000-502 Pollutant(s) X Monitoring Control System Parameters or Operating Parameters of a Process - Form 2000-503 Pollutant(s): VOCs, HAPs Monitoring Maintenance Procedures - Form 2000-504 Pollutant(s): Stack Testing - Form 2000-505 Pollutant(s): Fuel Sampling and Analysis (FSA) - Form 2000-506 Pollutant(s): X Recordlceeping - Form 2000-507 Pollutant(s): VOC, HAPs X Other (please describe) - Form 2000-508 Pollutant(s): VOC. HAPs 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February 1, of the year following the Operating Permit renewal. Compliance monitoring reports will be submitted to the Division according to the following schedule: Start date: February 1, of the year following the Operating Permit renewal. and every 6 months thereafter. (6 month maximum interval) NOTE: EACH APPLICABLE REQUIREMENT ON FORM 2000-604 NEEDS TO BE SPECIFICALLY ADDRESSED IN ITEM 5. Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-503 Colorado Department of MONITORING CONTROL SYSTEM PARAMETERS OR Rev 06-95 Public Health and Environment OPERATING PARAMETERS OF A PROCESS Air Pollution Control Division The monitoringof a control system parameter or a process may be acceptable as a compliance demonstration method provided that a correlation between the parameter value and the emission rate of a particular pollutant is established in the form of a curve of emission rate versus parameter values. Ideally stack test data that bracket the emission limit, if possible, could be used to define the emission curve. This correlation shall constitute the certification of the system. It should be attached for Division approval. If it is not attached, please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-112 4.Unit identification code: TEG Dehydrator, Enclosed Combustor 5. Pollutant(s) being monitored: VOC, HAPs 6. Name of manufacturer: 7. Model number: 8. Is this an existing system? X Yes No 9. Reserved for future use 10. Describe the method of monitoring: Presence of a flame in Enclosed Combustor: Presence of a flame is continuously monitored 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. The observation of the presence of a flame will indicate that the device is operational. 11. Backup system: Daily Visual Inspections 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 - X The presence of a pilot flame in the enclosed combustor is monitored continuously using a thermocouple, or equivalent device. Backup monitoring is provided by visual inspection if pilot light status cannot be verified. Daily logs of both continuous monitoring results, as well as any backup visual inspection results, are kept. QA/QC checked by periodic review of logs by Supervisory personnel. 13. The applicant shall propose an appropriate averaging period, (i.e., a particular number of continuous hours) for the purpose of defining excess emissions. The Division may approve the proposed averaging period, or other period which the Division determines to be appropriate. Provide the proposed averaging period(s) below. Parameter Averaging Period Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of BY RECORDKEEPING Rev 06-95 Public Health and Environment Air Pollution Control Division Recordkeeping may be acceptable as a compliance demonstration method provided that a correlation between the parameter value recorded and the emission rate of a particular pollutant is established in the form of a curve or chart of emission rate versus parameter values. This correlation may constitute the certification of the system. For an existing program, the correlation demonstration must be attached for Division consideration for approval. If the correlation information has not yet been developed, please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-112 4. Unit identification code: P-112 5. Pollutant(s) being monitored: VOC, HAPs 6. Material or parameter being monitored and recorded: Inlet wet gas temperature and pressure, Flash tank temperature and pressure, glycol recirculation rate, inlet wet gas throughput, hours of operation, enclosed combustor hours of operation and hours of downtime, actual emissions of VOCs and HAPs 7. Method of monitoring and recording (see information on back of this page): Inlet wet gas temperature and pressure — monitored weekly and averaged for month Flash tank temperature and pressure — monitored weekly and averaged for month Glycol recirculation rate — monitored weekly and averaged for month Inlet wet gas throughput — monitored monthly using existing flow meter, used with hours of operation to determine daily average throughput Hours of Operation — monitored monthly, used with monthly throughput to calculate average daily throughput Enclosed Combustor hours of operation and hours of downtime — Daily pilot light monitoring (via flame rod) to determined daily hours of operation and daily hours of downtime Actual Emissions of VOCs and HAPs — Calculated monthly using GLYCalc run based on above parameters 8. List any EPA methods used: None 9. Is this an existing method of demonstrating compliance? No X Yes 10. Start date: November 2005 11. Backup system: Assume maximum values for recordkeeping analysis in case of missing values 12 a. Data collection frequency: X Daily X Weekly X Monthly Batch (not to exceed monthly) Other - specify 12 b. Compliance shall be demonstrated: Daily 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. -A quality assurance/quality control plan for the recordkeeping system is attached for Division review. -The plan is not attached, but will be submitted to the Division by DCP will continue to conduct QC/QA as required by Operating Permit 95OPWE020. 14. A proposed format for the compliance certification report and excess emission report is attached. DCP is proposing no changes to the format of the compliance certification or excess emissions reports submitted for this facility. ***** ***** The compliance records shall be available for Division inspection. The source shall record any malfunction that causes or may cause an emission limit to be exceeded. ***** Malfunctions shall be reported to the Division the next business day. Hazardous air releases shall be reported to the Division immediately. Operating Permit Application COMPLIANCE DEMONSTRATION Colorado Department of Public Health and Environment BY OTHER METHODS Air Pollution Control Division FORM 2000-508 Rev 06-95 1. Facility Name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-112 4. Unit Identification code: TEG Dehydrator 5. Pollutant(s) or Parameter(s) being monitored: Inlet Wet Gas Sampling 6. Description of the method of monitoring: Samples of inlet gas shall be collected and analyzed to determine CI to C6, n -hexane, benzene, toluene, ethyl benzene and total xylene (BTEX) composition. The wet gas composition from the most recent extended analysis will be used with other recorded parameters to calculate VOC and HAP emissions on a monthly basis, using GLYCaIc. 7. Compliance shall be demonstrated: (Specify the frequency with which compliance will be demonstrated) Inlet wet gas will be collected and sampled annually. If any concentrations of BTEX on the analysis exceed specified values, inlet sampling frequency will increase to quarterly. Operating Permit Application EMISSION UNIT HAZARDOUS AIR POLLUTANTS Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-600 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-112 4. Unit identification code: P-112 5. Unit material description: Triethylene glycol (TEG) Dehydrator used for dehydration of inlet wet gas stream. 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor references. Attached X Actual Emissions Data is for calendar year Pollutant CAS Common or Generic Pollutant Name Allowable OR Potential to emit Quantity Measurement Units 71-43-2 Benzene 1.60 TPY 108-88-3 Toluene 2.52 TPY 100-41-4 Ethylbenzene 0.14 TPY 1330-20-7 Xylene 1.89 TPY 110-54-3 n -Hexane 0.16 TPY NOTE: If there is a permit for this unit, the permit limits are the same as the potential to emit. Operating Permit Application EMISSION UNIT CRITERIA AIR POLLUTANTS Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-601 09-94 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 ' 3: Stack identification code: P-112 4. Unit identification code: P-112 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached X Air pollutant Actual'' Potential to emit Maximum allowable Quantity U = TPY U TPY Particulates (TSP) TPY PM -10 TPY Nitrogen oxides 0.13 TPY 0.068 2 0.13 Volatile organic compounds 10.62 TPY 1.29 7 10.62 Carbon monoxide 0.61 TPY 0.31 2 0.61 Lead TPY Sulfur dioxide TPY Total reduced sulfur TPY Reduced sulfur compounds TPY Hydrogen sulfide TPY Sulfuric Acid Mist TPY Fluorides TPY TPY TPY TPY TPY Units (U) should be entered as follows: 1 = lb/hr 2 = lb/mmBTU 3 = grains/dscf 4 = lb/ gallon 5 = ppmdv 6 = gram/HP-hour 7 = lb/mmscf 8 = other (specify) 9 = other (specify) 10 = other (specify) I; Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE APPLICABLE REQUIREMENTS AND STATUS OF EMISSION UNIT FORM 2000-604 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-112 4. Unit identification code: P-112 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT VOC 01WE0506 10.62 tpy X HAPs 01WE0506 < 8 tpy individual < 20 tpy facilitywide x 10. Other requirements (e.g., malfunction existing permit such as material reporting, special operating conditions from an usage, hours of operation, etc.) State Only Compliance IN Status OUT Extended Gas Analysis: Annually, or quarterly if results exceed specified values X Gas Throughput Limit: 16,425 Gas Throughput Limit during MMscf/yr, monthly recordkeeping ECD Downtime: 492.75 MMscf/yr, monthly recordkeeping x Hours of Operation: monthly recordkeeping X Enclosed Combustor Downtime: daily recordkeeping X Enclosed Combustor Requirements: pilot light monitoring, recordkeeping X Compliance Assurance Monitoring: this TEG natural gas dehydrator the permitee shall follow the CAM plan for control of X Colorado Regulation 7 Section dehydrator of at least 90%. Follow requirements. XII: maintain overall control of emission from natural gas all applicable monitoring, recordkeeping, and reporting X Colorado Regulation 7 Section dehydrator of at least 95%. Follow requirements. XVII: maintain overall control of emissions from natural gas all applicable monitoring, recordkeeping, and reporting X X Lean Glycol Recirculation Rate: 6.25 gallons/minute, weekly recordkeeping X NESHAP Subpart HH Area Source requirements X NESHAP Subpart A General Provisions X *The only proposed change in applicable requirements for this equipment is removal of the condenser outlet temperature monitoring and recordkeeping requirements, and the resulting update to potential VOC emissions from this source. There will be no change in the methods of determining compliance for the above requirements, except for calculations of VOC emissions from this source. Monthly emission estimates of VOCs made using GLYCalc will no longer incorporate control from the installed condenser. Since DCP is proposing no other updates to the methods of compliance determination for the above requirements, a Form 2000-700 has not been included in this application. **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1.Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-112 4.Unit identification code: P-112 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. X We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. 2. 3. Progress reports will be submitted: Start date: and every six (6) months thereafter P-113: 55.0 Mtvlscfd TEG Natural Gas Dehydrator AIRS: 123 / 0243 / 063 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE STACK IDENTIFICATION FORM 2000-200 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-113 3a. Construction Permit Number: 05WE0579 4. Exhausting Unit(s), use Unit identification code from appropriate Form(s) 2000-300, 301, 302, 303, 304, 305, 306, 307 2000-300 2000-304 2000-301 2000-305 2000-302 2000-306 2000-303 2000-307 P-113 5. Stack identified on the plot plan required on Form 2000-101 X No Change in Equipment Location 6. Indicate by checking: X This stack has an actual exhaust point. The parameters are entered in Items 7-13. This stack serves to identify fugitive emissions. Skip items 7-13. Go to next form. When stack height Good Engineering Practice (GEP) exceeds 65 meters (Colorado Air Quality Reg 3.A.VIII.D) data entry is required for Item 7. 7. Discharge height above round level (feet) *****Complete the appropriate Air Permit Application Forms(s) 2000-300, 301, 302, 303, 304,***** 305, 306, or 307 for each Unit exhausting through this stack. Operating Permit Application TABULATION OF PERMIT APPLICATION FORMS FORM 2000-800 Colorado Department of Health Air Pollution Control Division Facility Name: Marla Compressor Station I. ADMINISTRATION 09-94 Facility Identification Code: CO 123-0243 This 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 II. EMISSIONS SOURCE DESCRIPTION Total Number of This Form This application contains the following forms (one form for each facility boiler, printing x Form 2000-200, Stack Identification 3 ❑ Form 2000-300, Boiler or Furnace Operation ❑ Form 2000-301, Storage Tanks x Form 2000-302, Internal Combustion Engine 1 ❑ Form 2000-303, Incineration ❑ Form 2000-304, Printing Operations ❑ Form 2000-305, Painting and Coating Operations ❑ Form 2000-306, Miscellaneous Processes x Form 2000-307, Glycol Dehydration Unit 2 III. AIR POLLUTION CONTROL SYSTEM Total Number of This Form This application contains, the following forms: X Form 2000400, Miscellaneous 2 o Form 2000-401, Condensers ❑ Form 2000-402, Adscrbers ❑ Form 2000-403, Catalytic or Thermal Oxidation ❑ Form 2000-404, Cyclones/Settling Chambers ❑ Form 2000-405, Electrostatic Precipitators ❑ Form 2000406, Wet Collection Systems ❑ Form 2000407, Baghouses/Fabric Filters IV. COMPLIANCE DEMONSTRATION Total Number of This Form This application contains the following forms (one for each facility boiler, printing operation, X Form 2000-500, Compliance Certification - Monitoring and Reporting 2 ❑ Form 2000-501, Continuous Emission Monitoring ❑ Form 2000-502, Periodic Emission Monitoring Using Portable Monitors x Form 2000-503, Control System Parameters or Operation ' Parameters of a Process 2 ❑ Form 2000-504, Monitoring Maintenance Procedures ❑ Form 2000-505, Stack Testing ❑ Form 2000-506, Fuel Sampling and Analysis x Form 2000-507, Recardkeeping 2 x Form 2000-508, Other Methods 2 1 V. EMISSION SUMMARY AND COMPLIANCE CERTIFICATION Total Number of This Form This application contains the following forms quantifying emissions, certifying compliance with applicable requirements, and developing a compliance plan x Form 2000-600, Emission Unit Hazardous Air Pollutants 2 x Form 2000-601, Emission Unit Criteria Air Pollutants 2 x Form 2000-602, Facility Hazardous Air Pollutants 1 x Form 2000-603, Facility Criteria Air Pollutants 1 x Form 2000-604, Applicable Requirements and Status of Emission Unit 2 ❑ Form 2000-605, Permit Shield Protection Identification x Form 2000-606, Emission Unit Compliance Plan - Commitments and Schedule 3 ❑ Form 2000-607, Plant -Wide Applicable Requirements ❑ Form 2000-608, Plant -Wide Compliance Plan - Commitments and Schedule VI. SIGNATURE OF RESPONSIBLE OFFICIAL - FEDERAL/STATE CONDITIONS A. STATEMENT OF COMPLETENESS I have reviewed this application in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this application are true, accurate and complete. B. CERTIFICATION OF FACILITY COMPLIANCE STATUS - FEDERAL/STATE CONDITIONS (check one box only) ❑ I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. x 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): C-176 (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 David M. Jost Title Vice President of Northern Operations Signature R,.,, -Y A hp- Date Sign ‘Als/0,10A7 Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE PLANT -WIDE CRITERIA MR POLLUTANTS FORM 2000-603 09-94 1.Facility name: Marla Compressor Station 2.Facility identification code: CO 123-0243 3. Complete the following emissions summary for the listed emissions at this facility. Air pollutant Actual Potential to emit Maximum allowable TPY;; TPY TPY Particulates (TSP) 6.3 6.3 PM -10 6.3 6.3 Nitrogen oxides 167.8 167.8 Volatile organic compounds 119.2 119.2 Carbon monoxide 213.6 213.6 Lead Sulfur dioxide 0.2 0.2 Total reduced sulfur Reduced sulfur compounds Hydrogen sulfide Sulfuric acid mist Fluorides Operating Permit Application PLANT -WIDE HAZARDOUS AIR POLLUTANTS Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-602 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Complete the following emissions summary for all hazardous air emissions at this facility. Calculations attached. Attach a copy of all calculations to this form. Attached X Pollutant CAS Common or Generic Pollutant Name anti Allowable OR Potential to emit Quantity Highest Individual HAP < 8.0 Units TPY Total Facilitywide HAPs < 20.0 TPY NOTE: If there is a permit for this unit, the permit limits are the same as the potential to emit. Marla Booster Unit C-176 (AIRS ID 061) NSPS JJJJ Compliance Plan In accordance with Regulation 3, Part C, Section III.C.8, the source is in compliance with the applicable state and federal requirements with the exception of the the 40 CFR 60 NSPS JJJJ Requirements for engine C-176. In accordance with Regulation 3, Part C Section III.C.8, the source will achieve compliance with the NSPS JJJJ requirements for Unit C-176 as described in the compliance schedule below. A narrative description is provided for each corrective action to be taken to achieve compliance. Regulation 3, Part C, Section III.C.9 Compliance Schedule: General Provisions and Specific NSPS JJJJ Requirement 60.4233(e), Table 1 60.7(a)(1) and 60.4245(c) 60.7(a)(3) 60.8(d) 60.8(a) 60.8(a) and 60.4245(d) 0.4243(b)(2)(ii) 60.4245(a) Corrective Actions NOx Emission Standard = 2.0 g/hp-hr (controlled), 150 ppmvd @ 15% O2 CO Emission Limit = 4.0 g/hp-hr (controlled), 540 ppmvd @ 15% O2 VOC Emission Limit = 1.0 g/hp-hr (controlled), 86 ppmvd @ 15% O2 Submit notice of construction of the affected facility Submit a notification of the actual date of initial startup of an affected facility. Submit notice of performance test 30 days in advance to the Administrator Conduct performance test Submit perfomance test results to the Administrator Keep a maintenance plan and records of maintenance Keep records of all notifications and supporting documentation Deadline In Compliance In Compliance In Compliance August 31, 2018 August 31, 2018 September 30, 2018 October 30, 2018 December 31, 2018 Completed December 31, 2018 As required by Regulation 3, Part C, Section III.C.10, DCP will submit a progress report every six months until all corrective actions have been completed. Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 3. Stack identification code: S-176 2. Facility identification code: CO 123-0243 4. Unit identification code: C-176 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. ❑ We will continue to operate and maintain this Unit in compliance with all applicable requirements. ❑ Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. ® This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. New Source Performance Standard (NSPS) Subpart JJJJ performance testing and notification requirements DCP will submit all required notifications, and perform all required performance testing for this engine, to comply with applicable Subpart JJJJ requirements. Please see the attached compliance plan on the following page for details. December 31St, 2018 2. 3. Progress reports will be submitted: Start date: December 31, 2018 and every six (6) months thereafter INTERNAL COMBUSTION ENGINE OPERATION Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-302 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-111 4. Engine (Unit) code: C-176 4a. Date first placed in service: 02/2003 Date last modified: 5. Engine use: natural gas compression 6. Engine Features: 2 -Cycle ❑ 4 -Cycle Standard rich burn Air/fuel ratio controller Low-NOx design Spark -ignition Diesel ❑ Standard lean burn Turbocharger Other(Describe): 7. Emission controls: ❑ No Non -Selective catalytic reduction Selective catalytic reduction Oxidation catalyst Z Yes - Attach control device form (no change in emission controls) Three-way catalyst Ammonia injected Other: El El 8. Manufacturer: Waukesha 9. Model No: L7044 GSI S/N: C-17976/1 10. Max Fuel Design Rate: 13.2 mmBTU/hr 11. Horsepower Max Design: 1,680 Site: 1,680 12. Heat Rate: 7,860 BTU/HP-hr 13. Operating Temp: Min. Max. EF 14. Fuels: Primary Fuel Backup Fuel #1 Fuel Type: Natural Gas Heating Value BTU/SCF 1,020 Sulfur Content (Wt.%) Neg. Ash Content, (Wt.%) Neg. Moisture Content (%) Maximum Hourly Consumption (Ft3,gal) Maximum Yearly Consumption (Ft3,gal) 12,947 scf/hr 113.4 MMscf/yr NOTE: Data entry below is NOT OPTIONAL if parametric monitoring is used for comp iance demonstration ararrie 'ers Low high RENIARI .�r ***** Identify, the method of compliance demonstration by completing Form 2000-500, ***** DESCRIPTION OF METHODS USED FOR DETERMINING COMPLIANCE. Attach Form 2000-500 to this form. ***** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE STACK IDENTIFICATION FORM 2000-200 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-111 3a. Construction Permit Number: 01WE0505 4. Exhausting Unit(s), use Unit identification code from appropriate Form(s) 2000-300, 301, 302, 303, 304, 305, 306, 307 2000-300 2000-304 2000-301 2000-305 2000-302 C-176 2000-306 2000-303 2000-307 5. Stack identified on the plot plan required on Form 2000-101 ® Engine Location Identified 6. Indicate by checking: ® This stack has an actual exhaust point. The parameters are entered in Items 7-13. ❑ This stack serves to identify fugitive emissions. Skip items 7-13. Go to next form. ❑ When stack height Good Engineering Practice (GEP) exceeds 65 meters (Colorado Air Quality Reg 3.A.VIII.D) data entry is required for Item 7. 7 Discharge,height above 8'. *****Complete the appropriate Air Permit Application Forms(s) 2000-300, 301, 302, 303, 304, ***** 305, 306, or 307 for each Unit exhausting through this stack. qund level . 40.0; (fi side dimensions at outlet(check one and complete �s stack. equipped with a rainftat or any obstruction to the free:] ases from the stack's ❑Yes�No C-176 Waukesha L-7044 Natural Gas Compressor Engine AIRS: 123 / 0243 / 061 Corrective Actions Deadline Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1.Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-113 4.Unit identification code: P-113 5. For Units that are presently in compliance with all applicable requirements, including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3, Part C that apply, complete the following. These commitments are part of the application for operating permits. X We will continue to operate and maintain this Unit in compliance with all applicable requirements. Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance, complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule (If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Progress reports will be submitted: Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division APPLICABLE REQUIREMENTS AND STATUS OF EMISSION UNIT FORM 2000-604 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-113 4. Unit identification code: P-113 5. Pollutant 6. Colorado Air Quality Regulations or Construction Permit Number 7. State Only 8. Limitation 9. Compliance Status IN OUT VOC 01WE0506 14.26 tpy X HAPs 01WE0506 < 8 tpy individual < 20 tpy facilitywide X 10. Other requirements (e.g., malfunction reporting, special operating conditions from an existing permit such as material usage, hours of operation, etc.) State Only Compliance Status IN OUT Extended Gas Analysis: Annually, or quarterly if results exceed specified values X Gas Throughput Limit: 20,075 MMscf/yr, monthly recordkeeping Gas Throughput Limit during ECD Downtime: 602.25 MMscf/yr, monthly recordkeeping X Hours of Operation: monthly recordkeeping X Enclosed Combustor Downtime: daily recordkeeping X Enclosed Combustor Requirements: pilot light monitoring, recordkeeping X Compliance Assurance Monitoring: the permitee shall follow the CAM plan for control of this TEG natural gas dehydrator x Colorado Regulation 7 Section XII: maintain overall control of emission from natural gas dehydrator of at least 90%. Follow all applicable monitoring, recordkeeping, and reporting requirements. x Colorado Regulation 7 Section XVII: maintain overall control of emissions from natural gas dehydrator of at least 95%. Follow all applicable monitoring, recordkeeping, and reporting requirements. X X Lean Glycol Recirculation Rate: 8.20 gallons/minute, weekly recordkeeping X NESHAP Subpart HH Area Source requirements X NESHAP Subpart A General Provisions X *The only proposed change in applicable requirements for this equipment is removal of the condenser outlet temperature monitoring and recordkeeping requirements, and the resulting update to potential VOC emissions from this source. There will be no change in the methods of determining compliance for the above requirements, except for calculations of VOC emissions from this source. Monthly emission estimates of VOCs made using GLYCaic will no longer incorporate control from the installed condenser. Since DCP is proposing no other updates to the methods of compliance determination for the above requirements, a Form 2000-700 has not been included in this application. **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT f; I Operating Permit Application EMISSION UNIT CRITERIA AIR POLLUTANTS Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE FORM 2000-601 09-94 1. Facility name: Marla Compressor Station Facility identification code: CO 123-0243 3. Stack identification code: P-113 4. Unit identification code: P-113 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached X Air pollutant is Potential to emit Maximum allowable U TPY Particulates (TSP) TPY PM -10 TPY Nitrogen oxides 0.19 TPY 0.068 2 0.19 Volatile organic compounds 14.26 TPY 1.42 7 14.26 Carbon monoxide 0.87 TPY 0.31 2 0.87 Lead TPY Sulfur dioxide TPY Total reduced sulfur TPY Reduced sulfur compounds TPY Hydrogen sulfide TPY Sulfuric Acid Mist TPY Fluorides TPY TPY TPY TPY TPY Units (U) should be entered as follows: = lb/hr 2 = lb/mmBTU 3 = grains/dscf 4 = lb/ gallon 5 = ppmdv 6 = gram/HP-hour 7 = lb/mmscf 8 = other (specify) 9 = other (specify) 10 = other (specify) Operating Permit Application EMISSION UNIT HAZARDOUS AIR POLLUTANTS FORM 2000-600 Colorado Department of Public Health and,Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-113 4. Unit identification code: P-113 5. Unit material description: Triethylene glycol (TEG) Dehydrator used for dehydration of inlet wet gas stream. 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor references. Attached X Actual Emissions Data is for calendar year Pollutant CAS Common or Generic Pollutant Name Allowable OR Potential to emit Quantity Measurement Units 71-43-2 Benzene 2.13 108-88-3 Toluene 3.32 TPY TPY 100-41-4 Ethylbenzene 0.18 TPY 1330-20-7 Xylene 2.45 TPY 110-54-3 n -Hexane 0.21 TPY 47 ,44 4,41 NOTE: If there is a permit for this unit, the permit limits are the same as the potential to emit. Operating Permit Application COMPLIANCE DEMONSTRATION Colorado Department of Public Health and Environn ent BY OTHER METHODS Air Pollution Control Division FORM 2000-508 Rev 06-95 1. Facility Name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-113 4. Unit Identification code: TEG Dehydrator 5. Pollutant(s) or Parameter(s) being monitored: Inlet Wet Gas Sampling 6. Description of the method of monitoring: Samples of inlet gas shall be collected and analyzed to determine CI to C6, n -hexane, benzene, toluene, ethyl benzene and total xylene (BTEX) composition. The wet gas composition from the most recent extended analysis will be used with other recorded parameters to calculate VOC and HAP emissions on a monthly basis, using GLYCalc. 7. Compliance shall be demonstrated: (Specify the frequency with which compliance will be demonstrated) Inlet wet gas will be collected and sampled annually. If any concentrations of BTEX on the analysis exceed specified values, inlet sampling frequency will increase to quarterly. Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division COMPLIANCE DEMONSTRATION BY RECORDKEEPING FORM 2000-507 Rev 06-95 Recordkeeping may be acceptable as a compliance demonstration method provided that a correlation between the parameter value recorded and the emission rate of a particular pollutant is established in the form of a curve or chart of emission rate versus parameter values. This correlation may constitute the certification of the system. For an existing program, the correlation demonstration must be attached for Division consideration for approval. If the correlation information has not yet been developed, please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-113 4. Unit identification code: P-113 5. Pollutant(s) being monitored: VOC, HAPs 6. Material or parameter being monitored and recorded: Inlet wet gas temperature and pressure, Flash tank temperature and pressure, glycol recirculation rate, inlet wet gas throughput, hours of operation, enclosed combustor hours of operation and hours of downtime, actual emissions of VOCs and HAPs 7. Method of monitoring and recording (see information on back of this page): Inlet wet gas temperature and pressure — monitored weekly and averaged for month Flash tank temperature and pressure — monitored weekly and averaged for month Glycol recirculation rate — monitored weekly and averaged for month Inlet wet gas throughput — monitored monthly using existing flow meter, used with hours of operation to determine daily average throughput Hours of Operation — monitored monthly, used with monthly throughput to calculate average daily throughput Enclosed Combustor hours of operation and hours of downtime — Daily pilot light monitoring (via flame rod) to determined daily hours of operation and daily hours of downtime Actual Emissions of VOCs and HAPs — Calculated monthly using GLYCalc run based on above parameters 8. List any EPA methods used: None 9. Is this an existing method of demonstrating compliance? No X Yes 11. Backup system: Assume maximum values for recordkeeping analysis in case of missing values 10. Start date: November 2005 12 a. Data collection frequency: X Daily X Weekly X Monthly Batch (not to exceed monthly) Other - specify 12 b. Compliance shall be demonstrated: Daily 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. -A quality assurance/quality control plan for the recordkeeping system is attached for Division review. -The plan is not attached, but will be submitted to the Division by DCP will continue to conduct QC/QA as required by Operating Permit 95OPWE020. 14. A proposed format for the compliance certification report and excess emission report is attached. DCP is proposing no changes to the format of the compliance certification or excess emissions reports submitted for this facility. ***** The compliance records shall be available for Division inspection. The source shall record any malfunction that causes or may cause an emission limit to be exceeded. ***** Malfunctions shall be reported to the Division the next business day. Hazardous air releases shall be reported to the Division immediately. Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-503 Colorado Department of MONITORING CONTROL SYSTEM PARAMETERS OR Rev 06-95 Public Health and Environment OPERATING PARAMETERS OF A PROCESS Air Pollution Control Division The monitoring of a control system parameter or a process may be acceptable as a compliance demonstration method provided that a correlation between the parameter value and the emission rate of a particular pollutant is established in the form of a curve of emission rate versus parameter values. Ideally stack test data that bracket the emission limit, if possible, could be used to define the emission curve. This correlation shall constitute the certification of the system. It should be attached for Division approval. If it is not attached, please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-113 4.Unit identification code: TEG Dehydrator, Enclosed Combustor 5. Pollutant(s) being monitored: VOC, HAPs 6. Name of manufacturer: 7. Model number: 8. Is this an existing system? X Yes No 9. Reserved for future use 10. Describe the method of monitoring: Presence of a flame in Enclosed Combustor: Presence of a flame is continuously monitored 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. The observation of the presence of a flame will indicate that the device is operational. 11. Backup system: Daily Visual Inspections 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 - X The presence of a pilot flame in the enclosed combustor is monitored continuously using a thermocouple, or equivalent device. Backup monitoring is provided by visual inspection if pilot light status cannot be verified. Daily logs of both continuous monitoring results, as well as any backup visual inspection results, are kept. QA/QC checked by periodic review of logs by Supervisory personnel. 13. The applicant shall propose an appropriate averaging period, (i.e., a particular number of continuous hours) for the purpose of defining excess emissions. The Division may approve the proposed averaging period, or other period which the Division determines to be appropriate. Provide the proposed averaging period(s) below. Parameter Averaging Period Operating Permit Application COMPLIANCE CERTIFICATION - MONITORING AND REPORTING FORM 2000-500 Colorado Department of DESCRIPTION OF METHODS USED Rev 06-95 Public Health and Environment FOR DETERMINING COMPLIANCE Air Pollution Control Division All applicants are required to certify compliance with all applicable air pollution permit requirements by including a statement within the permit application of the methods used for determining compliance. This statement must include a description of the monitoring, recordkeeping, and reporting requirements and test methods. In addition, the application must include a schedule for compliance certification submittals during the permit term. These submittals must be no less frequent than annually, and may need to be more frequent if specified by the underlying applicable requirement or by the Division. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-113 4. Unit identification code: TEG Dehydrator 5. For this Unit the following method(s) for determining compliance with the requirements of the permit will be used (check all that apply and attach the appropriate form(s) to this form). Continuous Emission Monitoring (CEM) - Form 2000-501 Pollutant(s): Periodic Emission Monitoring Using Portable Monitors - Form 2000-502 Pollutant(s) X Monitoring Control System Parameters or Operating Parameters of a Process - Form 2000-503 Pollutant(s): VOCs, HAPs Monitoring Maintenance Procedures - Form 2000-504 Pollutant(s): Stack Testing - Form 2000-505 Pollutant(s): Fuel Sampling and Analysis (FSA) - Form 2000-506 Pollutant(s):. X Recordkeeping - Form 2000-507 Pollutant(s): VOC, HAPs x Other (please describe) - Form 2000-508 Pollutant(s): VOC, HAPs 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February 1, of the year following the Operating Permit renewal. Compliance monitoring reports will be submitted to the Division according to the following schedule: Start date: February 1, of the year following the Operating Permit renewal. and every 6 months thereafter. (6 month maximum interval) NOTE: EACH APPLICABLE REQUIREMENT ON FORM 2000-604 NEEDS TO BE SPECIFICALLY ADDRESSED IN ITEM 5. NOTE: COMPLETION OF INFORMATION IN SHADED AREA OF THIS FORM IS OPTIONAL Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE CONTROL EQUIPMENT - MISCELLANEOUS FORM 2000-400 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-113 4. Unit identification code: P-113 5. Control device code: Enclosed Combustor (ECD) 6. Manufacturer and model number: Cimarron 7. Date placed in service: November 2005 Date of last modification: October 2017 8. Describe the device being used. Attach a diagram of the system. The emissions from the P-113 still vent are routed to an enclosed combustor. Emissions from the flash tank are routed back to the inlet stream. Enclosed combustor shared by units P-112 and P-113 9. List the pollutants to be controlled by this equipment and the expected control efficiency for each pollutant on the table below. ❑ Documentation attached EITHER the outlet pollutant concentration OR the control efficiency must be provided. Pollutant Outlet pollutant concentration gr/acf ppmv Control Efficiency (%) VOC 95% HAPs 95% iscuss hour th 'colIected;material will be handled or r'eus_e or: Operating Permit Application Colorado Department of Public Health and Environment Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE GLYCOL DEHYDRATION UNIT FORM 2000-307 Rev 06-95 1. Facility name: Marla Compressor Station 2. Facility identification code: CO 123-0243 3. Stack identification code: P-113 4. Dehydrator (Unit) code: P-113 5. Unit description: Triethylene glycol dehydrator for dehydration of inlet wet gas stream 6. Indicate the dehydrator control technology status. D Uncontrolled X Controlled If the dehydrator is controlled, enter the control device number(s) from the appropriate forms: 2000-400 ECD 2000-403 7. Manufacturer: Custom 8. Model & serial number: TEG Dehydration Unit Serial Number: Custom 9. Regenerator heater design rate or maximum continuous rating (mmBTU/hr): 0.75 10. Date first placed in service: November 2005 Date of last modification: October 2017 11. Flash Tank: X Yes ❑ No Flash tank vented to: 0 atmosphere X recycled 12. Glycol Circulation rate: 8.20 gallons per minute (maximum) gallon per pound of H2O OR 13. Pipeline Capacity: (mmscf/day): 55.0 14. Glycol Type: X Triethylene Glycol O Ethylene Glycol ❑ Other (specify) 15. Glycol Make-up Rate (gallons/year): 16. Computer model input & output printout attached x Glycalc 4.0 results 17. Gas Pressure (psi): 1,000 18. Gas Temperature (°F): 106 19. Gas composition test results Test date: 06/28/2017 VOC BTEX HEXANE value units value units value units 12.097 mol% 0.047 mol% 0.124 mol% *****For this emissions unit, identify the method of compliance demonstration by completing Form 2000-500, ***** DESCRIPTION OF METHODS USED FOR DETERMINING COMPLIANCE. Attach Form 2000-500 and its attachment(s) to this form. ***** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** NOTE: THE SPECIALIZED APEN FOR A GLYCOL DEHYDRATION UNIT MUST BE COMPLETED AND SUBMITTED IF THE STILL VENT EMISSIONS HAVE NOT BEEN REPORTED BEFORE Operating Permit Application CERT1141CATION FOR STATE -ONLY CONDITIONS FORM 2000-800 Colorado Department of Health Air Pollution Control Division Facility Name: Maria Compressor Station Facility Identification Code: CO 123-0243 09-94 VI. SIGNATURE OF RESPONSIBLE OFFICIAL - STATE ONLY CONDITIONS A. STATEMENT OF COMPLETENESS I have reviewed this application in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this application are true, accurate and complete. B. CERTIFICATION OF FACILITY COMPLIANCE STATUS FOR STATE -ONLY CONDITIONS (check one box only) X I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. ❑ I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements, except for the following emissions unit(s): (list all non -complying units) WARNING: Any person who knowingly, as defined in § 18-1-501(6), C.R.S., makes any false material statement, representation, or certification in, or omits material information from this application is guilty of a misdemeanor and may be punished in accordance with the provisions of § 25-7 122.1, C.R.S. Printed or Typed Name David M. Jost Title Vice President of Northern Operations Signature 7 )a...- LAY A' ,d1c Date Signed 6//o2,4476 ii> SEND ALL MATERIALS TO: COLORADO DEPARTMENT OF HEALTH APCD-SS-B 1 4300 CHERRY CREEK DRIVE SOUTH DENVER, CO 80246-1530 I; I; 3 Attachment F Facilitywide Emission Summary - Fonn APCD-102 Marla Compressor Station Form APCD-102 Company Name: DCP Operating Company, LP Source Name: Marla Compressor Station Source AIRS ID: 123/0243 Colorado Department of Public Health and Environment Air Pollution Control Division Facility Wide Emissions Inventory Form Ver. April, 2015 AIRS ID 123/0243/052 123/0243/053 123/0243/054 123/0243/059 123/0243/060 123/0243/061 123/0243/062 123/0243/063 Equipment Descriplion engine C -148/P-102 Engine C-135/'-103 Engine C -151/P-104 Engine C -166/P-109 Engine C -174/P-110 Engine C -176/P-111 P-112 TOG Dehy P-113 TEG Dehy Permitted Sources Subtotal. Pent Evempt S Contra led Potential In Emit (PTE Criteria (TPY) I HAPs (Ih r) Criteria (TPY) I HAPs( ',sly0 224-TMP TSP PA110 PA'12.5 002 NOx VOC CO 1 11CHO Acc/al -Acre BZ Tel ED Xyl n -Hex Meth 224-TMP TSP P1)110 P1142.5 S02 NOx VOC CO 111CI10 AcelaT Acro BZ Tor ED Xyl n -Hex Me10 1.0 1.0 1.0 0.0 157.0 214 114.2 1 2,071 283 267 160 57 3 20 0 310 0 1.0 1.0 1.0 0.0 42.8 14.3 42.8 1 499 141 133 80 28 1 10 0 155 0 1.0 1.0 1.0 0.0 157.0 21.4 114.2 1 2.078 283 267 160 57 3 20 0 310 0 1.0 1.0 1.0 0.0 28.5 143 42.8 I 499 141 133 80 28 1 10 0 155 0 1.0 1.0 1.0 0.0 157,0 21.4 114.2 I 2,078 283 267 160 57 3 20 0 310 0 1.0 1.0 1.0 0.0 14.3 10.0 28.5 I 499 141 135 00 28 I 10 0 155 0 1.1 1.1 1.1 0.0 178.4 243 129.8 I 2,371 323 304 169 65 3 23 0 354 0 1,1 1.1 1.1 0.0 32,4 16.2 32.4 I 569 '161 152 91 32 1 11 0 177 0 1.1 1.1 1.1 0.0 171.4 24.3 129.8 1 2.371 323 304 183 65 3 23 0 354 0 1.1 1.1 1.1 0.0 16.2 11.4 32.4 I 569 161 152 91 32 I II 0 177 0 1.1 1.1 1.1 0.0 178.4 24.3 129.8 I 2,371 323 304 183 65 3 23 0 354 0 I. 1.1 1.1 0.0 32.4 16.2 32.4 I 569 161 152 91 32 I 11 0 177 0 0.0 0.0 0.0 0.0 0.13 453.51 0.61 1 0 0 0 44.041 67,470 3,619 48,894 15,436 0 0 0.11 0.0 0.0 0.0 0.13 10.62 0.61 I 0 0 0 3.191 5,044 277 3,771 320 0 0 0.0 0.0 0.0 0.0 0.19 300.24 0.87 1 0 0 0 56,441 86,867 3.893 63.211 10,379 0 0 0.0 0.0 0.0 0.0 0.19 14.26 0.87 I 0 0 0 4,266 6,641 361 4,904 423 0 0 6.3 6.3 6.3 0.2 1006.6 893.0 733.3 i 13,349 1,817 1,713 101,511 154,701 7,528 112,231 25,815 1,993 0 63 6.3 6.3 0.2 167.1 107.2 213.0 i 3,204 908 856 7,972 11,867 645 8,738 742 996 0 I I I 1 I I I I I 1 APEN Only Subtotal. APEN Exempt /hatgN0canl sources 0.0 0.0 0.0 0.0 0.0 0.0 0.0 I 0 0 0 0 0 0 0 0 0 0 0.0 0.0 0.0 0.0 0.0 0.0 0.6 I 0 0 0 0 0 0 0 0 0 0 I Insignificant Acitives(Sec Lis') 0.0 0.0 0.0 0.0 0.7 12.0 0.6 1 0 0 0 91 0 0 0 480 152 0 0.0 0.0 0.0 0.0 0.7 12.0 0.61 0 0 0 _ 91 0 0 0 480 152 0 I 1 1 1 I I 1 I I 1 Insignificant Subtotal. 0.0 0.0 0.0 0.0 0.7 12.0 0.6 I 0 0 0 91 0 0 0 480 152 0 0.0 0.0 0.0 0.0 0.7 12.0 0.6 1 0 0 0 91 0 0 0 480 152 0 Total, All Sources. 63 6.3 6.3 0.2 10073 905.0 733.9 , 13,349 1,817 1,713 101,602 154,701 7,528 112,231 26,295 2,145 0 6.3 63 6.3 0.2 167.8 119.2 213.6 3,204 908 856 8,063 11,867 645 8,738 ' 1,223 1,149 0 Uncontrolled HAPs Summery (TPY).1 6.7 I 0.9 I 0.9 I 50.8 I 77.4 I 3.8 I 56.1 I 13.1 I 1.1 I 0.0 I Uncontrolled Total, All HAPs (TPY) =I 210.7 Footnotes: I. This form should be completed to include both existing sources and all proposed new or modifications to existing emissions sources 2. lithe emissions source is new then enter "proposed" under the Permit No. and AIRS ID data columns 3. HAP abbreviations include: BZ = Benzene 224-TMP = 2,2,4-Trimethylpentane Tol = Toluene Acetal = Acetaldehyde EB = Ethylbenzene Acro = Acrolein Xyl = Xylene n -Hex = n -Hexane HCHO = Formaldehyde Meth = Methanol 4. APEN Exempt/Insignificant Sources should he included when warranted. Cmlrolled HAPs Summary (TPY)- 1.6 I 0.5 I 0.4 I 40 I 5.9 I 0.3 I 4.4 I 0.6 I 0.6 I 0.0 Controlled Total, All HAPs (TPY) _) 18.3 I Attachment G Updated O&M Plan P-112 P-113 Marla Compressor Station COLORADO Air Pollution Control Division Department of Public Health & Environment Form APCD-302 Air Pollution Control Division Operating and Maintenance Plan Template for Glycol Dehydration Systems Ver. January 1, 2018 The Air Pollution Control Division (Division) developed this Operating and Maintenance Plan (O&M Plan) for glycol dehydration systems that use emissions controls, permitted at synthetic minor and major oil and gas facilities in the State of Colorado. An OEtM Plan shall be submitted with the permit application when required. One OEtM Plan may be used for multiple dehydrators 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, OEtM Plan and a construction permit will be issued with the requirement to follow the OEtM Plan as submitted. If the template is not completed correctly, the Division will work with the operator 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. An existing approved O&M Plan may be modified without a permit modification or permit reissuance, but the operator must adhere to the requirements of the existing approved OM Plan until an approval letter is issued for the new OEtM Plan. The operator is required to use the Division -developed O&M Plan template forms in order to meet minimum expectations within a standard, organized format. Do not modify the structure and/or content of this template. If the facility or equipment is subject to other state or federal regulations with duplicative requirements, the operator shall follow the most stringent regulatory requirement. For sources that are subject to the Title V Operating Permits program: in accordance with Colorado Regulation No. 3, Part C, Section V.C.5., some or all of the monitoring specified in this O&M plan will be incorporated as specific conditions in the source's Operating Permit, and in some cases permit limits will be established for certain operational parameters. Submittal Date: July 2018 Section 1 - Source Identification For new permits, some of this information (i.e., Facility AIRS ID, Permit Number, and AIRS Point ID) may not be known at the time of application. Please only fill in the fields that are known and leave the others blank. Company Name: DCP Operating Company, LP Facility Location: Weld County Facility Name: Marla Compressor Station Facility AIRS ID (for existing facilities) 123 - 0243 Emission Units Covered by this O&M Form Facility Equipment ID P-112 P-113 Permit Number (if known) 95OPWE020 95OPWE020 AIRS Point ID (if known) 062 063 Glycol Type Used a TEG TEG Equipped with Flash Tank? (YIN) Y Y a Glycol types are Ethylene Glycol (EG), Diethylene Glycol (DEG), or Triethylene Glycol (TEG). CD_'_Internal Use Only Page 1 of 5 COLORADO Air Pollution Control Division Department of Public Health & Environment Section 2 - Maintenance Schedules Check one of the following: Facility shall follow manufacturer recommendations for the operation and maintenance of the emissions unit and control devices. These schedules and practices, as well as all 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 all maintenance records showing adherence to these practices, shall be made available to the Division upon request and shall be consistent with good air pollution control practices for mipimizing emissions as defined in the New Source Performance Standard (NSPS) general conditions. Section 3 - Recordkeeping Requirements The following box must be checked for the O&M Plan to be considered complete: Synthetic minor and major sources are required to maintain maintenance and monitoring records for the requirements of this OEtM Plan for a period of five (5) years. If applicable state requirements or any Federal NSPS, NESHAP, or MACT require a longer record retention period, the operator must comply with the longest record retention requirement. Section 4 - Monitoring Requirements Control Equipment Information Table 1 below details the monitoring parameters and frequency for control equipment depending on the type of control equipment and the requested permitted emissions at the facility. Indicate the emissions control type(s) by checking the appropriate boxes. In addition, check the appropriate box for "Monitoring Frequency" based on the facility -wide permitted VOC emissions. Table 1 Emissions Control or Recycling Method Flash Still Tank Vent (if present) Parameter Monitoring Frequency 11 Permitted ❑ Permitted Facility Emissions < 80 tpy VOC Facility Emissions ≥ 80 tpy VOC * Condenser b ❑ ❑ Condenser Outlet Temperature Weekly Monthly Enclosed Flare or Combustor ❑ Pilot Light and Auto- igniter Monitoring Daily Weekly �� Visible Emissions Observation e Daily Weekly Elevated Open Flare C ❑ ❑ Pilot Light and Auto - igniter Monitoring d Daily Weekly Visible Emissions Observation e Daily Weekly Thermal Oxidizer ❑ ❑ Combustion Chamber Temperature r Daily Weekly Visible Emissions Observation e Daily Weekly * Condenser is present, but functions as a secondary control device. Page 2 of 5 COLORADO Air Pollution Control Division Department of Public Health £r Environment Table 1 Emissions Control or Recycling Method Flash Still Tank Vent (if present) Parameter Monitoring Frequency a Permitted ❑ Permitted Facility Emissions < 80 tpy VOC Facility Emissions ≥ 80 tpy VOC Vapor Recovery Unit (VRU) or Recycled or Closed Loop System g ❑ Monitoring requirements, including parameters and frequency, to be determined by the operator and listed below, and approved by the Division pP Routed to Reboiler Burner as Fuel h ❑ ❑ Monitoring requirements, including parameters and frequency, to be determined by the operator and listed below,. and approved by the Division Other ❑ ❑ Monitoring requirements including specific parameters and frequency to be determined by the operator and described in Section 5 below, and approved by the Division b Condenser Maximum 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 Table 2: Condenser Maximum Outlet Temperature ❑ 160 °F ❑ °F A maximum temperature greater than 160 °F requires approval from the Division. Supporting documentation must be submitted with the permit application and made available to the Division upon request. ` Elevated Open Flare An open flare permitted after May 1, 2014 and used to comply with Regulation No. 7 Section XVII must be approved by the Division as an alternate emission control device prior to operation, in accordance with Regulation No. 7 Section XVII.B.2.e.; see PS Memo 15-03. d Pilot Light Monitoring Options If emissions are controlled by flare or combustor, then the operator must indicate in Table 3 the method by which the presence of a pilot light will be monitored. One primary method for Pilot Light Monitoring must be checked and, optionally, up to two backup methods may be checked. Table 3: Pilot Light Monitoring Primary Back-up Monitoring Method ❑ /1 Visual Inspection ❑ ❑ Optical Sensor ❑ ❑ Auto -Igniter Signal a ❑ Thermocouple * * A Flame Rod is used for pilot light monitoring at this facility. e Visible Emissions Observation and Method 22 Options At the frequency specified in Table 1, the operator is required to conduct an inspection of the subject Page 3 of 5 COLORADO Air Pollution Control Division Department of Public Health & Environment combustion device for the presence or absence of smoke (e.g., visible emissions). If smoke is observed during the visible emissions inspection, the operator has the option to either (1) immediately shut-in the equipment to investigate the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed; or (2) conduct a formal Method 22 observation to determine whether visible emissions (as defined per Regulation No. 7, Section XVII.A.16.) are present. If a Method 22 is conducted, the record of the observations shall be maintained as required in Section 3 of this O&M Plan. If visible emissions are observed by Method 22, the operator shall immediately conduct any necessary repairs and maintain records of the specific repairs completed; if repair cannot be immediately completed, the operator shall shut-in the equipment, conduct any necessary repairs, and maintain records of the specific repairs completed. The Division has historically approved a "check box" to satisfy the Method 22 documentation procedures. The Division will continue to accept the "check box" recordkeeping format in instances where no visible emissions are observed in order to demonstrate compliance with the Method 22 requirement. If a flare is not subject to Regulation No. 7 requirements (as described in the permit), a similar approach may be employed where the operator may conduct an inspection for presence or absence of smoke, and, if smoke is observed, the operator has the option to (1) immediately conduct repairs and maintain records of the specific repairs completed; (2) shut-in the equipment to investigate the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed; or (3). conduct a formal Method 9 observation to determine the opacity of the visible emissions, and conduct repairs if necessary. Thermal Oxidizer: Minimum Combustion Chamber Temperature If emissions are controlled by thermal oxidizer, the minimum combustion chamber temperature shall be: Table 4: Thermal Oxidizer Minimum Combustion Chamber Temperature 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 Division -approved testing. Test data shall be submitted with and attached to O&M Plan. g Vapor Recovery Unit (VRU) or Recycled or Closed Loop System In the space provided below, please provide a description of the emission control system, including an explanation of parameters monitored, monitoring frequency, and how the system design ensures that emissions are being routed to the appropriate system at all times, or during all permitted runtime. Also, provide a description of how downtime is tracked and recorded. Attach additional pages if necessary. The flash tank is hard piped to the condensate tanks which feed the VRU. Page 4 of 5 COLORADO Air Pollution Control Division Department of Public Health & Environment h Routed to Reboiler Burner as Fuel 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. Describe the cycling frequency of the burner. Describe the other parameters and frequency for monitoring of this emissions control approach. Attach additional pages if necessary. Section 5 - Additional Notes and OEtM Activities Please use this section to describe any additional notes or operation and maintenance activities, or if additional space is needed from a previous section. Attach additional pages if necessary. The enclosed combustor (ECD) used for shared still vent control for both units P- 112 and P-113 has a 3.0% annual downtime for maintenance and malfunctions, during which time, still vent emissions will be vented to atmosphere. ECD Runtime Status will be tracked on at least a daily basis to determine ECD downtime. ECD downtime is defined as periods when emissions from the still vent are routed to the atmosphere instead of to the ECD. If both units P-112 and P-113 are down in addition to the ECD, this does not constitute downtime as no emissions are being produced. Natural Gas throughput to each dehy, P-112 and P-113, is metered individually. Metered values are then used in the monthly GLYCalc runs for each individual TEG dehy unit. These metered throughput values will be combined with the ECD Runtime Status to track throughput against the downtime -specific gas processing limits for each individual TEG dehy unit. Page 5 of 5 Attachment H Facility Plot Plan Marla Compressor Station dcp Midstream_ Figure 2 Marla Compressor Station Legend x: 'm x0 'ao4a.1'r.n r&u�r�4dwmSae�'Suw"/0ynrwIu47muraeSum—aax.©c®vaxvauc�uxvw4`.e.m m a 4 8 f7 Mewbom Pig N q Launchers F.?, -at e a n f/ C Ig a ,L..24...,_ TK-0175 TK-0176 ea Stormwater 9 Storrmvater A Sheds Surge I° Tank el ® • C x—x—x—x—x—x—x—x—x—x—x—x—x—x—x—x—x—x—x—x—x—x—x—x—x—x—xl a r.'- m ¢i m RI m WI m ON m On FAWN m en m IC m m lW 01 m la 13,31 CI m E3 m m m 6 LIMO m w m Al m a1 Fit et m Pe is m m m t& ® x QD 4. a I F-0202 S I coalescer v-0214 a Cu Discharge n x Scrubber m Used oil 8 x TK-1071 TK-1072 FillersI Pig Launcher Gate OM Meter -1 i, Light Plant ; ; Methanol Tank —O— Sound Wall m lx' i Berm —• • Ventbustor O Air Receiver p Radio Antenna x — x • Fence County Road 40 e� Gate Entry la - :" ' Glycol•_ Stonrnvater Stormwaler x 4! la .. Reboiler ".' - , - ^ Cooler TK-1073 e LJ\ Slop Oil X `a Analyzer Id Buikting BERM la ® Meter Run GLYCOL SKID V-0114 T-0102 F-0202 Discharge AC -0151 F Contactor Coaiescer Snubber Cooler a I it x a I M .r1 i L r., J- Box e x Shed la o TK-1080 TEG DEHY6G TION UNIT s x a la v d 1 m Drum BERM G Storage BERM D 9 w TK-0172 V-0130 atom -water Intel Separator C-01478 C-0135 C-0151 I a x I tli le`— '� ubeOi Luba Oil Area T-0101/ x ®❑ C / I}I}I}------ p C -01 Lobe Oil C-0176 C-0174 Lobe Oil a I x 't Contactor I / TK-1148 TK-1135 TK-1151 Luke Oil 6 1 le V-600�O Fuel Meter Shed Lube Oil Luba Oil Lube Oil I a ..,,l° s BERM C De Tank De Tank Day Tank l FUEL GAS SKID y y "� Oe � C TK-1074 I- -a—TK 8 Lube Oil u-zso 0 a 1 t Used Oil 'l -TK-7 Norkool V-200 V-300 TK-0174 0 i g xMEM la "-—TK-S TEG ter` Day Tank i na 1 xo 1� r . I�—TK-5 Methanol Luba Oil O —O —v —o —G —G' -3 —cc —o —C- IC i xfi :. J+—TK-5B Methanol TK-1168—►O —TK-1174 x Site Features la BSI la m e'll'' ,g VRU Day I Switch Rack Enterprise m x Radio Truck Loading O Tank Oil BERM B R Sphere Pig I Berm xa 0 0 AnteAnna Air Shed Launcher n x V-0101 ® pig is Skid/Unit le Receiver MCC Platform�� 1 O Traps ' xis MCC t V-0117 Slug Catcher BERM A TK-0515 x Produced Pad Surface IM xii Dumpster Instrument Inlet Separators - '- Water q q q x Feature symbols not to scale NI 0 n so IM--(/ Air Building 7K-0850 Produced Methanol V-0116 Slug Catcher TK-09-0501 • .®. a TK-0516 n I Water m la I ^ Pump ,m w m w n m m - m Va m m es m m es m 43.63 13: NI: rd a n :II m rd to m m m m eo m e m t 5 t 131,:32 :3,122 m m m re m sa m m oOm ae n m el w m m■ Lx —x —x —x —x x—x—x————xxx—xxx—x—x••x x —x —x —x —x —x —x —x —xis V-0104 TK 09-0502 Produced Water m m m n m m w 1 Aix —x —x —x x to rn v<r, s,<rs ry m axon a�;: ea a s e n is %;r t .xx 1 xe..Lmxnr nx/ to Feel tsao Notes: Equipment connections an shown for process ...lion only end ere not e reflection of es -piped conditions In Ne INN. . :::,.. ..a.. n - .�'a .:4='-:v("z� r�?JLIsfi$e'IfsP,Rr l!PilGfi/9Wi4C3�h+196'9!f7�i�fJBL#YI[b�"'t'La£kP.1`t%/Flil r�s�l?');11i13&ail8aigil FRlb:11&411k I1nia431":!!iii.lkd�-.e^,1'k9fd?-b36.+�iPa'_'.Idrg 714.:rarA1�SF.i1sZ3%'IS:H.;:'.E1:3:.tid1,.+::P431J2iR411�3p<51!d,+�i'7 tai'✓►9?rtdl-i� ₹I :zah'. dlr:��i%Ycw.',h7SY:. sn,., 1n3 .I,r, trr ur..• In„rr. _..1 FYI-,_ / core gni I ensue,. xz Nse upame. A APEX M:Wrojects\DCP\ SPCC \Marla_CS\Projects\DCP_Marla_CS_Figure2_20180109.mxd Modified 1/10/2018 by Joshua.Zeeb Apex Companies, LLC NAD 1983 UTM Zone 13N Coordinate System Attachment I Updated Compliance Assurance Monitoring (CAM) Plan P-112 P-113 Marla Compressor Station APPENDIX H Compliance Assurance Monitoring Plan — Dehydrators I. Background a. Emission Unit Description Natural Gas Dehydration Systems using triethylene glycol (P-112, P-113); b. Applicable Regulation, Emission Limit, Monitoring Requirements: Regulations: Emission Limitations: c. Control Technology: Operating Permit Section II, Section 3.1 VOC (P-112) 10.62 TPY VOC (P-113) 14.26 TPY Any Individual HAP (facility -wide) Total HAP (facility -wide) Enclosed Combustor (one for both units) 8.O TPY 20.0 TPY II. Monitoring Approach Indicator No. 1 I. Indicator Measurement Approach Enclosed Combustor Presence of a flame is continuously monitored 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. This enclosed combustor is permitted 3% annual downtime, during which the presence of a flame is not required. II. Indicator Range Any absence of a flame, apart from during periods of permitted downtime, will trigger an investigation to determine the problem and to perform corrective action, recordkeeping relating to the problem, and reporting of the problem when necessary. III. Performance Criteria a. Data Representativeness Device sensing heat will determine the presence or absence of the flame. b. Verification of Operational Status The observation of the presence of a flame will indicate that the device is operational. c. QA / QC Practices / Criteria Annual verification or replacement. d. Monitoring Frequency Heat sensor will be monitored continuously. e. Data Collection Procedures Excursions and any adjustments or repairs made to the enclosed combustor following an excursion shall be recorded in a log. f. Averaging Time Heat sensor will operate continuously and averaging will not be necessary. III. Justification a. Background: The pollutant specific emission unit are two individual dehydration units, which function to remove water vapor from the gas stream. Flash emissions from the inlet dehydrator flash tanks are routed to the plant inlet using a closed loop system with 100% efficiency and the still vent emissions are routed to a shared enclosed combustor. b. Rationale for Selection of Performance Indicators and Indicator Ranges: The destruction of VOC is dependent upon combustion. The presence of a flame indicates the ECD is operational. In order to ensure the ECD is operating at all times that emissions are vented to it, it is continuously monitored for the presence of heat / a flame. Hello