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Home My WebLink About20192041.tiffCl=P Midstream DCP Operating Company, LP 370 17th Street, Suite 2500 Denver, CO 80202 303-605-2039 June 26, 2018 Sent via UPS Tracking #: 1Z 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-BI Denver, CO 80246-15.30 Re: DCP Operating Company, LP; Marla Compressor Station (123/0243) Title V Operating Permit Modification (95OPWE020) Natural Gas Compressor Engines (AIRS 052 - 054, 059 - 061) JUG"272018 Ms. Elie Shuchardt: 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. The following is a summary of the changes DCP is requesting in this minor modification application to permit 95OPWE020. Summary of Changes • Alternative Operating Scenario (AOS) Engine Replacements DCP provided a list of AOS Engine updates in the Title V Renewal application submitted December 28, 2016. The following list covers all AOS engine replacements that have occurred since the renewal application was submitted. o Compressor Engine C-135 (AIRS 053) • Waukesha L-7044 GSI Compressor Engine: engine included in 2013 operating permit was replaced under AOS provisions; dated 04/2017 o Compressor Engine C-151 (AIRS 054) • Waukesha L-7044 GSI Compressor Engine: engine included in 2013 operating permit was replaced under AOS provisions; dated 06/2018 o Compressor Engine C-174 (AIRS 060)1 • Waukesha L-7044 GSI Compressor Engine: engine included in 2013 operating permit was replaced under AOS provisions; dated 03/2018 1The Title V renewal application submitted December 28, 2016 indicated an AOS engine update for C-174 (SN: C-13849/1) which occurred 06/2013. The AOS engine replacement indicated in this application represents a more recent engine replacement, dated 03/2018. Please see the included APEN for the updated serial number for this engine. ?v\J‘c?)e)JietiO 2019-2041 • Compressor Engines C-148, C-135, C-151, C-166, C-174, C-176 (AIRS 052-054, 059-061)2 o Update the fuel use limits for all six compressor engines at this facility, based on a revised estimate of the Btu/scf fuel heat value (FHV) of the natural gas combusted to power these units. The original fuel use limits were calculated from an FHV of 1,200 Btu/scf. DCP has since determined that these engines typically run on a much leaner natural gas mixture, closer to 1,020 Btu/scf. A FHV of 1,020 Btu/scf was used to calculate the following revised annual fuel limits for all six compressor engines: • Increase annual fuel use limits for engines C-148, C-135, and C-151 from 84.5 MMscf/yr to 99.4 MMscf/yr • Increase annual fuel use limits for engines C-166, C-174, and C-176 from 96.4 MMscf/yr to 113.4 MMscf/yr o DCP is not requesting any changes to the criteria or non -criteria emission limits for these engines. The updated FHV of the combustion natural gas only affects the annual volume of natural gas combusted, in standard cubic feet. The annual heat rate (MMBtu/yr) and resulting emission estimates will remain unchanged. This Title V operating permit minor modification application includes the following attachments: A. Responsible Official Certification B. APEN Fees C. Updated APENs (C-148, C-135, C-151, C-166, C-174, C-176) 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 RShankaranADCPMidstream.com. Sincerely, DCP Operating Company, LP Roshini Shankaran Environmental Engineer Enclosures 2Per previous e-mail conversations, DCP has indicated that the existing MACT Subpart ZZZZ applicable requirements in the active Title V Operating Permit for this facility are incorrect. DCP requests that the Subpart ZZZZ applicable requirements be corrected as part of this application. 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 ),61/':".1/ -11 ctl>k 91iff /7 Signature of Responsible Official Date 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 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 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 384542 COLORADO 1 I • ' ' Hah�bEnrlwnm�n� Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 052 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action O NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source O PORTABLE source O 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 - 0 MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O 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 - ❑ 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-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. Qov /cdphe /attainment) Normal Hours of Source Operation: 24 O Yes ❑ No hours/day 7 days/week 52 weeks/year 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 //y�� COLORADO 2 I AV H $thfr��mvmuf Hek0i6EnvLLonmaM 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 ❑ 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 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: ❑ Lean Burn ❑✓ Rich Burn Ignition Source: 0 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? 0 O2 Sensor (mV) ❑NOx Sensor (ppm) Is this engine equipped with a Low-NOx design? ❑ Yes 0 No Engine Dates: What is the manufactured date of this engine? 8/25/1972 What date was this engine ordered? 1972 ❑ 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 3 COLORADO M.. E. En.onnonl Permit Number: 95OPWE020 AIRS ID Number: 123 /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 O eratar Stack ID No r Discharge Height Above Ground Level (Feet) ,y Tertap ( F) Flow Rafe (ACFM) V ft°ei 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) 0 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 Actual Annual Fuel Use Requested Annual Permit Limit ≤MMSCF/year) (ScF/hour) (MMSCFIyear) 11,347 82.9 99.4 From what year is the actual annual amount? 2017 7 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Indicate the type of fuel used': ❑✓ 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): Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO wwim vsnxmnn.,am Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 052 [Leave blank unless APCD has already assigned a permit it 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? E Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): ....::�:... > .: Pollutant'•:. . .....• ..':... .: ::..; :_. ,.: ,- Primary Control Equipment Description-: •: .: .. Overaequ ested Control • - .. -::• •..Efficiency; •; : ' Osns . ( redaction in emtssro ) TSP (PM) PM10 PM2.5 SOx NO x NSCR 73% 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? 2017 • • •�� .� • - Crrtena Pollutant Emissions inveto � :` �:• .. n Emision Factor.:: s • Actual Annual Emissions .. Itequested,Annua. Permit Emission .Limit(s)...,. Pollutant :: z;_:::.::::~.::. ;.....,...,. :.•.::�:-F:::.::: .:::...:r.•`:.s::• ...:Source -.Uncontrolled._, ..,.,.:...•...-,:r :.:...... ,, Basis.,-., .: .: �...:: .:::....,.:: ..:.U.__.:.:_ - .Units-. .. .<........ -• _.M.:..:: .;:rs .. ::.._,. _7,4 _._._ :: •(AP -42;::. �. :. ) : .r.Mfg.'etc Uncontrolled .._ -., . �•-..Emissioris�. "�- /year) • (cons/ ear <. Controlled ..; ,=::Em1ss>ons- . y . ) . (Tans/ ear ...:--:-:-(Tonslyear) -= Uncontrolled :. :Emissions ;. Controlled:.... `'.. ,.. -:' Emusiorrs��-�� ::: ( y ) _.. Tons/ear TSP (PM) 1.94E-02 lb/MMBtu / AP -42 0.90 0.90 0.98 0.98 PM10 1.94E-02 lb/MMBtu AP -42 0.90 0.90 0.98 0.98 PM2.5 1.94E-02 lb/MMBtu AP -42 0.90 0.90 0.98 0.98 SOx 5.88E-04 lb/MMBtu AP -42 0.03 0.03 0.03 0.03 NOx 11.0 g/hp-hr Mfg. 143.63 38.96 156.99 42.82 VOC 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-criteriaEl Yes ❑ No 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: : ` Non= Criteria Reportable Pollutant Emissions inventory -. .. .. .. .... . . - :. ' Chemical..Name .,.• . Chemical -:: Abstract._. Service (CAS) Number.;-.:: "":"": _ -. ' Emission Factor •"��-�'-:~ "':� ."_ ' " . '.:Actual:Annual:Emissionsg• :.. � ::.,: :.. ..:::•.., Uncontrolled Basis Units. Source:': :. (AP -42, .. :;.Mfg. etc .: ) • Uncontrolled.:^';. • Emissions ,-; .. � ( y J :... ��': Pounds% ear .Controlled Emissions . ._.:(pQundslyear) .:.:.. Formaldehyde 50000 2.05E-02 lb/MMBtu AP -42 1901.39 456.33 Acetaldehyde 75070 2.79E-03 lb/MMBtu AP -42 258.77 129.39 Acrolein 107028 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. litsw COLORADO 5 I Jell& '07 Seau,55aWh m4Cfl H,p 6E5Wtan SU' Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 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. 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 Small Business Assistance Program Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 (303) 692-3175 or (303) 692-3148 Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 6 COLORADO oeaI,moat Pa., H®allh 6 Emikrnisn f 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.Qov/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: 370 17th Street Suite 2500 (Include Zip Code) 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 384543 AV COLORADO 1 I AV °"� ° `°`i Hwsnn [ Enu= 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 O 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 $1,500.00 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 O Change company name ❑ Add point to existing permit ❑✓ Change permit limit O Transfer of ownership4 -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: O Other (describe below) 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. 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. Roy /cdphe/attainment) Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec -Feb: 25% Mar -May: 25% June -Aug: 25% Sept -Nov: 25% ❑✓ Yes ❑ No Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 2 laroea.ropentmaah& Haahh 6Fnabanmcnl 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 wilt be used for emergency back-up power? Engine Make: Waukesha Engine Model: L7042 GSI Serial Number': 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 0Rich Burn Turbocharged Ignition Source: Q Spark El Compression Aspiration: El Natural ❑ 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? 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_ hours/year 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 COLORADO yrn,.noi wau. ...AO b FnNwnnenu 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 Geographical Coordinates (Latitude/Longitude or UTM) 40.2767 / -104.5475 Operator Stack ID No Discharge Height Above Ground Level ( ) Temp F � v Flaw Rate 1�CFA ( � sr Velocity (ft/sec) �r C-135 25 1,125 6,967 108 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward ❑ Horizontal El Downward El Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): ❑ Square/Rectangle Interior stack diameter (inches): ❑ Other (describe): 14 ❑ Upward with obstructing raincap Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information ueI Use Rate ® 10 CF/hour 11,347 actual AnnuaCFuel_ SCF/year,) 82.13 u'ested Annual Permit Limit' MSCFI year 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) El Landfill Gas Heating Value: BTU/scf El 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 Permit Number: 95O PWE020 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 O No If yes, describe the control equipment AND state the overall control efficiency (% reduction): TSP (PM) PACK. PM2.5 Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) SOX NOx VOC NSCR 82% NSCR 33% CO Other: NSCR 63% 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) PM10 PM25 Criteria Pollutant Emissions Inventory Emission Factor Uncontrolled Basis 1.94E-02 Units lb/MMBtu Uncontrolled Emissions (Tons/year). Controlled Emissions - (Tons/year) Source (AP -42, Mfg. etc) AP -42 0.89 0.89 Requested Annual Permit Emission'Limit(s)7 Uncontrolled Emissions (Tons/year) 0.98 Controlled Emissions - (Tons%year). 0.98 1.94E-02 lb/MMBtu AP -42 0.89 0.89 0.98 0.98 SOX NOx VOC 1.94E-02 Ib/MMBtu AP -42 0.89 0.89 0.98 0.98 5.88E-04 lb/MMBtu AP -42 0.03 0.03 0.03 0.03 CO 11.0 g/hp-hr Mfg. 142.33 25.74 156.99 28.54 1.5 glhp-hr Mfg. 19.41 12.87 21.41 14.27 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 ❑ No 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: Formaldehyde Acetaldehyde Acrolein Non -Criteria Reportable Pollutant Emissions Inventory: Chemical Abstract Service (CAS) Number 50000 75070 107028 71432 Emission Factor, Uncontrolled Basis 2.05E-02 Units lb/MMBtu Source (AP -42, Mfg. etc) AP -42 Actual Annual Emissions' Uncontrolled Emissions (Pounds year) ., 1884.19 Controlled Emissions (Pounds/year) 452.21 2.79E-03 Ib/MMBtu AP -42 256.43 128.22 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-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 © COLORADO 5 'AV W w«+nnu�, cnmrau+am Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 053 [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. 6 (26 120 c 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 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-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-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 6 Ia� Heattli FrDIV 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 /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: p Code370 17th Street Suite 2500 (Include Zip Code) 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 ' 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 384544 COLORADO 1!AVNwllX EErvlI!diM!n! 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 0 NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source 0 PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 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 O Change permit limit 0 Transfer of ownership4 ❑ 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 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 )WCD-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. General description of equipment and purpose: C-151 /P-104 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) 0 Yes El No Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec -Feb: 25% Mar -May: 25% June -Aug: 25% Sept -Nov: 25% 14, Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 2 1 AV• COLORADO b t IP Lk Permit Number: 95O PWE020 AIRS ID Number: 123 /0243 / 054 [Leave blank unless APCD has already assigned a permit if and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: El 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: 230355 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: C cle Type: ❑ 2 -Stroke 04 -Stroke Combustion: ❑ Lean Burn 0 Rich Burn Y Compression Aspiration: ❑ Natural 0 Turbocharged Ignition Source: ID Spark ❑ Com Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ✓❑ Yes ❑ No ❑ Other: hours/year If yes, what type of AFRC is in use? ❑✓ 02 Sensor (mV) LINOx Sensor (ppm) Is this engine equipped with a Low-NOx design? ❑ Yes ID No Engine Dates: What is the manufactured date of this engine? 05/26/1972 What date was this engine ordered? Prior to 2001 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 COLORADO ��???��??? ' =7=ttf 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 r ®� S,ta 1 ® Discharge Height e ogrGround Leve i ee� �+ . i.vy r C-151 25 1,125 6,967 108 Indicate the direction of the. Stack outlet: (check one) 0 Upward ❑ Horizontal Downward O Other (describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): 14 O Upward with obstructing raincap ❑ Square/Rectangle Interior stack diameter (inches): Interior stack depth (inches): O Other (describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate Cam" 100% LoadActual Ur�nts... �� `�- Annual Fuel Use I 5-Fliea�� '' 't yg* _..-t�t.F Requested Annual Permit Lim t7 �, s �z (MMSCFfyear� 11,573 82.90 _ 99.4 From what year is the actual annual amount? 2017 Indicate the type of fuel used': 0 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-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2O17 COLORADO Permit Number: 95O PWE020 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? E] Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): :., Pollutant " :., Primary Control Equipment Description : alleste OyerRe u . ontro ::. a -::Efficiency _'`_ . `: .` ;..`: reduction in emissions)• TSP (PM) PMto PM2.5 SOX NOx NSCR 91% VOC 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 TSP (PM) PMio PM2.5 Criteria Pollutant Emissions Inventory. Emission Factor: ; -Uncontrolled : 1.94E-02 lb/MMBtu • :.Source • Mfg._etc) AP -42 Actual Annual Emissions9. Uncontrolled Emissions (Tanslyear) ..... 0.90 ...Controlled _. Emissions (Tonslye?r) 0.90 Reguested.Annual Permit Emission 'Limit(s)7,•: Uncontrolled. Emissions (Tonslyear) :. 0.98 Controlled_...;. Emissions :0-6i-is/year) 0.98 1.94E-02 lb/MMBtu AP -42 0.90 0.90 0.98 0.98 SOX NOx VOC 1.94E-02 lb/MMBtu AP -42 0.90 0.90 0.98 0.98 5.88E-04 Ib/MMBtu AP -42 0.03 0.03 0.03 0.03 CO 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 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 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 Non -Criteria Reportable Pollutant Emissions Inventory ' " . . . emical Name -" Ch• - "'Cfiemical ; :. •" Abstract ^.' : . Service" CAS ( " " ) •Basis Number. .:. " `:"•""�" " Emission Factor:. - :" Actual Annual: Emissions:= .'.; ,. _`: ......... •" Uncontrolled . >, ", " Units.: Source. ;• •;"•_ ( AP -42, Mfg. etc) Unc•ontrolled .•: • Emissions •". " .. • " (Pounds%year) " r` Cone olled "• Emissions r" (Pounds /year);:` " Formaldehyde 50000 2.05E-02 Ib/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 lb/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. COLORADO o�ummcdrw,u� Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 5 I Hamnrranmom o , 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. /Z6 (Z6 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 $152.90 and the General Permit registration fee of $1,500, if applicable to: For more information or assistance call: Colorado Department of Public Health and Small Business Assistance Program Environment (303) 692-3175 or (303) 692-3148 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: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 https: / /www. colorado. gov/cdphe/apcd Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 6 AV` MT.-tone. ol Public COLORADO HnaM1h 6 n Fnvl rimeni 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. `427?0� 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 [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 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 384545 COLORADO 1 a N,�`= Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 059 [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- Li MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name O Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership4 O Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info & 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-1 66 / P-109 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 9/25/2001 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: / /www.colorado.Rov/cdphe/attainment) Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year • Seasonal'use percentag Dec -Feb: 25% Mar -May: 25% June -Aug: 25% Sept -Nov: 25% lYes 0 N Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 �Lsl COLORADO 2 DepariamatWPeh5' Health 6 EnNron+aateM 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 wilt be used for emergency back-up power? gee Pctf`ae .( L.70 (Pt Engine Make: Waukesha Engine Model: L -7-e 2'GGSI Serial Number': C-13852/1 hours/year 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 0 4 -Stroke Combustion: ❑ Lean Burn Rich Burn Ignition Source: 0 Spark ❑ Compression Aspiration: ❑ Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes ❑ No If yes, what type of AFRC is in use? 0 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? 8/21/2001 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 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 4±1 HaMth 6ETYt nr, , f 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 Operator Stack ID ,o Discharge Height Above Ground Level (Feet) Temp F) Flow Rate (ACFM) s r Velocity (ft/sec) C-166 40 1,152 9,662 205 Indicate the direction of the Stack outlet: (check one) ❑ Downward ❑ Other (describe): ✓❑ Upward ❑ Horizontal 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 C� 100% toad Actual Annual Fuel Use (MHISCFIyear,l -Y Requested AnnualPermitLimit? (NfI�ISCF--„,-,,,-,,,,,r, year) .An..; , CF/hour 12,947 96.7 113.4 From what year is the actual annual amount? 2017 Indicate the type of fuel used8: fm_At,c :� IZ'Pipeline Natural Gas se,j6 L9f1G"1l ® Field Natural Gas ❑ Propane ❑ Landfill Gas ❑ Other (describe): (assumed fuel heating value of 1,020 BTU/scf) Heating value: 1 0 BTU /scf (assumed fuel heating value of 2,300 BTU/scf) Heating Value: BTU/scf 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 l a "dam Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 059 [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): Pollutant: TSP (PM) PM10 PM2.5 Primary Control Equipment Description 82% SOx NOx VOC NSCR CO Other: NSCR 33% NSCR 75% 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 • PM10 PM2.5 SOx NOx VOC CO TSP (PM) lb/MMBtu AP -42 Emission Factor 1.94E-02 riteria Pollutant Emissions Inventory`. Source:. (AP' -42 = • Actual Annual Emissions9 Uncontrolled Emissions (Tons/ year) . . 1.05 Controlle•d 'Emissions` 1.05 Requested Annual:P.ermit. Emission; Limit(s)7,; ..:' Uncontf olled Emissions .- .` . (Ton`s%year) 1.12 onttolled. missions? `oris7 year) 1.12 1.94E-02 1.94E-02 5.88E-04 11.0 9.5 8.0 Ib/MMBtu lb/MMBtu Ih/MMBtu glhp-hr g/hp-hr g/hp-hr AP -42 AP -42 AP -42 Mfg. Mfg. Mfg. 1.05 1.05 0.03 166.99 22.77 121.45 1.05 1.05 0.03 30.31 15.15 30.31 1.12 1.12 0.03 178.45 24.33 129.78 1.12 1.12 0.03 32.45 16.22 32.45 Does the emissions source have any uncontrolled actual emissions of non-criteriaLI 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 Formaldehyde Acetaldehyde Acrolein Benzene Non -Criteria Reportable:pollutant.Emissions Inventory ::Chemical, Abstract Se"rvice CAS. Number . 50000 75070 107028 71432 mission :Factor .ActualAnnual Emission Uncontrolled • Basis.•.s: 2.05E-02 Units . Ib/MMBtu Source • (AP -42, Mfg. etc) AP -42 Uncontrolled Emissions_:, ... (Poinids%year) 2219.06 Controlled: Emissions.. •(7."00,c4/1/* 532.57 2.79E-03 lb/MM Btu AP -42 302.01 151.00 2.63E-02 lb/MMBtu AP -42 284.69 142:34 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 5 •... AyCO•LORADO o rammt of Putun Hcatth E.nNronmo f Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 /059 [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. IZ6f2.0t 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 Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 6I�' Hu14f E ? .,o, FnNtoo�anttl STATE OF COLO RADO Caton - CDPHE, Byron <byron.caton@state.co.us> 95OPWE020 Mod Package received 6/27/2018 2 messages Caton - CDPHE, Byron <byron.caton@state.co.us> To: rshankaran@dcpmidstream.com Roshini, Thu, Jul 12, 2018 at 8:37 AM Initial review of the (6) six submitted APENs for the Minor Modification request at the Marla Compressor Station has triggered the need for clarification and/or additional information to support red -line of the submitted APEN(s) for 123- 0243-059. The listed model number on the most recent APEN is L7042 GSI. Previous APENs and the Title V Permit list this engine as Model # 7044 GSI. Please review and confirm the correct Model # at your earliest convenience. I will red -line the submitted APEN as necessary. Best Regards Byron Caton Engineering / Physical Sciences Technician Stationary Sources Program COLORA,©O Air Pollution Control Division Department of Public Health & Environment P 303.692.3220 I F 303.782.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 byron.caton@state.co.us I www.colorado.gov/cdphe/apcd As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete APENs. Additional fees may apply if an APEN is submitted without the necessary information. An application with missing information may result in longer processing times. Please note that all APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section ILA). Current APEN forms can be found at: https://www.colorado.gov/cdphe/APENforms Shankaran, Roshini <RShankaran@dcpmidstream.com> To: "Caton - CDPHE, Byron" <byron.caton@state.co.us> Cc: "Schuchardt - CDPHE, Elie (elie.schuchardt@state.co.us)" <elie.schuchardt@state.co.us> Hello Byron, Thu, Jul 12, 2018 at 12:39 PM You are correct and I apologize for the typo. The model number for AIRS Point 059 (C166) should be 7044 GSI instead of 7042. It looks like this error actually carried back to the April 2018 submittal (4/25/2018) as well. The emissions are based on a 7044 but the model was just listed incorrectly. It would be great if you can red -line this APEN for us! Elie — FYI! https://mail.google.com/mail/u/0/?ui=2&ik=06fcf96471 &jsver=RNUrTVtuKqo.en.&cbl=gmail_fe_180708.15_p4&view=pt&search=inbox&th=1648fca217... 1/2 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 /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. 384546 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 1 A� COLORADO _.alPublic F4 ahb6Fnvnonm.n' 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 ❑ 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 O Transfer of ownership4 ❑ 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 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.gov/cdphe/attainment) Normal Hours of Source Operation: 24 Seasonal I. pereetitagei • Dec -Feb: 25 A L., A,,f 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 l �� o�amw=�irvhu� /i=aUh6Pa�Hwnmenf 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 hours/year Engine Model: L-7044 GSI Serial Number6: 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 p 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? ❑✓ 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? August 2010 What date was this engine ordered? 2011 ❑ Other: 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 Departramt al PuhUc HURM1 E EnNtonnetrl 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 Geographical Coordinates (Latitude/Longitude-pr UTM) 40.2767, -104.5478 O era p Stack ID No Discharge Height Above Ground Level (Feet) Temp ( F) Ftow Rate jgcFM) " Velocity (ft/secy C -174/P-110 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) ❑✓ Circular ❑ Square/ Rectangle ❑ Other (describe): Interior stack diameter (inches): 12 ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate %,L..,oad u, (SCF/hour) Actual Annual Fuel Use Requested Annual Permit Limit? (MMSCFIyear) (MMSCF/year) 12,947 94.9 113.4 From what year is the actual annual amount? 2017 Indicate the type of fuel used': cv. w1. [v�Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) Q°'`6 U'k:i-cA '`� F.1 Field Natural Gas Heating value: 16 BTU/scf ❑ Propane ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): (assumed fuel heating value of 2,300 BTU/scf) 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. $ 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 t p 5 g � At COLORADO DepmMm[d Pahhc - Health bTnvIionr-,oht Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 060 [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): TSP (PM) PM10 PM2.5 Primary Control Equipment Description OverallRequested ; Control • (Y reduction in emissions SOx NOx VOC NSCR NSCR 91% 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 TSP (PM) lb/MMBtu PM10 PM2.5 •••Un controlled • Basts 1.94E-02 riteria Pollutant Einissions.lnventory Source Mfg: etc):__- AP -42 Actual Annual Eniissioris8. Uncontrolled . Emissions' (Tons%,year) 1.03 Controlled. - ..........................-:: :.(ons/year) 1.03 Requested Annual Permit • Emission Lim1t(s)�f`"' Uncontrolled Emissions' (Tons/.year) 1.12 Controlled Emissions ?- 1.12 1.94E-02 lb/MMBtu AP -42 1.03 1.03 1.12 1.12 SOX NOx VOC 1.94E-02 Ib/MMBtu AP -42 1.03 1.03 1.12 1.12 5.88E-04 lb/MM Btu AP -42 0.031 0.031 0.034 0.034 11.0 grnp-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 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 Chemical:Name.: • Formaldehyde Acetaldehyde Acrolein Non -Criteria Reportable Pollutant Emissions Inventory; emical bstratt'.. Service (CAS) Number 50000 75070 107028 • 71432 Emission Factor .: ctual Annua[Emissions'..°: Uncontrolled • Basis 2.05E-02 Units lb/MMBtu • So'urce' (AP -42, Mfg. etc) AP -42 Unconti'o4ted Emissions (Pourids�year) 2,166.67 ont1o11ed Erii ssions •• (Pound"/yepr) 520 2.79E-03 2.63E-03 lb/MMBtu lb/MMBtu AP -42 AP -42 280 280 140 ' 140 Benzene 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 cocoRAoo 5 Iv nepunian.dra=uc Hamm u'GmumiraaM Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 060 [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 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 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 n COLORADO 6 I - ' Ha�al�h 6Fi.Nen.„.% 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.cotorado.Qov/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 `JUN 2 7 2018 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: Marla Compressor Station Site Location: SE Sec. 28, T4N, R64W Mailing Address: 370 17th Street Suite 2500 (Include Zip Code) 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 384547 COLORADO 1 I AV ... em n„,,t Name senvuonmom Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 061 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action O NEW permit OR newly -reported emission source (check one below) O STATIONARY source O PORTABLE source O 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) O Change fuel or equipment O Change company name ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership4 O Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ▪ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Ft 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. Roy /cdphe/attainment) Normal Hours of Source Operation: 24 hours/day 7 Seasonal use percentage: Dec -Feb: 25% 0 Yes ❑ No Mar -May: 25% days/week 52 June -Aug: 25% weeks/year Sept -Nov: 25% Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 2 I ° =T.aplar NOiNhb&rvlggcen{ Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 061 [Leave blank unless APCD has already assigned a permit /4` 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 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 BTU/hp-hr hours/year Engine Model: L7044 GSI Serial Number6: C-17976/1 What is the engine Brake Specific Fuel Consumption at 100% Load? 7,860 Engine Features: Cycle Type: ❑ 2 -Stroke 0 4 -Stroke Combustion: ❑ Lean Burn ❑✓ Rich Burn Ignition Source: 0 Spark ❑ Compression Aspiration: ❑ Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes ❑ No If yes, what type of AFRC is in use? 0 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? 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-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 • COLORADO bcpaavvmt a1 Fa. H.Ith E £n,...mon, Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 / 061 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 4,458,467.15 / 538,468.97 pe. a _or � ac I e DIschar a el h Above r ndd Lee m® to '=Ra1 e AGia � Q c t t�se4 r C 176/P 111 40 1,152 9,662 205 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward El Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 12 ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information el Use Rate ® 100% Load 1rF/hour) � Actual Annual Fuel Use 's Requested Annual Permitx) emit' "�� (MMSCF/year 12, 947 96.1 113.4 From what year is the actual annual amount? Indicate the type of fuel used': 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): 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. 2017 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 4 COLORADO Departmental Nf E£AN tl mo Heale 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): v_rall:Requested Control:, reduction in emissions) TSP (PM) PM10 Primary Control Equipment` Description Sax NOx VOC CO Other: NSCR. NSCR NSCR NSCR (HAPs) 82% 33% 75% 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 Pollutant_ TSP (PM) PM10 PM2.5 SOX NOx VOC • CO Emission Factor :.Uncontrolled 1.94E-02 1.94E-02 1.94E-02 5.88E-04 11.0 1.5 8.0 Ib/MMBtu Ib/MMBtu Ib/MMBtu Ib/MMBtu g/hp-hr g/hp-hr g/hp-hr Criteria .Pollutant Emissions lnventory Source:: Mfg: etc) AP -42 AP -42 AP -42 AP -42 Mfg. Mfg. Mfg. Actual Annual. Emissions9' Uncontrolled . Emission's;.: (Tons/, ear) 1.04 1.04 1.04 0.03 166.05 22.64 120.76 ..-Controlled Emissions (Tonsiyear) :. . 1.04 1.04 1.04 0.03 30.14 15.07 30.14 Requested Annual Permit : Emission Limit(s)7 Uncontrolled = Emissions :: (Tonslyedr). 1.12 1.12 1.12 0.03 178.45 24.33 129.78 Controlled. Emissions;; (Tons/year) 1.12 1.12 1.12 0.03 32.45 16.22 32.45 Does the emissions source have any uncontrolled actual emissions of non -criteria Yes ❑ No 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: Formaldehyde Acetaldehyde Acrolein Benzene . Non -Criteria Reportable Pollutant Emissions.lnventory:r. Chemical •Abstract.:, Seri/ice (CAS) Number 50000 75070 107028 71432 Emission Factor. Uncontrolled Basis 2.05E-02 Units .. lb/MMBtu • Source • (AP -42; Mfg. etc) AP -42 ctual Annual Emissions" 1. Uncontrolled Emissions (Pouhdslyeat), .:::... 2,206.59 Controlled Emissions (Pounds/year) 529.58 2.79E-03 lb/MMBtu AP -42 300.31 2.63E-03 lb/MMBtu AP -42 263.09 150.16 ' 141.54 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. Form APCD-201 - Reciprocating internal Combustion Engine APEN - Revision 1/2017 COLORADO A 5 �n4um�fmr�u� Hwith bEn+rtfonmanf Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Permit Number: 95OPWE020 AIRS ID Number: 123 /0243 /061 [Leave blank unless APCD has already assigned a permit #I 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 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-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 Vl COLORADO 6 l a =VI= ' Fia?I h b EnNeofunartf Engine Emission Calculations Marla Compressor Station DCP Operating Company, LP Waukesha L 7042 GS! Engine C -148/P-102 123/0243/052 4 Stroke, Rich Burn Unit Rating: BSFC: Maximum Heat Input Potential Hours of Operation for 2013: Potential FHV: Maximum Potential Fuel Use 2017 Actual Parameters 1,478 hp 7,830 btu/hp-hr 11.57 mmbtu/hr 8,760 hr/yr 1,020Ibtu/sof 99.4 mmscf/yr Month Fuel Use Heat Value (MMsoEmonth) (Btu/scf) January 7.12 1123.53 February 5.09 1149.81 March 7.14 1115.80 April 7.01 1144.68 May 7.39 1111.15 June 6.86 1117.09 July 7.04 1096.48 August 6.53 1140.89 September 6.98 1109.54 October 7.54 1105.72 November 7.00 1114.91 December 7.20 1110.29 2017 82.89 1119.99 eria Pollutant Emission Calculations Uncontrolled Controlled Emission Factors Potential Emissions (ton/yr) Compliance Factors (Ib/MMBtu) Actual Emissions (ton/yr) Emission Factors Potential Emissions (ton/yr) Compliance Factors (Ib/MMBtu) Actual Emissions (ton/yr) Pollutant N0x° 11.0 g/bhp-hr 156.99 3.10 143.63 3.0 g/bhp-hr 42.82 0.84 38.96 12.99 ° 1.5 21.41 0.42 19.59 1.0 g/bhp-hr 14.27 0.28 38.96 VOC ° 8.0 y/hhp-hr g/hhp-hr 114.18 2.25 104.46 3.0 q/bhp-hr 42.82 0.94 0.90 CO 1.94E-02 Ib/mmBtu 0.90 1,94E-02 0.90 1.94E-02 Ib/mmBtu 0.98 1.94E-02 Pm', SOr° 5.08E-041b/mmBtu 0.030 5.88E-04 0.027 5.BBE-04 lb/mmBtu 0.030 5.88E-04 0.027 •. Manufacturer's emissions factors s Uncontrolled emission factors from 4 -stroke, Rich -bum (40891 engines from AP -42, Chapter 3, Table 3.2-3, (7/00). 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 (Ib/yr) Controlled Actual Emissions (Ib/yr) 2.53E-05 lb/mmBtu EPA 2.56 2.35 50% 1.28 1.17 1,1,2,2-Tetrachloroethene <1-53E-05 lb/mmBtu EPA 1.55 1.42. 50% 0.78 0.71 0.52 1,1,2-Trichloroethane <1.13E-05 Ib/mmBtu EPA 0.36 1.05 50% 0.18 1,1 Dichlaroethane <1.13E-05 Ib/mmotu EPA 0.36 1.05 50% 0.18 0.52 1,2 Dichloroethane <1.30E-05 lblmmBlu EPA 0.41 1.21 50% - 0.20 0.60 1,2 Dichlaropropene 6.63E-04 lb/metBtu EPA 67.21 61.49 50% 33.61 30.75 0,59 1,3 -Butadiene <127E-05 lb/mmBtu EPA 1.29 1.18 50% 0.64 1,3-Dichloropropene 2.79E-03 Ib/mmetu • - EPA 28285 258.77 . '-.50% • 141.42 129.39 Acetaldehyde Acrolein 2.63E-031b/mmBtu EPA 266.63 243.93 _ 50% 133.31 121.97 1.58E-03 lb/mmBtu EPA 160,10 146.55 50% 80.09 73.27 Benzene < 1.77E-05 lb/mmBtu EPA 1.79 - 1.64 50% 0.90 0.82 Carbon Tetrachloride benzene <1.29E-05 lb/mmBtu EPA 1.31 1.20 50% 0.65 0.60 Chloro <1.37E-05 lb/mmBtu EPA 1.39 1.27 50% 0.69 0.64 Chloroform <2.48E-051b/mmstu EPA 2.51 2.30 50% 1.26 1.15 ene Ethylene Dibrornide - 16/mmBtu EPA 2.16 1.98 50% 1.08 0.99 Ethylene hmmide 2.05E-0216lmmatu ---�� EPA - - 207828 1801.38 •. • —76% .- • 498.78 456.33 Formaldehyde Methanol - ' 3.06E-03 tblmmBtu - . _ EPA - 31022 "'' "'283,53' "-" •-'55% 155.11 - 141.91 ' Chloride 4.12E-05 lb/mmBtu EPA 4.19 3.82 50% 2.09 1.91 Methylene c9.71E-051b/mmBtu EPA 9.84 9.01 50% 4.92 4.50 Naphthalene 1.41E-041b/mmBtu EPA 14.25 . 13.08 50% 7.15 6.54 0.55 PAH <1,19E-051b/mmetu EPA 1.21 1-10 50% 0.60 Styrene 5.58E-04 lb/mmBtu EPA 56.57 51.75 50% , 28.28 25.88 Toluene <7,18E-06 Ib/mmBlu EPA 0.73 0.67 50% 0,36 0.33 ' Vinyl Chloride 1.95E-041b/mmBtu EPA 19.77 10.09 50% 9.88 9,04 <1011 Xylenes(m, p,o) TOTAL 0.0324537 Ib/mmBtu . — <3280 <3010 <1103 Uncontrolled emission factors from 4 -stroke, Rich -bum (45R9) engines from AP -42, Chapter 3. Table 32-3, (71001. Waukesha L-7042 GSI Engine C -135/P-103 95OPWE020 123/0243/D53 4 Stroke, Rich Burn Unit Rating: BSFC: Maximum Heat Input f}ot?nR�lcT.io"3+1�*fi1�P raGoA$`�;�u' Potential FHV: Maximum Potential Fuel Use, 1,476 7,830 11.57 6,760 1,020 99.4 hp btu/hp-hr mmbtu/hr hr/yr btu/sof mmsct/yr Year Fuel Use Heat Value (MMscf/yr) (Btu/sef) January 7.07 1123.53 February 6.14 1199.81 March 6.38 1115.80 April 5.52 1144.68 May 7.48 1111.15 June 6.93 1117.09 July 6.96 1096.48 August 6.91 1140.89 September 7.06 1109.54 October 7.57 1105.72 November 6.85 1114.91 December 7.28 1110.29 82.13 1120.0 Criteria Pollutant Emission Calculations Engine Emission Calculations Marla Compressor Station DCP Operating Company, LP Pollutant NOxl Emission Factors Potential Emissions (ton/yr) Compliance Factors (ll;(MMBtu) .Y ArXs, Emission Factors Controlled Potential Emissions (tan/yr) Compliance Factors (Ib/MMBtu) 0.1r:' (ton/yr) VOC a 11.0 g/hhp-hr 156.99 3.10 142.33 2.0 g/bhp-hr j 28.54 0.56 (ton/yr) 25.74 CO 1.5 g/bhp-hr 21.41 0.42 19.41 1.0 g/bhp-hr 14.27 0.28 12.97 n 8.0 g/bhp-hr 114.18 2.25 103.51 3.0 g/bhp-hr I 42.82 0.84 38.60 SO2' 1.94E-02 lb/mmetu 0.98 1.94E-02 0.89 1.94E-02 lb/mmBtu 0.98 1.94E-02 S.BBE-041blmmBtu 0.030 5.88E-04 0.027 5.88E-O41b/mmBtu ' OA30 5.68E-04 .89 0.02.02 7 ° Uncontrolled emission factors from 4 -stroke, Rich -burn (4SRB) engines from AP -42, Chapter 3, Table 3.2.3, (7/00). Non -Criteria Reportable Pollutant Calc Pollutant 1,1,2,2-Tetrachloroethane HAP Emission factors° Data Source Uncontrolled Potential Emissions (lb/yr) Uncontrolled Actual Emissions (lb/yr) Control Efficiency % Controlled Potential Emissions (Ib/yr) Controlled Actual Emissions (Ib/yr) 1,1,2-Trichloroethane 2.53E-05 lb/mmBtu EPA 256 233 -50% 1.28 1.16 • <1.53E-05 lb/mmBtu " EPA 1.55 1.41 50% 0.78 0.70 1,1 Dichloroethane 1,2 Dichloroethane <1,13E-05 lb/mmBtu EPA 0.36 1.04 50% 0.18 0.52 1,2Dichloropropane < 1.13E-05 lb/mmBtu EPA 0.36 1.04 50% 0.18 0.52 1,3 <1.30E-05 lb/mmBtu EPA 0.41 1.19 50% 0.20 0.60 -Butadiene 1,3-Dichloropropene 6.63E-04 lb/mroBtu EPA 5721 60.94 50% 33.61 30.47 < 1.27E-05 lb/mmBtu EPA 129 1.17 50% 0.64 0.58 Acetaldehyde . 2.79E-03 1b/mmEttu EPA 282,85 256.43 50% 141.42 ' - 129,22' ' Acroleln 2.63E-031b/mmBtu EPA 266.63 241.73 50% 133.31 120.86 Benzene 1.58E-03 lb/mmBtu EPA 160.18 145.22 50% 8009 72.61 Carbon Tetrachloride <1.77E-05lb/mmBtu EPA 1.79 1.63 50% 0.90 0.81 Chlorobenzene < 1.29E-0516/mmBtu .EPA 1.31 1.19 50% 0.65 0.59 Chloroform < 1.37E-05 lb/mmBtu EPA 1.39 1,26 50% 0.69 0.63 Ethylbenzene <2.48E-05 lb/mmBtu EPA 2.51 2.28 50% 1.26 1.14 Ethylene➢ibromide <2,13E-05 lb/mmBtu EPA 2.16 1.96 50% 1.08 0.98 Formaldehyde 2,05E-02 lb/mmBtu • EPA 2078.28 1884.19 76 • 498.79 452.21 Methanol Methylene 3.06E-03 I6/mmBtu EPA' 31022 281.25 " 50% 155.11 140.62 Chloride Naphthalene 4.12E-05 Ib/mmBtu EPA 4.18 3.79 50% 2.09 1.89 PAH <9.71E-00 lb/mmBtu EPA 9.84 8,92 50% 4.92 4.46 Styrene 1.41E-04 lb/mm8tu EPA 14.29 12.95 50% 7.15 6.48 Toluene < 1.19E-05 Ib/mmBtu EPA 121 1.09 50% 0.60 0.55 Vinyl 5.58E-04 lh/mmBtu EPA 56.57 51.29 50% 28.28 25.64 Chloride Xylenes(m,p,o) <7.18E-06 lb/mmBtu EPA 0.73 0.66 50% 0.36 0.33 TOTAL 1.95E-04 lb/mmBtu EPA 19.77 17.92 50% 9.88 8.96 — <3288 <2983 <1103 <1002 Uncontrolled emission factors from 4 -stroke, Hub -bum (498B) engines from AP -42, Chapter3, Table 3.2-3, (7/00). Engine Emission Calculations Marla Compressor Station DCP Operating Company, LP Waukesha L 7042 GSI Engine C -151/P -1e4 12310243/054 4 Stroke, Rich Bum Unit Rating: BSFC: Maximum Heat Input Operating Schedule: FHV: Maximum Fuel Use: 1,478 hp 7,830 btu/hp-hr 11.6 mmbtu/hr 5,760 hr/yr 1,020Ibtu/scf 99.4 mmsef/yr Year Fuel Use Heat Value (MMscf/yr) 7.19 (Btu/scf) 1123.53 January February 6.17 1149.81 March 7.06 1115.80 April 6.95 1144.68 May 7.49 1111.15 June 6.35 1117.09 July 6.84 1096.48 August 6.70 1140.89 September 6.97 1109.54 ctober October ` 7.57 1105.72 November 6.96 1114.91 December 6.67 111029 82.90 1120.0 Criteria Pollutant Emission Calculations Uncontrolled Emission Factors Pollutant Nos° VOC° CO. PM ° 000' 11.0 1.5 85 1.94E-02 5.86E-04 g/bhp-hr q/bhp-hr 9/bhp-hr Ib/mmBtu Ib/mmBtu Potential Emissions (ton/yr) 156.99 21.41 114.18 Compliance Factors (lb/MMBtu) 3.10 0.42 225 (ton/yr) 143.72 19.60 104.53 Emission Factors 0.99 0.030 1.94E-02 5.88E-04 0.90 0.027 1.0 0.7 20 1.94E-02 5.88E-04 Ib/mmBtu g/bhp-hr q/bhp-hr g/bhp-hr Ib/mmBtu Controlled Potential Emissions (tonlyr) 14.27 9.99 28.54 0.98 0.030 Compliance Factors (Ib/MMBtu) 0.28 0.20 0.56 .ud (ton/yr) 12.99 9.28 25.99 0.90 0.027 1.94E-02 5.88E-04 a Manufacturer's emissions factors ° Uncontrolled emission factors from 4 -stroke, Rich -bum (4866) engines from AP -42, Chapter 3, Table 3.2-3, (7/00). Calculations Controlled Non -Criteria Reportable Pollutant Pollutant HAP Emission factors' Data Source EPA Uncontrolled Potential Emissions 18/ (or) 2.56 Uncontrolled Actual Emissions (Ib/yr) 2 35 Control Efficiency % 50% Potential Emissions (Ib/yr) 1.28 0.78 Controlled Actual . Emissions (110yr) 1.17 1 077 1,1,2,2-Tetrachioroeihane 2.53E-05 lb/mmBtu 01.13E-05 EPA 1.55 1.42 50% 50% 0.18 0.52 1,1 a Ib/mmBtu < 1.13E-05 EPA 0.36 1.05 50% 0.18 0.52 1,1 Dlchloroetllane DIchloro thane lb/mmBtu < 1.13E-05 EPA 0.36 1.05 50% 0.20 0.60 1,2 Dichloroethane lb/mmBtu < 1.30E-04 lb/mmBtu EPA50% 0.41 121 33.61 30.77 1,2Dichloropropane 6.63E-04 lhlmmBtu EPA 6721 61.53 50% 0.64 0.59 1,3 -Butadiene <1.27E -0S ibt% Btu EPA 1 29 1,18 " 50%.'. 141.42 ".- _ 129:47: - -- -- ---.2.7,9E-03_ ..__ 'EPA _ EPA .: 282.85 .. - , 25894 :, �� . 50% . 133,31 122.04 Acetaldehyde - Acetaldehyde lb/mmBtu 2.63E-03 EPA 266.63 244,09 50% 80.09 7232 0.82 Aeraleln Ib/maBtu 1.58E-03 EPA 160.18 146,64 0.90 Benzene lb/mmBtu < 1.77E-05 EPA 1.79 164 50% 50% 0.65 0.60 Carbon Tetrachloride lb/mmBtu <1.37E-05 EPA127 1.31 1.20 50% 0.69 0.64 Chloroform a lb/mmBtu < 1.37E-05 16/mmetu EPA 1.38 50% 126 1.15 0,99 Chloroform <2.48E -OS lb/mmetu EPA 2. 51 2.30 � 1.OB Ethylhenzene � < 2.13E-05 lb/mmBtu EPA 216 1 g6 ' 50% 76% 496.79" - 45652' • mide 205E-03 lblmmetu - EPA' . 207828 1902,58 - 28399 50% 155.11 14250 Formaldehyde Formaldehyde - 3.06E-03 Ib/mm u EPA 31022 50% 2.09 1.91 .0 4.51 Methanol 4.12E-05 Ib/mmBt EPA 4.16 3.82 50% 4.92 Methylene Chloride < 9.71E-04 b/mmstu EPA 9-84 01 13.09 50% 50% 7.15 0.60 6.54 0,55 Naphthalene l9 1.41E-05 b/mmBtu EPA 14.29 PAH <5.50E-054 EPA 1.21 121 1.10 50% 28.28 25.89 Styrene lb/mmBtu 5.58E-04 Ib/mmBtu EPA 5179 50% 0.36 0.33 Toluene <7.15E-06 Ih/mmBtu EPA 0.73 0.67 50% 9.88 9.05 Vinyl Chloride 1.95E-0416/mmBiu EPA 1977 1510 <3012 <1103 <1011 Tenes(m,p,o) TOTAL <3288 ° Uncontrolled emission factors form 4 -stroke, R ch-bum (4560) engines from AP -42, Chapter 3, Table 323, (7100). Engine Emission Calculations Marla Compressor Station DCP Operating Company, LP Waukesha L 7044 GS! Engine C -166/P-109 123/0243/059 4 Stroke, Rich Burn Unit Rating: BSFC: Maximum Heat Input: Operating Schedule: FHV: Maximum Fuel Use: 1,680 hp 7,860 btu/hp-hr 13.2 mmbtu/hr 8,760 hr/yr 1,020Ibtu/scf 113.4Immscf/yr Year Fuel Use Heat Value (MMscf/yr) (Btu/scf) January 1123.53 February 7.20 7.20 1149.81 March - 8.22 1115.80 April 7.81 1144.68 May 8.48 1111.15 June 7.85 1117.09 July 8.09 1096.40 August 7.92 1140.89 September 8.04 1109.54 October 8.64 1105.72 November 7.96 1114.91 December, 8.17 1110.29 ro`-r""" 17 ,„M'VS. 95.69 1120.0 Criteria Pollutant Emission Calculations Uncontrolled Pollutant NOO VOC' CO° PM ° SO," Emission Factors 11.0 1.5 8.0 1.94E-02 5.88E-04 Ib/mmBtu g/bhp-hr g/bhp-hr glbhp-hr Ib/mmBtu Potential Emissions (ton/yr) 178,45 24.33 129.78 1.12 0.034 Manufacturer's emissions factors ° Uncontrolled emission factors from 4 -stroke, Rich -burn (4080) engines from AP -42, Chapter 3, Table 3.2-3, (7/00). Non -Criteria Reportable Pollutant Calcufaeu Compliance Factors (Ib/MMetu) 3.09 0.42 2.24 1.94E-02 5.88E-04 (tonlyr) 166.99 22.77 121.45 1.05 0.032 Emission Factors 2.0 1.0 2.0 1.94E-02 5.88E-04 g/bhp-hr /bhp -hr g/bhp-hr Ib/mmBtu Ib/mmBtu Controlled Potential Emissions (ton/yr) 32,45 16.22 32.45 1.12 0,034 Pollutant 1,1,2,2-Tehachloroethane HAP Emission factors ° ❑ata Source Uncontrolled Potential Emissions 16/ r ( y ) Uncontrolled Actual Emissions (Ib/yr) Control EC cienc Y % Controlled Potential Emissions ,Controlled Actual Emissions 1,1,2-Trichlomethane 2.53E-05 lb/mmBtu Epq 2.83 2'74 50% (Ib/yr) (Ibyr) m 1,1 Dichloethane <1.53E-0516/mmBtu EPA 1.77 1.66 50% 1.46 137 1,2 Dichioroethane <1.13E-05 Ib/mmBtu EPA 0.36 1.22 50% 0.88 0.83 1,2 Dichlo one < 1.13E-05 b/mmBtu EPA 0.36 1.22 50% 0.18 0.61 1,3 -Butadiene ene < 1.30E-05 Ib/mmBtu EPA 0.41 161 50% 0.18 D.61 1,3-Dichlompropene 6.63E-04 Ib/mostu EPA 76.69 71.77 50% 0.20 0.70 Acetaldehyde < 1.27E-05 Ib/mmBtu EPA 1.47 1.37 50% 38:35 3558 .. 2.79E-03 13/mmetu EPA 322.74 302.01 : 50% 0.73 101.37 0.69 Benzene Benzene 2.63E-03 lb/mmBtu EPA 304.23 284,69 50% 151.11 151.00 Carbon Tetrachloride 1.58E-031b/rnmBt, EPA 18277 171.03 50% 91.38 142.34 Chloroform ne <1.77E-051h/mmBtu EPA 2.05 1.92 50% 1.02 85.51 Chloroform <1,37E-05 Ib/mmBN EPA 1 49 1,40 0.75 0.96 Ethylene <1.37E-05 Ib/mmBtu 15850% 1.48 50% 0.79 0.70 Ethylene Dior <2.48E-05 Ib/mmBtu EPA 287 i 2,65 50% 0.74 hyromide Formaldehyde mmB <2.13E.02 EPA 246 2.31 50% 1.43 1.34 Methanol ] 2.05E-0213/mmBtu t EPA1.23 2371,35 2219,06 70% 555.12 1.15 3.06E-03 lb/mmltu EPA 353.97 331.24 50% . 176.9k 53237 Naphthalene Naphthalene 4.12E-05 lb/mmBtu EPA 4.46 50% 165.32 PAH <9,71E-0513/mmBtu EPA 11.23 10.51 50% 2.38 2.23 Styrene 1.41E-0416/mmBtu EPA 16,31 15.26 50% 566 5.26 Toluene <1.19E-0513/mmBtu EPA 1..4 50% 6.16 7,® Vinyl 5.56E-04 Ib/mrBtu 64.55 6070 50% 0.64 TOTnes(m,P,o) es(mChlor,p, <'7.18E-06 Ib/mmBtu EPA 0.63 0.76 50% 3.27 2.2 TOTAL 1.95E-0416/mm6tu EPA 2256 21.11 50% 1128. 1.2 0.39 0..5 — <3751 <3513 <1259 1118 <1105 , R ch-bum (4SRB) engines from AP -42, Chapter 3, Table 3.2-3, (7/00). Compliance Factors (Ib/MMBtu) 0.56 0.28 0.56 1.94E-02 5.88E-04 (ton/yr) 30.31 15.15 30.31 1.05 0.032 Engine Emission Calculations Marla Compressor Station DCP Operating Company, LP Waukesha L 7044 GSI Engine C -1741P-110 123102431060 4 Stroke, Rich Burn Unit Rating: B5FC: Maximum Heat Input Operating Schedule: FHV: Maximum Fuel Usc 1,680 hp 7,860 btu/hp-hr 13.2 mmbtu/hr 8,760 hr/yr 1,020Ibtu/scf 113.4 mmscf/yr Year Fuel Use Heat Value (MMscf/yr) (Btu/scf) January 8.19 1123.53 February 7.15 1149.81 March 8.30 1115.8 April 8.06 1144.68 May 8.51 1111.15 June 7.71 1117.09 July 7.45 1096.48 August 7.61 1140.89 September 8.09 1109.54 October 8.08 1105.72 November 7.73 1114.91 December 7.97 1110,29 ; ,f -S1'2 -,:re -.7,4.17- 94.85 1120.0 Criteria Pollutant Emission Calculations Uncontrolled Emission Factors Pollutant NOx VOC° CO° PM° 505° 11.0 1,5 • 8,0 1.94E-02 5.88E-04 g/bhp-hr g/bhp-hr 9/bhp.hr lb/mmBtu lb/mmBtu Potential Emissions (ton/yr) 178.45 24.33 129,78 1.12 0.034 Compliance Factors (Ib/MMBtu) 3.09 0.42 2.24 1.94E-02 5.88E-04 (tonlyr) 163.84 22.34 119.16 1.03 0.031 Emission Factors 2.0 1.0 2.0 1.94E-02 5.88E-04 Ib/mmfitu glbhp-hr g/bhp-hr g/bhp-hr Ib/mmetu Controlled Potential Emissions (tan/yr) 32.45 16.22 32.45 1.12 0.034 Campiiance Factors (Ib/MMBtu) 0.56 0.28 0.56 194E-02 5.88E-04 7" (ton/yr) 29,74 14.87 29.74 1.03 0.031 ° Manufacturer's emissions factors Uncontrolled emission factors from 4 -stroke, Rich -bum (4669) engines from AP -42. Chapler3, Table 3.2-3, (7/00). Pollutant Calculations Controlled Nan -Criteria Reportable Pollutant HAP Emission factors' Data Source EPA Uncontrolled Potential Emissions (Ib/yr) 293 Uncontrolled Actual Emissions (Ib/yr) 269 Control Efficiency % 50% Potential Emissions (Iblyr) 1.46 Controlled Actual Emissions lb/yr) 1.34 1,1,2-Trichmchlihune 2.53E-051b/mmBfu <1.13E-05 EPA 1.37 162 50% 088 0.18 5,81 0.60 1,1, lb/mmBtu <1.13E-0516/mmBfu EPA 0.36 1.20 55% 0,18 0,60 Dichia ethane 1,1 Dichloroethane <1.30E-05 Ib/mmfitu EPA 0.36 1.20 50% 0.20 O.fi9 1,2 Dichloroethene <1.30E-05 Ib/mmfitu EPA 0.41 1.36 50% 38.35 35.21 1,2Dicodlana pane 6.63E-051b/mmfitu EPA 76.69 7042 50% 0.73 0.67 1,3 -Butadiene <1_27E-05 1b/mmBfu EPA 1.47 1.47 1.35 50% 148.16 rydmpene 2,796.53 lh/mmBfu - EPA 322.74 296.32 50% 761,37 .. 139.66 Acetaldehyde Anralni ehYde304.23 . 2.63E-03 Iblmm EPA'-- .' 279.33 .., . 50% 152.11 , 83.90 ABenzene /u 1.58E-031hImmBtu EPA 182.77 167.81 50% 91.36 0,94 Benzene 1b/mmfitu EPA 2 05 1,88 50% 1 02 0,69 CarbonTetrachloride<1.77E-05 <1.29E-051blmmBtu EPA 1.49 1.37 50% 0.75 0.73 Chlorobenzene c 1.37E-05 lb/mmBtu EPA 1.58 1.46 50% 0.79 1,32 Chloroform c2.48E-051b/mmfitu EPA 287 2.63 50% 1.43 1,13 Ethylene <2.13E-05 lb/mmBtu EPA 226 50% 1.23 -' 522.54 Ethylene Dibr 2.95E-03 ib/mmfitu • -- 'EPA'.. . - 2371.35 - . , 217.725 ' - 76% 569.12 162.50 hyde Formaldehyde 3.06E-03 lb/mmBtu '- EPA � 35397 324.99 • • - 50% 17698 2.38 2.19 Methanol 4.12E-05 lb/mmBfu EPA 477 4.38 55% 5,62 5.16 Methylene Chloride < 9.71E-041b/mmfitu EPA 1121 14.31 60% 7.49 Naphthalene 1.41E-04 16/mmBfu EPA 16.31 14.96 50% 0.69 0,63 PAH8.16 <1.19E-05 lb/mmBtu EPA 1.38 1.26 50% 3227 29.63 Styrene 5.56E-041b/mmfitu EPA 64.55 5826 50% 0.42 0.38 ToWene <7.18E-06 lb/mmBfu EPA 0.83 0.76 50% 1.28 10,36 Vinyl 155E-041b/mmfitu EPA<3447 22.55 20.71 • 50% <1259 `1157 TOTnes(m,p,o) Xylenes(m,p, — c 3751 TOTAL ' ° Uncontrolled emission factors from 4 -stroke, R ch-bum (45RB) engines from AP -42, Chapter 3, Table 32.3, (7100 . Engine Emission Calculations Marla Compressor Station DCP Operating Company, LP Waukesha L 7044 GS! Engine C -176/P-111 123/0243/061 4 Stroke, Rich Bum Unit Rating: BSFC: Maximum Heat Input Operating Schedule: FHV: Maximum Fuel Use 1;680 hp 7.860 btu/hp-hr 13.2 rnmbtu/hr 8,760 hr/yr 1.0201 btu/scf 113.4 mmscf/yr Year Fuel Use Heat Value (MMscf/yr) (8tu/scf) January 6.19 1123.53 February 7.17 1149.81 March 8.27 1115.80 April 7.99 1144,68 May 8.41 1111.15 June 7.77 1117.09 July 7.93 1096.48 August 7.87 1140.89 September 7.93 1109.54 ' October 8.60 1105,72 November 7.91 1114.91 December 8,10 1110.29 96.1 1120.0 Criteria Pollutant Emission Calculations Pollutant NOx' VOC' Co° PM' 00, ' Manufacturer's emissions factors ' Uncontrolled emission factors from 4 -stroke, Rich -bum (4SRB) engines from AP -42, Chapter 3, Table 3.2-3, (7/00). Uncontrolled Controlled Emission Factors Potential Emissions (ton/yr) Compliance Factors (Ib/MMB10) .. (ton/yr) Emission Factors Potential Emissions /yr) Compliance Factors 3014"", 11.0 g/bhp-hr 178.45 3.09 166.05 2.0 g/bhp-hr (to 32.45 (fb/MMBtu) (ton/ y 1.5 /bh - g p hr 24.33 0.42 22.64 1.0,g/bhp-hr 0.56 15.07 8.0 g/bhp-hr 129.78 2.24 120.76 2.0 g/bhp-hr 16.22 ' 32.45 0.28 15.07 1.94E-02 lb/mmBtu 1,12 1.94E-02 1.04 1.94E-02 lb/mmBtu 1.12 0.56 30.14 5.BBE-04 lb/mmBtu 0.034 5.88E-04 0.032 5.88E-04 lb/mmBtu 0.034 1.94E-02 5.88E-04 1.04 -_ - 0.032 Non -Criteria Reportable Po Pollutant 1,1,2,2-Tetrachlorbethane HAP Emission factors' Data Source Uncontrolled Potential Emissions (lb/yr Uncontrolled Actual ' Emissions O.72 Control Efficient y % Controlled Potential Emissions (1.46 Controlled Actual Emissfons 1,1, ho a 2.53E-0516/mmBtu EPA 2.93 2.72 2'72 50% (1.36 Dichl 1,1 Dichloroethane ethane <1.53E -0S lb/mmBtu _ - EPA 1.77 1.65 50% 1.46 1.36 1,2 Dichloroethane <1.13E-05 Ib/mmBtu EPA 0.36 1.22 50% 0.68 - 0.82 ro rie P Pe < 1.13E-05 Ib/mmBtu EPA 0.36 1.40 50% 0.18 0.18 0.61 11,3-0 tadie 1,3 -Butadiene <1.30E-0516/mmetu EPA _ 0,41 1.40 50% 0.61 1,3-Dildehydropene 6.63E-0416/mmBtu EPA 76,69 71.36 50% 0.20 0,7p <1.27E-053 lb/mmBto EPA 1.47 1.37 50% 38.35 35.68 Acr'eAcetaldehyde de - ` 2;78E-03 Iblmmetu ` ' ' - EPA' -' . ' 322.74 - 300,31 = 50% ' 0.73 ' - 161;37 ' 0.68 ' Benzene Carbone , 2.63E-03 lblmmBtu -,., EPA ' 304:23 203:09 ' ' -50% ' : 152:11 ' 150:18 ' Carbon Tetrachloride < 1.58E-036 llb/mmBtu EPA 182.77 170.07 50% . 91.38 141:54 .. Chiorofor <1.77E-0516/mmBtu EPA 2.05 1.91 50% - 1.02 85.03 zone Chloroform <1.37E-0516/mmBtu EPA 1.49 1.39 50% ` 0.75 0.95 Ethylene <1.37E-05 Ib/mmBtu EPA 1.56 1.47 . 50% 0.73 0.69 Ethylene DIbr <248E -OS lb/mmBtu EPA 2.87 2.67 50% 1.43 0.74 Formaldehyde hyde <2.13E-05 Ib/mmBtu '- EPA 2.46 2.29 50% 1.23 1.33 Methanol - "' 2.05E-02-Ib/mmBtu_ EPA - 2371.35 2206.59 76% - 586,12 -' 1.15 Methylene Chloride - " " ' — 16/mm u - EPA. - 953.97 - 329.37 - 50%- 176.98 529.58 • Naphthalene 4.1125-03 t 4,718-05 lb/mmBtu EPA 4.77 4.43 50% - 164.69 PAH <g,71 E-04 EPA 11.23 10.45 50% 2.38 222 Toluene tb/mmBtu 1.41E-04 lb/mmBtu EPA 16.31 15.16 50% 5,62 5.23 Toluene < 1.18E-04 lb/mmBtu EPA 1.38 1.28 50% 8,16 7.59 Vinyl Chloride 5.58E-0416/mmBtu EPA 64.55 60.06 50% 0.69 0.69 0.64 TOTnes(m,p,o; <7.18E-06 Ib/mmBtu 50% 3.39 TOTAL 1.95E-04 lb/mmBtu EPA 22.55 0.9.83 2348 50% 0.42 11.26 0..9 <3751 <3493 <1259 10.49 <1173 e ec-bum (4SRB) engines from AP -42, Chapter 3, Table 3.2-3, (7/00) 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 AIRS ID Equipment Dmcripaon 123/0243/052 123/0243/051 123/0243/054 123/0243/059 123/0243/060 123/0243/061 123/0243/062 123/0243/063 Engine C -148/P-102 Engine C -135/P-101 Engine C-I51/P-104 Engine C -166/P-109 Engine C -174/P-110 Engine C -176/P -III P-112 TE0 Dehy P-113 TEO Dehy Permilled Sources Sublolnl APEN Only - Permit Exempt Sources controlled Polmtinl to Emil (PTE Controlled Polenllol to Emit RITE) Criterin (TPV I HAP, (Ibr/yr) Criteria (TPY) I HAP, I bs/yr) TSP P6810 P012.5 S02 too VOC CO 1 MHO Aootll Acro LIZ Tel En Xyl n-Hee Meth 124-T01P TSP P5,118 P242.5 S03 NOx ROC CO I HCNO Arelol Acre BZ Tot EB Xyl n -Hex Meth 224-TMP 1.0 10 1.0 00 157.0 21.4 1142 I 2,078 28] 267 160 57 3 20 0 310 0 1.0 . 1.0 1.0 0.0 428 143 428 I 499 141 133 80 28. I 10 0 155 0 1.0 10 10 0.0 157.0 21.4 114.2 I 2,078 283 267 160 57 3 20 0 310 0 10 1.0 1.0 00 28.5 143 428 I 499 141 133 80 28 1 10 0 155 0 1.0 10 10 DO 1570 21.4 1142 I 2078 283 267 160 57 3 20 0 310 0 10 10 10 0.0 14.3 100 285 I 499 141, 133 80, 28 I 10 0 155 0 1.1 1.I 1 00 1784 243 1298 I 2,371 323 304 183 65 3 23 0 354 0 LI 1.I 1.1 0.0 324 162 I. 324 I 569 161 152 91 32 I 11 0 177 0 1.1 1.1 1.1 00 175.4 24.3 1298 2371 323 304 183 65 3 23 0 354 0 1.1 LI 1.1 0.0 32.4 162 32.4 569 161 152 91 32 I II 0 177 0 1.1 1.1 I.1 00 178.4 24.3 129.8 2,371 325 304 183 65 3 23 0 354 0 LI LI 1.1 0.0 32.4 102 32.4 I 569 161 152 91 32 I II 0 177 0 0.0 0.0 00 0.0 0.13 455.51 0.61 I 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 8.49 0.61 I 0 0 0 2,907 4,107 187 2482 304 0 0 0.0 0.0 00 0.0 0.19 30024 087 l 0 0 0 56,441 86,867 3893 63,2)1 10,379 0 0 0.0 00 00 00 0.19 1225 0.87 s 0 0 0 4,029 5.819 274 3.650 409 0 0 6,3 6.3 6.3 0.2 1006.6 853,0 733.3 I 13,149 1,817 1,713 101,511 154,701 7,528 112,131 15,815 1,993 0 6.3 63 6.3 0.2 183.3 108.0 213.0 I 3,204 908 656 1,450 10,108 470 6,196 713 996 0 I APEN Only Subtotal - APEN Exempt/ lnsignl6cnnl 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 Insignificant Acilives (See Lis/) 0,0 00 0.0 00 0.7 11.4 06 I 0 0 0 75 0 0 0 431 0 0.0 00 oa 00 0.7 11_4 0.6 I 0 0 75 0 431 0 0 Inslgnl0ennl Subtotal - 0.0 0.0 0.0 0.0 0.7 11.4 0.6 I 0 0 75 431 0 0 0.0 0.0 0.0 0.0 0.7 11.4 0.6 I 0 0 0 75 0 431 0 Total, All Sources.. 6.3 6.3 6.3 0.2 1007.3 904.4 733.9 I 13,345 1,817 1,713 101,585 154,701 7,528 112,231 I 26,246 1,993 0 6,3 6,3 6.3 0.2 184.0 1194 213.6 I 3,204 908 856 7,535 10,108 478 6,196 1,144 996 0 Uncontrolled OAPs Summary (TPY)- 6.7 I 0.9 I 0.9 I 50.6 I 77.4 I 3.8 I 56.1 I 13.1 I 1.0 I 0.0 , Uncontrolled Tool, All HAP, (TPV) e I 2156 I Controlled HAPN Summary (TPY) 1.6 I 0.5 I 0.4 I 3,8 I 5.1 _I 0.2 I 3.1 I 0.6 I 0.5 I 0.0 Controlled Total, All HAP, (TPY)-I 15.7 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: BZ= Benzene 224-TMP = 2,2,4-Trimethylpentane Tol = Toluene Acetal = Acetaldehyde EB = Ethylbenzene Acro = Aerobic Xyl = Xylene n -lies = n -Hexane lICHO = Formaldehyde Melts = Methanol 4. APEN Exempt/Insignificant Sources should be included when warranted. Attachment F Proposed Updates to Operating Permit 95OPWE020 Marla Compressor Station SECTION I - General Activities and Summary 6. Summary of Emission Units 6.1 The emissions units regulated by this permit are the following: AIRS Point Number Facility Identifier Description Pollution Control Device 053 C-135 (P-103) Waukesha Model L-7042 GSI Natural Gas Fired Internal Combustion Reciprocating Engine, 4 -cycle, Rich Burn, Serial No. 317310 C-10605/1, Non -Selective Catalytic Reduction & Air/Fuel ratio controller Standard 1478 HP; powering a natural gas compressor 054 C-151 (P-104) Waukesha Model L-7042 GSI Natural Gas Fired Internal Combustion Reciprocating Engine, 4 -cycle, Burn, Serial No. C 12813/1230355, Non -Selective Catalytic Reduction & Air/Fuel ratio controller Standard Rich 1478 HP; powering a•natural gas compressor 060 C-174 (P-110) Waukesha Model L-7044 GSI Natural Gas Fired Internal Combustion Reciprocating Engine, 4 -cycle, Burn, Serial No. C 13818/15283700815, Non -Selective Catalytic Reduction & Air/Fuel ratio controller Standard Rich 1680 HP; powering a natural gas compressor SECTION II - Specific Permit Terms 1. Three Waukesha L-7042 GSI, 1478 hp engines (C-148, C-135, C-151) with NSCR; Three Waukesha L-7044 GSI, 1680 hp engines (C-166, C-174, C-176) with NSCR Note: These limitations apply to each engine individually. Parameter, .. :. : Permit: - Condition Number : Limitations ::. . " :: Compliance. Emission Facfor . Monitoring Method Interval.... NOX 1.1 C-148: 42.82 ton/yr 0.84 Ib/MMBtu Record keeping and calculation 12 month rolling Monthly C-135: 28.54 ton/yr 0.56 lb/MMBtu C-151: 14.27 ton/yr 0.28 lb/MM Btu C-166, C-174, C-176: 32.45 ton/yr 0.56 lb/MMBtu CO C-148, C-135: 42.82 ton/yr 0.84 lb/MMBtu C-151: 28.54 ton/yr 0.56 lb/MM Btu C-166, C-174, C-176: 32.45 ton/yr 0.56 Ib/MMBtu VOC C-148, C-135: 14.27 ton/yr 0.28 lb/MMBtu C-151: 9.99 ton/yr 0.20 Ib/MMBtu C-166, C-174, C-176: 16.22 ton/yr 0.28 Ib/MMBtu HAP Emissions Facility wide: Individual HAP: 8.0 tons/yr Total HAPs: 20.0 ton/yr Natural Gas Consumption 1.2 C-148, C-135, C-151:84 99.4 M1vlscf/yr C-166, C-174, C-176: 96.1.113.4 MMscf/yr _ Opacity 1.3 Not to Exceed 20% Except as Provided for Below Fuel Restriction Only Natural Gas is Used as Fuel For Startup — Not to Exceed 30%, for a Period or Periods Aggregating More than Six (6) Min in any 60 Consecutive Min Portable Monitoring . 1.4 Flue Gas Analyzer Quarterly Hours of Operation 1.5 Recordkeeping Monthly Btu Content of Natural Gas 1.6 , ASTM or other Division Approved . Method Semi - Annually CAM 1.7 See Condition 1.7 Emissions Control 1.8 Non -selective catalyst reduction and an air fuel controller required. See Condition 1.8 NESHAP Subpart ZZZZ 1.9 Limit Formaldehyde concentrations to 2.7 ppmvd @ 15% O2 or Reduce Formaldehyde by 76% . ... _. . i See Condition 1.9 NESHAP Subpart A 1.10 : See Condition 1.10 MINOR MODIFICATION ADDENDUM REC'D VIA EMAIL 6/29/2618 STATE OF COLORADO Schuchardt - CDPHE, Elie <elie.schuchardt@state.co.us> Marla Responses Shankaran, Roshini <RShankaran@dcpmidstream.com> To: "Schuchardt - CDPHE, Elie" <elie.schuchardt@state.co.us> Elie, Fri, Jun 29, 2018 at 2:25 PM This serves as an addendum/correction to the application filed on June 26, 2018 for the Marla Compressor Station. Please replace the following items from the submittal per the corrections: • C-174 corrections o Incorrect emission factors were used in the supporting calculations, but the APEN is accurate. o Updated Attachment D from original submittal with calculation sheet for C-174. o Updated Attachment E from original submittal with revised Form 102. o Updated Attachment F from original submittal with revised red -lined Title V conditions. • APEN Red -Lines o Upon further review, DCP discovered the following items that need to be corrected on the APENs: • On Section 6 of the APENs, Engines C-174 and C-166 (AIRS 060 and AIRS 059) incorrectly list the fuel as Field Natural Gas, with a heating value of 1,000 Btu/scf. Please update this to Pipeline Natural Gas to match the other 4 compressor engines. Sorry about the error. If you would like for me to resubmit the whole package, let me know. Thanks, Roshini Roshini Shankaran Environmental Engineer — Weld County DCP Midstream 370 17th Street, Suite 2500 Denver, CO 80202 Office: 303-605-2039 Cell: 720-391-7005 https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1604639991014882549&simpl=msg-f%3A16046399910... 1/3 Attachment D Emission Calculations and Supporting Documentation C-148, C-135, C-151, C-166, C-174, C-176 Marla Compressor Station Engine Emission Calculations Marla Compressor Station DCP Operating Company, LP Waukesha L 7044 GSI Engine C -174/P-110 123/0243/060 4 Stroke, Rich Burn Unit Rating: BSFC: Maximum Heat Input: Operating Schedule: FHV: Maximum Fuel USE 1,680 hp 7,860 btu/hp-hr 13.2 mmbiu/hr 8,760 hr/yr 1,020 btu/scf 113.4Immscf/yr Year Fuel Use Heat Value (MMscf/yr) (Btu/scf) January 8.19 1123.53 February 7.15 1149.81 March 8.30 1115.8 April 8.06 1144.68 May 6.51 1111.15 June 7.71 1117.09 July 7.45 1096.48 August 7.61 1140.89 September 8.09 1109.54 October 8.08 1105.72 November 7.73 1114.91 December 7.97 1110.29 94.85 1120.0 Criteria Pollutant Emission Calculations Uneontrnlled Controlled Pollutant Emission Factors Potential Emissions (ton/yr) Compliance Factors (ib/MMBtu) - - --- •-,-^ — - - Emission Factors Potential Emissions (ton/yr) Compliance Factors (Ib/MMBtu) (ton/yr) (ton/yr) NO/ 11.0 g/bhp-hr 178.45 3.09 163.84 1.0 g/bhp-hr 16.22 0.56 29.74 VOC ' 1.5 g/bhp-hr 24.33 0.42 22.34 0.7 g/bhp-hr 11.36 0.28 14.87 CO ' 8.0 g/bhp-hr 129.78 2.24 119.16 2.0 g/bhp-hr 32.45 0.56 29.74 PM ° 1.94E-02 IblmmBtu 1.12 1.94E-02 1.03 1.94E-02 Ib/mmBtu 1.12 1.94E-02 1.03 00z° 5.88E-04 lblmnlBtu 0.034 5.88E-04 0.031 5.88E-04 lb/mmBtu 0.034 5.88E-04 0.031 Manufacturers emissions factors ° Uncontrolled emission factors from 4 -stroke, Rich -bum (4SRB) engines from AP -42, Chapter 3, Table 3.2-3,17/001, rrvr� •.r rtc„a rcNvi.ou.c • v .............................. Pollutant HAP Emission factors' Data Source Uncontrolled Potential Emissions (Ib/yr) Uncontrolled Actual Emissions (Ib/yr) Control Efficiency % Controlled , Potential Emissions (Ib/yr) Controlled Actual Emissions (lb/yr) 1,1,2,2-Tetrachloroethane 2.53E-05 Ib/mmBtu EPA 2.93 2.69 • 50% 1.46 1.34 1,1,2-Trichluroethane < 1.53E-05 lb/mmBtu EPA 1.77 1.62 50% 0.88 0.81 1,1 Dichloroethane < 1.13E-05 Ib/mmBtu EPA 0.36 1.20 50% 0.18 0.60 1,2 Dichloroethane < 1.13E-05 IblmmBtu EPA 0.36 1.20 50% 0.18 0.60 1,2 Dichloropmpane <1.30E-05 lb/mmBlu EPA 0.41 1.38 50% 0.20 0.69 1,3 -Butadiene 6.63E-041b/mmBtu EPA 76.69 70.42 50% 38.35 35.21 1,3-Dichloropropene < 1.27E-05 lblmmBtu EPA 1.47 1.35 50% 0.73 0.67 Acetaldehyde 2.79E-03 Ib/mmBtu EPA 322.74 296.32 50% 161.37 148.16 Acrelein 2.63E-03 lb/mmBtu EPA 304.23 279.33 50% 152.11 139.66 Benzene 1.58E-03 lb/mmBtu EPA 182.77 167.81 50% 91.38 83.90 Carbon Tetrachloride <1.77E-05 lblmmatu EPA 2.05 1.88 50% 1.02 0.94 Chlorobenzene <1.29E-051b/mmBtu EPA 1.49 1.37 50% 0.75 0.69 Chloroform <1.37E-05 lb/mmBtu EPA 1.58 1.46 50% 0.79 0.73 Ethylbenzene c248E-05 lb/mrnBtu EPA 2.87 2.63 50% 1.43 1.32 Ethylene Dibromide <2.13E-05 ib/mmBtu EPA 2.46 2.26 50% 1.23 1.13 Formaldehyde 2.05E-02 lb/mmBtu EPA 2371.35 2177.25 76% 569.12 522.54 Methanol 3.06E-03 Ib/mmBtu EPA 353.97 324.99 50% 176.98 162.50 Methylene Chloride 4.12E-05 Ib1mmBtu EPA 4.77 4.38 50% 2.38 2.19 . Naphthalene <9.71E-05 lb/mmBtu EPA 11.23 10.31 50% 5.62 5.16 PAH 1.41E-04 lb/mmBtu EPA 16.31 14.98 50% 8.16 7.49 Styrene < 1.19E-05 lb/mmBtu EPA 1.38 1.26 - 50% 0.69 0.63 Toluene 5.58E-04 lb/mmBtu EPA 64.55 59.26 50% 32.27 29,63 Vinyl Chloride <7.18E-06 lb/mmBtu EPA 0.83 0.76 50% 0.42 0.38 Xylenes(m,p,c) 1.95E-04 lb/mmBtu EPA 22.56 20.71 50% 11.28 10.36 TOTAL — < 3751 < 3447 < 1259 < 1157 ° Uncontrolled emission factors from 4 -stroke, Rich -bum (4008) engines from AP -42, Chapter 3, Table 3.2-3, (77001. 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 123/0243/052 123/0243/053 123/0243/054 123/0243/059 123/0243/060 123/0243/061 123/0243/062 123/0243/063 E ul•ment Dew i•Hon Engine C -140/P-102 Engine C -135/P-103 Engine C -151/P-104 Engine C -166/P -I09 Engine C -174/P -I 10 Engine C -176/P-111 P-112 TEG Dehy P-113 TEG Deb Permitted Sources Subtotal = Colorado Department of Public Health and Environment Air Pollution Control Division Facility Wide Emissions Inventory Form Ver. April, 2015 Uncontrolled Potendnl to Emit (PTE) Controlled Potential to Emit (PTE) Criteria (TPY) I HAPs (Ibr/yr) Criteria (TPY) HAPs (lbs/yr) : s Acela • cro : I 'y- so: ex r e I' TSP PMIO -EMS SO2 NO: WC CO I HCH0 Acetar Acre BZ Tot ES X510-Her -1911th 124-TMP TSP PMfu PM2.5 SO2 NOx VOC CO • 10 155 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 14.3 42.8 499 141 133 80 28 10 155 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 L0 0.0 28.5 14.3 42.8 499 141 133 80 28 28. 10 155 1.0 1.0 1.0 00 157.0 21.4 1142 I 2,078 283 267 160 57 3 20 0 310 0 1.0 1.0 1.0 0.0 14.3 10.0 28.5 499 141 133 80 32 11 177 1.1 1.1 1.1 0.0 178.4 243 129.8 , 2,371 323 304 183 65 3 23 0 354 0 1.1 1.1 1.1 0.0 32.4 16.2 32.4 569 161 152 152 91 91 32 11 177 1.1 1.1 1.1 0.0 178.4 243 129.8 2,371 323 304 183 65 3 23 0 354 0 1.1 1.1 1.1 0.0 16.2 11.4 32.4 569 161 152 91 32 I1 177 1.1 (,) 1.1 0.0 178.4 243 I 129.8 2,371 323 304 183 65 3 23 0 354 0 1.1 1.1 1.1 0.0 32.4 16.2 32.4 569 161 0 0 2,907 4,107 1 7 2,482 304 0 0.0 0.0 0.0 0.0 011 455.51 0.81 1 0 0 0 44,041 §7,470 3,619 48,894 15,436 0 0 0.0 0.0 0.0 0.0 0.13 8.49 0.61 0 0 4,029 5,819 2 4 3,650 409 0 0.0 0.0 0.0 0.19 300.24 0.87 0 0 0 56,441 86,867 3,893 63,211 10,379 0 0 0.0 0.0 0.0 0.0 p,14 12.25 0.87 0 0 0.0 63 6.3 6.3 0.2 1006.6 893.0 1 733.3 I 13,349 1,817 1,713 101,511 154,701 7,528 112,231 25,815 1,993 0 63 63 6.3 0,2 167.1 103.1 213.0 3,204 908 856 7,450 10,108 470 6,190 713 996 0 1PEN Only - Perms Exempt Sources f I I I 1 I I I I 1 I I I \PEN Exempt/ Insignificant APENOn1y Subtotal= 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 0.0 i 0 0 0 0 0 0 0 0 0 0 0 0 439 0 0 List) 0.0 0.0 0.0 0.0 0.7 11.4 0.6 I 0 0 0 75 0 0 0 431 0 0 0.0 0.0 0.0 0.0 0.7 11.4 0.6 I 0 0 0 75 0 Insignificant Aci6ves (See I I 1 J 1 I I I 1 I r 0.6 I 0 0 0 75 0 0 0 431 0 0 Insignificant Subtalal= 0.6 I 0 0 0 75 0 0 0 431 0 D 0.0 0.0 0.0 0.0 0.7 11.4 0.0 0.0 0.0 0.0 0.7 11.4 Total, AO Sources- 63 63 1 6.3 0.2 1007.3 904.4 733.9 I 13.349 1,817 1,713 101,585 154,701 7,528 112,231 26,246 1,993 0 6.3 6.3 6.3 0.2 167.7 114.5 213,6 3,204 900 856 7,525 10,108 470 6,196 1,144 996 0 Uncontrolled HAPs Summary (TPY)_ I 6.7 I 0.9 I 0.9 I 50.8 I 77.4 I 3.8 I 56.1 I 13.1 I 1.0 I 0.0 I Uncontrolled Total, All HAPs (TPY) = I 210.6 I 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 source is new then enter "proposed" under the Pem11t No. and AIRS ID data columns 3. HAP abbreviations include: BZ = Benzene 224-TMP = 2,2,4-Trimethylpeatane Tot = Toluene Acetal = Acetaldehyde EB = Ethylbenzene Acro = Acrolein Xy1= Xylene n -flex = n -Hexane HCHO = Formaldehyde Meth = Methanol 4. APEN Exempt/Insignificant Sources should be included when warranted. Controlled fAPs Summary (TPY) —I 1.6 I 0.5 I 0.4 I 3.8 I 5.1 I 0.2 I 3.1 I 0.6 I 0.5 I 0.0 Controlled Total, All HAPS (TPY) = I 15.7 I Attachment F Proposed Updates to Operating Permit 95OPWE020 Marla Compressor Station SECTION II - Specific Permit Terms 1. Three Waukesha L-7042 GSI, 1478 hp engines (C-148, C-135, C-151) with NSCR; Three Waukesha L-7044 GSI, 1680 hp engines (C-166, C-174, C-176) with NSCR Note: These limitations apply to each engine individually. ParamQte Permit Co rc(rtion Number s 4rri!tamilts »'+.—;+.= :,� ''.,'<. ,..,.,..., v'i'a'- �` Com Ilan e Ewa s— .h.. - ,.e.-... .....Y- ,.�W s_._ �Mo n grin Metha' _..._" .1 '?�' ;'�,.,.r�`a'�,, ' In - - NOx x 1.1 C-148: 42.82 ton/yr 0.84 lb/MMBtu Record keeping and calculation 12 month rolling Monthly C-135: 28.54 ton/yr 0.56 Ib/MMBtu C-151: 14.27 ton/yr 0.28 lb/MMBtu C-174: 16.22 ton/yr 0.28 lb/MMBtu C-166, C 17'l, C-176: 32.45 ton/yr 0.56 lb/MMBtu CO C-148, C-135: 42.82 ton/yr 0.84 lb/MMBtu C-151: 28.54 ton/yr 0.56 Ib/MMBtu C-166, C-174, C-176: 32.45 ton/yr 0.56 Ib/MMBtu VOC C-148, C-135: 14.27 ton/yr 0.28 lb/MMBtu C-151: 9.99 ton/yr 0.20 lb/MMBtu C-174: 11.36 ton/yr 0.20 lb/MMBtu C-166, C 17'l, C-176: 16.22 ton/yr 0.28 lb/MMBtu HAP Emissions Facility wide: Individual HAP: 8.0 tons/yr Total HAPs: 20.0 ton/yr Natural Gas Consumption 1.2 C-148, C-135, C-151: 84.5 99.4 MMscf/yr C-166, C-174, C-176: 9-6-4113.4 MMscf/yr = Opacity 1.3 Not to Exceed 20% Except as Provided for Below Fuel Restriction Only Natural Gas is Used as Fuel _ _ For Startup — Not to Exceed 30%, for a Period or Periods Aggregating More than Six (6) Min in any 60 Consecutive Min Portable Monitoring 1.4 Flue Gas Analyzer Quarterly Hours of Operation 1.5 Recordkeeping Monthly Btu Content of Natural Gas 1.6 ASTM or other Division Approved Method Semi - Annually CAM 1.7 See Condition 1.7 Emissions Control 1.8 Non -selective catalyst reduction and an air fuel controller required. See Condition 1.8 NESHAP Subpart ZZZZ 1.9 Limit Formaldehyde concentrations to 2.7 ppmvd @ 15% 02 or Reduce Formaldehyde by 76% See Condition 1.9 NESHAP Subpart A 1.10 , _ _ - See Condition 1.10 Air Pollution Control Division Colorado Operating Permit Compliance Assurance Monitoring Plan - Engines Appendix Page APPENDIX G Compliance Assurance Monitoring Plan - Engines Background a. Emission Unit Description: C-148, C-135, and C-151: Three Waukesha Model L-7042 GSI Internal Combustion Engines, 1478 HP each C-166, C-174, and C-176: Three Waukesha Model L-7044 GSI Internal Combustion Engines, 1680 HP each b. Applicable Regulation, Emission Limit, Monitoring Requirements: Regulation: Operating Permit Section II, Condition 1.1, Colorado Regulation No. 7, Section XVII.E.2.b (until compliance with Section II, Condition 1.9) Emission Limitations: C-148: NOx 42.82 tons/yr CO 42.82 tons/yr C-135: NOx 28.54 tons/yr 2.0 g/hp-hr CO 42.82 tons/yr 3.0 g/hp-hr C-151: NOx 14.27 tons/yr 1.0 g/hp-hr CO 28.54 tons/yr 2.0 g/hp-hr C-174: NOx 16.22 tons/yr 1.0 g/hp-hr CO 32.45 tons/yr 2.0 g/hp-hr C-166, C 17/1, C-176 (each): NOx 32.45 tons/yr CO 32.45 tons/yr c. Control Technology: Non -Selective Catalytic Reduction Air Pollution Control Division Colorado Operating Permit Compliance Assurance Monitoring Plan - Engines Appendix Page II. Monitoring Approach Indicator No. 1 Indicator No. 2 I. Indicator Measurement Approach Temperature of exhaust gas into catalyst Pressure drop across the catalyst Thermocouple Measured in inches of water II. Indicator Range The indicator range is a temperature between 750° F and 1250° F. Excursions above 1250° F trigger engine shutdown. Excursions below 750° F trigger notification of excursion. Excursions trigger the permittee to investigate the engine performance and make any repairs or adjustments necessary. Any adjustments or repairs shall be recorded in a log, to be made available to the Division upon request. The indicator range is a pressure drop across the catalyst that is within three inches of water from the pressure drop across the catalyst measured during the initial performance test (or within three inches of the manufacturer's specified range if the pressure drop was not determined during an initial performance test). Excursions trigger the permittee to investigate the catalyst performance and make any repairs or adjustments necessary. Any adjustments or repairs shall be recorded in a log, to be made available to the Division upon request. III. Performance Criteria a. Data Representativeness Temperature is measured at the inlet to the catalyst. The minimum accuracy is +/- 5 ° F. Pressure drop is measured across the catalyst while the engine is operating. b. Verification of Operational Status Thermocouple manufacturer guarantee. Manometer manufacturer guarantee. c. QA/QC Practices/Criteria Calibration annually. Per manufacturer's recommendation. d. Monitoring Frequency Daily. Monthly f. Data Collection Procedures Temperature data will be automatically or manually recorded on days that the engine is operating. Pressure drop will be recorded once per month. e. Averaging Time None None. dcp Midstream 370 17th Street, Suite 25U0 Denver, CO 80202 303-605-1745 October 10, 2017 Sent via UPS Tracking No: 1Z F46 915 02 9545 1048 Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, CO 80246-1530 ATTN: Elie Schuchardt Re: DCP Operating Company, LP; Marla Compressor Station Title V Minor Modification Application (AIRS 123/0243) P-112 Natural Gas Dehydrator (AIRS 062) P-113 Natural Gas Dehydrator (AIRS 063) Dear 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 renewal application for this facility was submitted December 28, 2016. This renewal application is currently pending review with the state. Summary of Changes P-112 (AIRS 062) Triethylene Glycol Dehydration Unit with condenser and flare; P-113 (AIRS 063) Triethylene Glycol Dehydration Unit with condenser and flare; • Add annual downtime of 3.0% for the individual condensers and shared enclosed combustor (ECD) used for still vent emissions control for both TEG Dehy units. Emissions from the combined still vents will vent to atmosphere during periods of ECD downtime. • Increase the natural gas processing limit for unit P-113 from 45 MMscfd to 55 MMscfd. • Change the listed glycol recirculation pump for P-113 from gas injection to electric. • Update various GLYCalc properties including a more recent extended gas analysis for each unit. • Adjust the maximum still vent outlet condenser temperature from 140 °F to 160 °F in the applicable TV Permit conditions, as well as the included Compliance Assurance Monitoring (CAM) Plan for units P-112 and P-113. o Update TV Operating Permit Condition 3.1.1 to match the CAM plan for units P- 112 and P-113. Condition 3.1.1 currently requires the highest daily condenser outlet temperature be used for the monthly compliance nce defines the GLYCalc emicondenserss ion runs e conducted for each unit. However, the CAM plan temperature as the daily average of a minimum of four r these readings. unitsis DCP believes the daily averages required by the CAM Plan representative of actual operation, and ests condition 3.1.1 be updated to match. Please see Attachment G for proposed changes. • Increase controlled VOC emission limit for P-112 from 2.82 tpy to 8.49 tpy as a result of the above changes. ■ Increase controlled VOC emission limit for P-113 from 2.82 tpy to 12.25 tpy as a result of the above changes. • Remove the 40 CFR 63 Subpart HH exemption criteria from the TV Operating Permit table of limitations for P-112 and P-113. Please see the section below on Federal and State Regulatory Applicability for details. • Minor adjustments to the list of insignificant activities at this facility, and their associated emissions. Please fmd updated emissions calculations, an updated Extended Gas Analysis (EGA), and updated GLYCaic runs for both P-112 and P-113 in Attachment D of s this unPp lica application. Additionally, please fmd updated Operating and Maintenance (O&M) Plfor P-113 in Attachment F of this application. The existing O&M pia hass been e. Finally,revised to please find the above requested changes to the control of emissions from updated list of insignificant activities and their associated emissions included in Attachment D. Federal and State Regulatory Applicability Units P-112 and P-113 at this facility are subject to the Area HH applicability Sourceprovisions based on the proposed of MACT Subpart HH. Although there are no changes in Subpart minor modifications in this application, DCP would like to include ALL applicable area source provisions from Subpart HH in this TV Permit, rather than just the otential benzene emissions of benzene axceed al gas throughput exemption criteria under 63.764(e)(1)(il). therefore actual emissions of 0.90 megagram/yr after these proposed minor modifications,dehys benzene need to be evaluated for P-112 or P-113 to assess dated p both 17anguag eegarding the exemption criteria on an annual basis. DCP has provided p the additional Subpart HH area source provisions in sAttmilar DCP facility. Please refer to achment G of this application. These were selected to match a current Title V permit fo operating permit 95OPWE103 for the Enterprise Compressor Station, for details. Units P-112 and P-113 are subject to the emission dkee cin nand report grequirements, requirementsunder vice operation requirements, and the monitoring, recor p g Colorado Regulation 7, Section XII.H. DCP will continue to meet all applicable requirements under this section. Units P-112 and P-113 are also subject to the state -specific Specifically, �ssion he emission reduction uction and control requirements under Colorado Regulation 7, Section requirements under Reg 7, Section XVII.D require at least ent D of this application show that DCP of hydrocarbons. The attached calculations in Attachm will continue to meet this requirement for both P-112 and P-113, even with the proposed addition of downtime for the condensers and enclosed combustor. This Title V Operating Permit Minor Modification application includes the following attachments: A. Responsible Official Acknowledgement B. APEN Fees C. Updated APENs (P-112, P-113) D. Emission Calculations and Supporting Documentation E Form APCD-102 F. Updated O&M Plan (P-112, P-113) G. Redlined Title V Operating Permit l9o5Oor g (C� Plan H. Redlined Compliance Assurance 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(cr�DCPMidstream.com. Sincerely, DCP Operating Company, LP Roshini Shankaran Environmental Engineer Enclosures Attachment A Responsible Official Acknowledgement 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 q /0L-.2011 Signature of Re ponsible Official Date Attachment B APEN Filing Fees — 2 APENs ($305.80) Marla Compressor Station Attachment C Updated APENs (P-112, P-113) Marla Compressor Station 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 General unit does not (Form APCD-200) is fall into this category, there may be a more specific APEN for your source. In addition, 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 _ [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] AIRS ID Number: 123 / 0243 / 062 Section 1 - Administrative Information Company Name!: DCP Operating Company, LP Site Name: Marla Compressor Station Site Location: SE Sec 28, T4N, R64W Mailing Address: 370 17th Street, Suite 2500 (Include Zip Code) Denver, CO 80202 E -Mail Address' RShankaran@DCPMidstream.com Site Location County: Weld NAICS or SIC Code: 4922 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 1Please 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. 370082 Form APCD-202 - Glycol Dehydration Unit APEN - Revision 02/2017 COLORADO 1 I AV Nw1en b cimmnmanf Permit Number: 95OPWE020 [Leave blank unless APCD has already assigned a permit # and AIRS ID] I G%) • Jr'L.- AIRS IL) Number. Section 2- Requested Action [] NEW permit OR newly -reported emission source -OR - ❑✓ MODIFICATION to existing permit (*check each box below that applies) O Change fuel or equipment ❑ Change company name O Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership3 0 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: P-112 11 / / 2005 For new or reconstructed sources, the projected / start-up date is: 0 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: days/week 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 Yes Yes weeks/year No No COLORADO 2 I E n•a„d.,�•aaax HOMe EnNmemN Permit Number: 95OPWE020 [Leave blank unless APCD has already assigned a permit # and AIRS ID] AIKJ IV rvunlucI. ILv Section 4 - Dehydration Unit Equipment Information Model Number: Manufacturer: Dehydrator Serial Reboiler Rating: 0.85 MMBTU/hr Number: DiEthylene Glycol ❑ TriEthylene Glycol Ethylene Glycol ❑ (TEG) Glycol Used: ❑ (EG) (DEG) Glycol Pump Drive: O Electric El Gas If Gas, injection pump ratio: 0.08 Acfm/gpm # of pumps: I__ Pump Make and Model: Kimray 45015 Max: 6.25 Requested: 6.25 TEG Dehydration Unit Glycol Recirculation rate (gal/min): Lean Glycol Water Content: 1.0 Wt.% Design Capacity: 45 MMSCF/day 16,425 1,647.5 MMSCF/year Dehydrator Gas Throughput: Requested: MMSCF/year Actual: Inlet Gas: Pressure: 1,000 psig Temperature: 106 °F Saturated Dry gas: 7,0 lb/MMSCF Water Content: Wet Gas: lb/MMSCF ❑ NA Temperature: 100 ° F O Flash Tank: Pressure: 45 psig Temperature: °F 0 NA Cold Separator: Pressure: psig _— Stripping Gas: (check one) ✓❑ None O Flash Gas O Dry Gas O Nitrogen Flow Rate: scfm 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 Et n -Hexane, temperature, and pressure) Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 COLOIADO lar=ondvaw� 3 I A+ � xanne EnVuonmonl Permit Number: 95OPWE020 [Leave blank unless APCD has already assigned a permit '# and AIRS ID] I GO / vG`ty' vvL AIRS ID Number: Section 5 - Stack Information Geographical Coordinates (LatitudelLongitude or UTM) 40.2767, -104.5475 S-112 Indicate the direction of the stack outlet: (check one) ❑✓ Upward O Horizontal ❑ Downward Other (describe): Indicate the stack opening and size: (check one) ✓❑ Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): ❑ Other (describe): eoct O Upward with obstructing raincap Interior stack depth (inches): Form APCD-202 -. -Glycol Dehydration Unit APEN - Revision 02/2017 4 I COLORADO bCWrtelemtrIlubLi Permit Number: 95OPWE020 AIRS ID Number: 123 /02431 UbZ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information Used for control of: Still Vent Stream ❑✓ Condenser: * Type: Maximum Temp Requested Control Efficiency Make/Model: Average Temp 160.0 ❑✓ 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 O No Pilot burner Rating 0.05 MMBtu/hr Closed O Loop System: Used for control of: Description: System Downtime O Other: Used for control of: Description: Control Efficiency Requested 1 0 * Condenser and ECD combustion device used for still vent control have a 3.0% annual downtime for maintenance and repairs. Stilt vent emissions will vent to atmosphere durinD periods of Condenser and ECD downtime. Form APCD-202 -Glycol. Dehydration Unit APEN - Revision 02/2017 }/ -COLORADO 5 i A It 1n eanw� RMIglBEnVll+onIDlnl Permit Number: 95OPWE020 [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? ❑✓ Yes ❑ No the overall control efficiency (% reduction): Requested Control If yes, please describe the control equ�prnent AND state Efficiency (% reduction in emissions) Pollutant:` Vapor Recovery Unit / Condenser / Enclosed Combustor Vapor Recovery Unit / Condenser / Enclosed Combustor From what year is the following reported actual annual emissions data? 2016 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Emission Actual�Annual EmissiOf. Factor ��: _.. k � Source (AP -42., -''Mfg.-etc) ctual controlled emissions reported. If source has not yet started operating, leave blank. 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on a Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 OL4RhB0 h Deportmcud 1,1X13‘t 1X13c 6 Far f.t,am.ora Permit Number: 95OPWE020 — [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. ►:rte Signature of Legally Authorized Person (not a vendor or consultant) Roshini Shankaran Name (please print) to o/tot Date Environmental Engineer 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) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-51 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Title For more information or assistance call: Small Business 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 4 =7.'utA1bUc 7 I ' HW�BEnuinanr4M Glycol Dehydration Unit APEN -aForm APCD-202 Air Pollutant Emission Notice (AP ) Application for Construction Permit EN uAllp sections of thisAPENand amisssin tion information mayust be pbeted determined r both in ompleteew and iandgmayibereturned orgresult in longer An application wissi g 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 is General unit APEN (Form APCD-2OO) is does not fall into this category, there may be a more specific APEN for your source. In addition, available if the specialty on Control Division (APCD) website atrtviwwecoloradeds. A losov/cdphelapcd t of all available APEN forms can be found on the Air Poll 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 eeortabe change is made )t See Regulation No. 3, (significant e, increase Part A,.C elrinsions for revisedsAPEN requirements�on, fuel t new equipment, change intype, etc Permit Number: 95OPWE020 [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: SE Sec 28, T4N, R64W Mailing Address: 370 17th Street, Suite 2500 (Include Zip Code) Denver, CO 80202 E -Mail Address2: RShankaran@DCPMidstream.com AIRS ID Number: 123 / 0243 / 063 Site Location County: Weld NAICS or SIC Code: 4922 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 1Please 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. 37008 3 Form APCD-202 - Glycol Dehydration Unit APEN - Revision 02/2017 COLORADO Naaleh 6Envuanmmi Permit Number: 95OPWE020 [Leave blank unless APCD has already assigned a permit # and AIRS ID] , L V • ..... . - - AIM Iu wunIuai . Section 2- Requested Action ❑ NEW permit OR newly -reported emission source -OR- Q MODIFICATION to existing permit (check each box below that applies) ❑ Change company name ❑ Add point to existing permit Change fuel or equipment O ✓❑ Change permit limit ❑ Transfer of ownership3 O 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: 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: P-113 11 / / 2005 For new or reconstructed sources, the projected / / start-up date is: 0 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours /day days /week weeks /year Will this equipment be operated in any NAAQS nonattainment Yes O No area Is this unit located at a stationary source that is considered a O Yes 0 No Major Source of (HAP) Emissions Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 :COLORADO 2 I ATz=7,7��,4�c ijnU1W BflWtronm�nt Permit Number: 95OPWE020 [Leave blank unless APCD has already assigned a permit # and AIRS ID] ILV ' vr- .... ARO IV r unwaI . Section 4 - Dehydration Unit Equipment Information Model Number: Manufacturer: Dehydrator Serial Number: TriEth lene Glycol Ethylene Glycol DiEthylene Glycol ❑ Y Glycol Used: ❑ (EG) ❑ (DEG) (TEG) Gas If Gas, injection pump ratio: Glycol Pump Drive: 0 Electric O Pump Make and Model: Kerr Triplex PD TEG Dehydration Unit Reboiler Rating: 0.75 Glycol. Recirculation rate (gal/min): Lean Glycol Water Content: Max: 8.2 1.0 Wt.% MMBTU/hr Requested: 8.2 # of pumps: Acfm/gpm 1 Dehydrator Gas Throughput: Design Capacity: 55 MMSCF/day 20,075 14,459.8 Requested: MMSCF/year Actual: MMSCF/year Inlet Gas: Pressure: 1,000 Water Content: Wet Gas: Flash Tank: Pressure: 55 Cold Separator: Pressure: Stripping Gas: (check one) ✓❑ None Flow Rate: 0 Flash Gas psig Temperature: lb/MMSCF El Saturated psig Temperature: psig Temperature: 0 Dry Gas 0 Nitrogen scfm Additional Required Information: 106 Dry gas: 160 °F 7.0 lb/MMSCF of 0 NA =F ✓❑ NA ❑✓ Attach a Process Flow Diagram 0 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 3I Mrstrmmafftlilic COLORADO Permit Number: 95OPWE020 [Leave blank unless APCD has already assigned a permit # and AIRS ID] AIRS IL) Plumper: r��-�- Section 5 - Stack Information Geographical Coordinates, (Latitude/Longitude or UTM) 40.2767, -104.5475 S-113 Indicate the direction of the stack outlet: (check one) 0 Upward 0 Horizontal ❑ Downward 0 Other (describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): ❑ Other (describe): 0 Upward with obstructing raincap Interior stack depth (inches): Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 Avg, ;COLORADO 4 I M� M rag R«.iw a F„w�a„m.w 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 Used for control of: Still Vent Stream p Condenser: * Type: Maximum Temp Requested Control Efficiency Make/Model: Average Temp 160.0 ❑✓ 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 h r 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 O 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 * Condenser and ECD combustion device used for still vent control have a 3.0% annual downtime for maintenance and repairs. Still vent emissions will vent to atmosphere during periods of Condenser and ECD downtime. Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 p COLORADO 5 1 d31V a mituna HMnh 6 ETV1Y0t�mrn) Permit Number: 95OPWE020 AIRS ID Number: 143 / UG'+'J vv..; [Leave blank unless APCD has already assigned a permit # and AIRS ID] PM PM 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? ❑✓ Yes O No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Overall;Requested Control Efficiency (% reduction in emissions). Control Equipment Description SO, NO„ CO VOC HAPs Other: Vapor Recovery Unit / Condenser / Enclosed Combustor Vapor Recovery Unit / Condenser / Enclosed Combustor 95% 95% From what year is the following reported actual annual emissions data? 2016 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Emission Factor Source (AP -42, Mfg. etc) Uncontrolled Emission actor; Emission Factor_ Uncontrolled !(Tons/year) " Uncontrolled (Tons/year) Controlled5 (Toes/year) Controlled (Tons%year) SO, NO), CO 0.068 Ib/MMBtu AP -42 0.19 0.19 VOC 0.31 29.9 Ib/MMBtu lb/MMscf AP -42 GLYCalc 105.41 1.44 0.87 300.24 0.87 12.25 Benzene Toluene 2.8 4.3 Ib/MMscf lb/MMscf GLYCalc GLYCaIc 9.19 7.10 0.20 0.07 28.22 43.43 2.01 2.91 Ethylbenzene Xylenes 0.2 lb/MMscf GLYCalc 0.30 0.001 2.34 0.14 3.1 lb/MMscf GLYCaIc 2.76 0.01 31.61 • 1.83 n -Hexane 0.5 Ib/MMscf GLYCalc 1.56 0.02 5.19 0.20 2,2,4- Trimethytpentane 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 6 I AVCOLORADO Ir===. 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. rr /,o/2nd Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name (please print) Title Check the appropriate box to request a copy of the: ✓❑ Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 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-202 -Glycol Dehydration Unit APEN - Revision 02/2017 7 I AV . Des1011) tIPULtic COLORADO Attachment D Emission Calculations and Supporting Documentation Marla Compressor Station Natural Gas Dehydration Marla Compressor Station DCP Operating Company, LP N Y/N Source ID Description Manufacturer Model Serial C Operation 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 Flesh Tank Pressure Flash Tank Control VRU Downtime P112 Dehydration Unit Custom TEG Dehydration Unit Custom Custom 6760 hr/yr 106 deg F 1000 psig Saturated IbH2O/MMscf 45 MMscfd 7.0 IbH2O/MMscf 1.0 wN/ H2O 6.25 gpm N Y/N N/A deg F N/A psig Kimmy45015 Gas Elec. or Gas 0.08 acfm/gpm Y Y/N 100 deg F 45 psig 100.00% Recycled to Inlet 0.00% Routed to Atm 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 & Condenser Downtime Total Emissions from GRI-GLYCaIc 4.0 N/A stem Y' Y/N 160 deg F 12 psia Y. Y/N 60 deg F 0% 95.00% % 3.00% Uncontrolled CAS Pollutant Number VOC e -hexane 110-54-3 Benzene 71-43-2 Toluene 108-88-3 Ethylbenzene 100-41-4 Xylene 1330-20-7 Total HAP Notes: The uncontrolled values inc ude bath lash and overheaa s (Ib/nr) 86.7 1.47 4.19 6.42 0.34 4.65 17.08 759178 12863 36701 56225 3016 40745 149618 Uncontrolled Emission 16425 mmscf/yr 1368.8 mmnCf/mo Controlled Emissions 379.59 6.43 16.35 28.11 1,51 20.37 74.81 +20% (tpy) 455.51 7.72 22.02 33.74 1.81 24,45 8977 (Ib/hr) 1.6 0.03 0.28 0.39 0.02 0.24 0.95 (lb/yr) 14156 253 2423 3422 156 2068 8322 (my) 7.08 0.13 1.21 1.71 0.08 1.03 4.16 •The still vent stream is routed through a condenser, then to an enclosed combustor (ECD). CAS Uncontrolled Emissions Flash Emissions' Still Vent Emissions' Total Dehy Emissions' Emission Factors (tpy) (tpy) (tpy) (Ibyr) +20%(thy) (Ib/MMsef) Pollutant Number 266.86 112.73 379.59 455.5 7.7 555 0.9 VOC 110-5 4-3 4.74 1.70 6.43 12863 27 n -Hexane 71 3-2 1.A1 16.94 16.35 36701 22.0 33.7 4.1 Benzene 108-9 8-3 1.34 26.77 28.11 56225 18 0.2 Toluene 100'41'4 0.35 1.47 7 51 3016 24.4 3.0 Ethylbenzene 1330-20-7 0.36 20.01 20.37 40745 10.9 Xylene 7.91 66.90 74.81 89.8 Total HAP 1. Flash emissions and still vent emissions (uncontrolled potenfial to emit) obtain 2 Total dehy emissions calculated as a sum of Flash and Still Vent emissions. Still Vent Emissions Total Still Vent CAS Number Still Vent Emissions' Uncontrolled Controlled lb/hr Still Vent Condenser / ECD Uptime Emissions' Still Vent Condenser / ECD Downtime Emissions' Emissions' (lY) GOY) (tpY) Pollutant 25.74 0.97 3.696 3.382 - 7.08 V000.051 110-54-3 0.39 0.02 0,076 0.13 n -Hexane 3.87 0.2117 0.703 0.508 1.21 Toluene 00-88-71-43-2 108 -BB -3 6.ti 0.21 0.908 0.803 1.71 0.08 EToluene 100-41-4001 0.34 0.034 0.044 0.600 1.03 XylYlb¢n2en¢ Total 1330-20-7 457 0.10 0.434 ' 2.007 4.16 Total HAP 1527 0.51 2.154 b 2017 3. Still Vent lb/hr controlled and uncontrolled emission rates obtained from GLYCeIc report dated Octoer . 4. Emissions during standard condenser and ECD operation Calculation includes 3% downtime of both condenser and ECD, for periods of malfunction and maintenance. 5. Emissions during combined condenser/ ECD downtime, for maintenance and malfunctions. Annual downtime of 3% (combined condenser and ECD) used. 6. Total still vent emissions are a sum of still vent condenser/ECD uptime and condenser/ECD downtime emissions. Total Controlled Emissions (PTE) Pollutant CAS Number Dehy Emissions' Dehy Emissions +20% Butter 1° Overall System Control'r Coy) ltpy) VOC 7.18 8.49 98.1% during control device downtime n -Hexane 110-54-3 0.13 0.15 Benzene 71-43-2 1.21 1.45 Toluene 108-88-3 1.71 2.05 Ethytbenzene 100-41-4 0.08 0.09 XYlane 1330-20-7 1.03 1.24 Total HAP 4.16 4.99 biped with emissions 9. Total controlled dehydrator emissions calculated as a sum of controlled sill von emissons, con 10. DCP is adding a 20% buffer to controlled emissions for variabtiity in gas analysis and other actual parameters. 11. Demonstrating an overall system control of 95%, calculated as [100%. Total Controlled Dehy VOC Emissions / Total Uncontrolled Dehy Emissions] +20% (tpy) 8.49 0.15 1.45 2.05 0.09 1.24 4.99 Condenser Vent Stream Detail from GRI-GLVCaIc 4.0 Condenser Vent Stream 202.00 scf/hr 8760 hr/yr 1.770 MMschyr Description Vent Flow Rate Hours of operation Annual Flow Rate Pure Component Mol Weight (Ib/Ib-mop Natural Gas Dehydration Marla Compressor Station DCP Operating Company, LP N Y/N Source ID P113 Description Dehydration Unit Manufacturer Custom Model TEG Dehydration Unit Serial # Custom Operation Date Custom 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 Kerr Triplex PD Glycol Pump Type Glycol Pump Gas Flow Rate Flash Tank? Flash Tank Temperature Flash Tank Pressure Flash Tank Control VRU Downtime 8760 hr/yr 106 deg F 1000 psig Saturated IbH2O/MMscf 55 MMscfd 7.0 IbH2O/MMsct 1.0 wt% H2O 8.2 gpm N YIN N/A deg F NIA psig Pollutant VOC nn -hexane Benzene Toluene Ethylbenzene Xylene 21.08 Total HAP 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, then to an enclosed combustor (ECD). Electric Elec. or Gas N/A acfndgpm Y Y/N 160 degF 55 psig 100.00% Recycled to Inlet 0.00% Routed to Atm CAS Number 110-54-3 71-43-2 108-88-3 100-41-4 1330-20-7 (lb/hr) 57.1 0.99 5.37 1.26 0.44 6.01 (Ib/yr) 500408 8649 47034 72389 3893 52676 184678 Stripping Gas? What is Skipping Gas? Shipping Gas Flow Rate Condenser?' Condenser Temperature Condenser Pressure Combustor? Combustor Ambient Air Temp Combustor Excess Oxygen Combustor Destruction Efficiency Combustor & Condenser Downtime Total Emissions from GRI-GLYCalc 4.0 Uncontrolled Emission (toy) 250.20 4.32 23.52 36.19 1.95- 28.34 92.34 pollutant VOC n -Hexane Benzene Toluene Ethylbenzene Xylene 1. Flash erosions and still vent emissions (uncontrolled potential to emit) obtained from GIyCio report dated October 2017. Total HAP 2. Total dehy emissions calculated as a sum of Flash and Still Vent emissions. CAS Number 110-54-3 71-43-2 108-88-3 100-41-4 1330-20-7 Flash Emissions' (tpv) 98.82 2.08 0.67 0.95 0.03 0.31 4.25 Still Vent Emissions' WY) 151.39 2.24 22.65 35.25 1.91 26.03 64.09 5011 Vent Emisslo Pollutant VOC n -Hexane Benzene Toluene Ethylbenzne Xylene Total HAP 3. Still Vent litter controlled and uncontrolled emission rates obtained from GLYCalc report dated October 2017. 4 Emissions during standard codenser and ECD operation Colcukotion co includes ECD downtime, for mainten nceland malfunctions Annualowntime maintenance. of 3% (combined condenser and ECD) used, 6. Emissions during combined fi. Total still vent emissions is a sum of still vent condenser/ECD up9me and condenser/ECD downtime emissions. Total C[ 11 tl E Is i na PTE1 CAS Number 110-54-3 71-83-2 108-88-3 100-41-4 1330-20-7 Still Vent Emissions' Uncontrolled Controlled Ibmr 34.56 0.51 5.17 8.05 0.44 5.94 2011 1.33 0.02 0.24 0.32 0.01 0,17 0.77 +20% (My) 300.24 5.19 28.22 43.43 2.34 31.61 110.81 Uncontrolled Emissions Total Dehy Emissions' (tpY) 250.20 4.32 2352 36.19 1.95 26 34 92.34 Still Vent Condenser/ ECD Uptime Emissions' (Ipy) 5.671 0.103 0.999 1.367 0.057 0.740 3.267 (Ibyr) 8649 47034 72389 3893 52676 Still Vent Condenser / ECD Downtime Emissions' Pollutant Voc n -Hexane Benzene CAS Number 110-54-3 71-43-2 Dehy Emissions' Wy) 10.21 0.17 1.68 2.42 0.11 1.52 Dehy Emissions +20% Butter t° (tpY) 12.21 0.20 2.01 2.91 0.14 1.83 Overall System Control" 95.9% Toluene 108-88-3 Ethylbenzene 100-414 Xylene 1330-20-7 5.91 7.09 Total HAP 9. Total controlled dehydrator emissions calculated as a sum of controlled still vent emissions, combined with emissions during control device downtime 10. DCP is adding a 20% buffer to controlled emissions for variability in gas analysis and other antral parameters. 11. Demonstrating an overall system control of 95%, calculated as [100% -Total Controlled Dehy VOC Emissions /Total Uncontrolled Dehy Emissions) (tpy) 4.542 0.067 0.679 1.057 0.057 0.781 2.643 (Ibmr) 2,3 0.04 0.38 0.55 0.03 0,35 1.35 +20% (tpy) 300.2 5.2 28.2 43.4 2.3 31.6 110.8 Total Still Vent Emissions° (tpy) 10.21 0.17 1.68 2.42 0.11 1.52 5.91 N/A scfm Y' Y/N 160 deg 12 Asia Y' YIN 60 deg F 0% 95.00% % 3.00% Uncontrolled 20075 mmscf/yr 1672.9 mm50f/m0 602.25 Controlled Eni tons (Ib/yr) 20424 341 3357 4849 229 3042 11820 Emission Factors (IbIMMscf) 29,9 0.5 2.8 4.3 0.2 3.1 11.0 IVY) 10_21 0.17 1.68 2.42 0.11 1.52 5.91 +20% spy) 12.25 021 2.01 2.91 0.14 1.63 7.09 Condenser Vent Strewn Detail from GRI-GLVCatc 4.0 Condenser Vent Stream 326.00 scf/hr Description Vent Flow Rate Hours of operation Annual Flow Rate Component Ethane Vol% 876 2.856 MMscf/yr Mel Fraction 0.000141 0.0145 00521 0.0112 0.0178 0.0060 0.0117 0O074 0O096 0.0098 0.0000 0.0700 0.0812 00029 0.0381 0.0013 0.9996 0.0166 Component Fraction Heat Value (Btufscf) Pure Component Mol Weight (lb/lb-mop 100.20 318.50 Component Mass Fraction 0.0855 0.0000 0.0001 0.0107 0.0321 0.0569 0.0159 00152 0.0242 0.0079 0.0107 0.0120 0.0181 0.0181 0.0000 d.1032 0.1412 0.0059 0.0028 Pure Component Heat Value (Blu/scif) 1010.0 4000.9 4008.9 3763.9 5502.5 5208.8 P-112 and P-113 TEG Dehy Calculations Uncontrolled Emissions Uncontrolled Emissions are taken directly from GLYCaIc. Emission Factor lb = Uncontrolled Emissions tons * 2,000 lb * * 1 year MMscf year ton Dehy Throughput MMscf 365 days Still Vent Emissions Condenser/ ECD Uptime Emissions tons = Controlled Regen Emissions I* Condenser/ ECD Uptime hrs * ton lb year hr 2000 Condenser / ECD Downtime Emissions tons = Uncontrolled Regen Emissions lb yr 2,000 * Condenser / ECD Downtime hrs * ton lb year Combined Condenser/ ECD annual downtime of 3% * 8,760 hrs/yr = 262.8 hrs/yr used for calculations. Combined Condenser/ECD annual upime of 97% * 8,760 hrs/yr= 8,497.2 hrs/yr used for calculations. Still Vent emissions are vented to atmosphere during 3.0% annual Condenser/ ECD downtime. Total Regen Emissions = Condenser/ECD uptime emissions + Condenser/ECD downtime emissions Total Dehy Emissions Total Dehy Emissions = Total Regen Emissions Overall Control Efficiency = 1- Total Dehv VOC Emissions Total Uncontrolled VOC Emissions Determined for both P-112 and P-113 individually Enclosed Combustor Emissions Marla Compressor Station DCP Operating Company, LP Enclosed Combustor 50 scf/hr Pilot Gas: 100 scf/hr Assist Gas: 150 scf/hr Total Natural Gas Usa e: 1 0D0 BTU/SCF Fuel Heatin Value: 8 760 hr/yr Hours per Year 1.31 MMSCF/ Fuel Use 1.77 MMSCFr Overheads Flow Rate (P-112 2.86 MMSCF/yr Overheads Flow Rate (P-113): Pilot + Assist Gas usage split equally between P-112 and P-113 657 MMBTU/ r assist as 3,257 MMBTU/ r from P-112 condenser vent 3,914 Total MMBTU/yr P-112 657 MMBTU/ r assist as 4,950 MMBTU/ r from P-112 condenser vent 5,607 Total MMBTU/yr P-113 Criteria Pollutant Emission Calculations Pollutant NOx CO 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 EGO; 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 Condenser I -II -IV Btu ) scf yr yr Emission Factors (ib!_ mmbtu) 0.068 0.31 Emissions (P112) (ton/yr) 0.13 0.61 Emissions (P113) (ton/yr) 0.19 0.87 Condenser Vent Rates and HHVs determined from individual GLYCaIc Runs, dated October 2017. P112 Inputs GRI-GLYCalc VERSION 4.0 - SUMMARY OF INPUT VALUES Case Name: Marla P112i File Name: \\dennas00\Data\Environmental\Air\Colorado\Marla\2017-06 Marla ECD Downtime TV Minor Mod\Minor Mod\GLYCalc\P112\P112 (6-2017 EGA).ddf Date: October 03, 2017 DESCRIPTION: Description: PTE Emissions EGA 6/2017 With Condenser 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 Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene 2.5100 0.2400 70.3768 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 Page 1 P112 Inputs 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 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: 160.0 deg. F Pressure: 12.0 psia Page 2 P112 Inputs Control Device: Combustion Device Destruction Efficiency: 95.0 Excess Oxygen: 0.0 Ambient Air Temperature: 60.0 deg. F Page 3 P112 Agg GRI-GLYCalc VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name* (Marla P112 File Name: \\dennas00\Data\Environmental\Air\Colorado\Marla\2017-06 Marla ECD Downtime TV Minor Mod\Minor Mod\GLYCalc\P112\P112 (6-2017 EGA).ddf Date: October 03, 2017 DESCRIPTION: Description: PTE Emissions EGA 6/2017 With Condenser Annual Hours of Operation: 8760.0 hours/yr EMISSIONS REPORTS: CONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.0254 0.609 0.1111 Ethane 0.0438 1.052 0.1920 Propane 0.0777 1.866 0.3405 Isobutane 0.0231 0.553 0.1010 n -Butane 0.0792 1.901 0.3470 Isopentane 0.0249 0.598 0.1092 n -Pentane 0.0377 0.904 0.1650 Cyclopentane 0.0101 0.243 0.0443 n -Hexane 0.0178 0.426 0.0777 Cyclohexane 0.0266 0.639 0.1166 Other Hexanes 0.0203 0.488 0.0890 Heptanes 0.0306 0.734 0.1339 Methylcyclohexane 0.0273 0.655 0.1195 2,2,4-Trimethylpentane 0.0001 0.002 0.0004 Benzene 0.1655 3.971 0.7247 Toluene 0.2137 5.128 0.9358 Ethylbenzene 0.0080 0.191 0.0348 Page 1 Xylenes C8+ Heavies P112 Agg 0.1021 0.0054 2.451 0.4473 0.129 0.0236 Total Emissions Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions UNCONTROLLED REGENERATOR EMISSIONS 0.9391 0.9391 0.8699 0.5070 0.4892 22.539 4.1134 22.539 4.1134 20.878 3.8103 12.169 2.2208 11.741 2.1427 Component lbs/hr lbs/day tons/yr Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene Xylenes C8+ Heavies 0.5074 0.8783 1.5656 0.4668 1.6094 0.5179 0.7927 0.2148 0.3872 0.6009 0.4350 0.7463 0.6776 0.0021 3.8671 6.1129 0.3353 4.5695 2.8367 12.177 21.078 37.576 11.203 38.627 12.430 19.025 5.156 9.293 14.422 10.439 17.911 16.263 0.052 92.809 146.709 8.046 109.668 68.081 2.2223 3.8468 6.8575 2.0446 7.0494 2.2684 3.4720 0.9410 1.6960 2.6321 1.9051 3.2688 2.9679 0.0094 16.9377 26.7745 1.4684 20.0144 12.4241 Total Emissions Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions 27.1236 650.966 27.1236 25.7379 15.2741 14.8847 Page 2 650.966 617.711 366.577 357.233 118.8012 118.8012 112.7322 66.9004 65.1950 P112 Agg FLASH GAS EMISSIONS Note: Flash Gas Emissions are zero with the Recycle/recompression control option. FLASH TANK OFF GAS Component lbs/hr lbs/day tons/yr Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene Xylenes C8+ Heavies 84.3844 38.3776 28.5218 5.2747 13.4072 3.5910 4.3027 0.3028 1.0812 0.4321 1.6519 0.9474 0.3573 0.0057 0.3226 0.3055 0.0090 0.0817 0.3317 2025.227 921.063 684.524 126.593 321.772 86.184 103.264 7.266 25.949 10.370 39.646 22.737 8.575 0.136 7.741 7.332 0.216 1.961 7.961 369.6039 168.0940 124.9257 23.1033 58.7234 15.7285 18.8457 1.3261 4.7357 1.8925 7.2354 4.1495 1.5649 0.0248 1.4128 1.3381 0.0395 0.3579 1.4530 Total Emissions Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions EQUIPMENT REPORTS: 183.6883 4408.520 183.6883 60.9262 1.8057 0.7188 4408.520 1462.230 43.336 17.251 804.5548. 804.5548 266.8569 7.9088 3.1484 Page 3 P112 Agg CONDENSER AND COMBUSTION DEVICE Condenser Outlet Temperature: Condenser Pressure: Condenser Duty: Hydrocarbon Recovery: Produced Water: Ambient Temperature: Excess Oxygen: Combustion Efficiency: Supplemental Fuel Requirement: Component 160.00 deg. F 12.00 psia 7.09e-002 MM BTU/hr 0.67 bbls/day 8.18 bbls/day 60.00 deg. F 0.00 95.00 7.09e-002 MM BTU/hr Emitted Destroyed Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene Xylenes C8+ Heavies ABSORBER 5.00% 4.99% 4.97% 4.94% 4.92% 4.81% 4.75% 4.71% 4.58% 4.43% 4.67% 4.10% 4.03% 4.09% 4.28% 3.50% 2.37% 2.24% 0.19% 95.00% 95.01% 95.03% 95.06% 95.08% 95.19% 95.25% 95.29% 95.42% 95.57% 95.33% 95.90% 95.97% 95.91% 95.72% 96.50% 97.63% 97.76% 99.81% NOTE: Because the Calculated Absorber Stages was below the minimum allowed, GRI-GLYCalc has set the number of Absorber Stages to 1.25 Page 4 P112 Agg and has calculated a revised Dry Gas Dew Point. Calculated Absorber Stages: 1.25 Calculated Dry Gas Dew Point: 4.35 lbs. H20/MMSCF Temperature: Pressure: Dry Gas Flow Rate: Glycol Losses with Dry Gas: Wet Gas Water Content: Calculated Wet Gas Water Content: Calculated Lean Glycol Recirc. Ratio: Component 106.0 deg. F 1000.0 psig 45.0000 MMSCF/day 2.2992 lb/hr Saturated 69.88 lbs. H20/MMSCF 3.05 gal/lb H2O Remaining in Dry Gas Absorbed in Glycol Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene Xylenes C8+ Heavies FLASH TANK 6.22% 99.81% 99.98% 99.98% 99.96% 99.94% 99.93% 99.91% 99.92% 99.90% 99.55% 99.86% 99.35% 99.89% 99.78% 99.37% 99.91% 94.33% 92.98% 91.93% 88.91% 99.53% 93.78% 0.19% 0.02% 0.02% 0.04% 0.06% 0.07% 0.09% 0.08% 0.10% 0.45% 0.14% 0.65% 0.11% 0.22% 0.63% 0.09% 5.67% 7.02% 8.07% 11.09% 0.47% Page 5 P112 Agg Flash Control: Recycle/recompression Flash Temperature: 100.0 deg. F Flash Pressure: 45.0 psig Component Left in Glycol Removed in Flash Gas Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene Xylenes C8+ Heavies REGENERATOR 99.85% 8.11% 0.57% 0.60% 2.24% 5.20% 8.13% 10.72% 12.77% 15.74% 41.73% 26.56% 59.29% 21.20% 44.24% 66.62% 27.95% 92.68% 95.61% 97.65% 98.47% 90.54% 0.15% 91.89% 99.43% 99.40% 97.76% 94.80% 91.87% 89.28% 87.23% 84.26% 58.27% 73.44% 40.71% 78.80% 55.76% 33.38% 72.05% 7.32% 4.39% 2.35% 1.53% 9.46% No Stripping Gas used in regenerator. Remaining Distilled in Glycol Overhead Component Water Carbon Dioxide Nitrogen Methane 22.24% 0.00% 0.00% 0.00% Page 6 77.76% 100.00% 100.00% 100.00% P112 Agg Ethane 0.00% Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene Xylenes C8+ Heavies STREAM REPORTS: 100.00% 0.00% 100.00% 0.00% 100.00% 0.00% 100.00% 1.48% 98.52% 1.37% 98.63% 0.92% 99.08% 0.96% 99.04% 4.49% 95.51% 2.15% 97.85% 0.71% 99.29% 4.98% 95.02% 2.22% 97.78% 5.28% 94.72% 8.12% 91.88% 10.51% 89.49% 13.01% 86.99% 10.61% 89.39% WET GAS STREAM Temperature: Pressure: Flow Rate: 106.00 deg. F 1014.70 psia 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 Page 7 P112 Agg n -Butane 2.30e+000 6.61e+003 Isopentane 5.28e-001 1.89e+003 n -Pentane 5.99e-001 2.14e+003 Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene 2.56e-002 8.87e+001 1.24e-001 5.29e+002 3.14e-002 1.31e+002 1.97e-001 8.41e+002 9.47e-002 4.70e+002 2.78e-002 1.35e+002 5.99e-004 3.39e+000 1.87e-002 7.22e+001 1.97e-002 8.97e+001 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: Pressure: Flow Rate: 106.00 deg. F 1014.70 psia 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 8 P112 Agg 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: 6.24e+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-018 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 Page 9 P112 Agg 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 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 4.40e+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 Page 10 P112 Agg 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 1.08e+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) Page 11 P112 Agg 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 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 1.11e-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 Page 12 P112 Agg 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 1.11e-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 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. Page 13 P112 Agg 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. CONDENSER RECOVERED OIL STREAM Temperature: 160.00 deg. F Flow Rate: 1.94e-002 gpm Component Conc. Loading (wt%) (lb/hr) Water 5.62e-002 4.65e-003 Carbon Dioxide 1.47e-002 1.22e-003 Nitrogen 1.22e-005 1.01e-006 Methane 1.77e-003 1.47e-004 Ethane 1.56e-002 1.29e-003 Propane 1.27e-001 1.05e-002 Isobutane 6.80e-002 5.62e-003 n -Butane 3.01e-001 2.49e-002 Isopentane 2.35e-001 1.94e-002 n -Pentane 4.75e-001 3.93e-002 Cyclopentane 1.48e-001 1.22e-002 n -Hexane 3.89e-001 3.22e-002 Page 14 P112 Agg Cyclohexane 8.24e-001 6.82e-002 Other Hexanes 3.45e-001 2.85e-002 Heptanes 1.63e+000 1.35e-001 Methylcyclohexane 1.59e+000 1.32e-001 2,2,4-Trimethylpentane 4.74e-003 3.92e-004 Benzene 6.39e+000 5.29e-001 Toluene 2.19e+001 1.81e+000 Ethylbenzene 2.12e+000 1.75e-001 Xylenes 3.04e+001 2.51e+000 C8+ Heavies 3.30e+001 2.73e+000 Total Components 100.00 8.27e+000 CONDENSER VENT STREAM Temperature: 160.00 deg. F Pressure: 12.00 psia Flow Rate: 2.02e+002 scfh Component Conc. Loading (vol%) (lb/hr) Water 3.96e+001 3.79e+000 Carbon Dioxide 6.14e+000 1.44e+000 Nitrogen 1.98e-002 2.94e-003 Methane 5.95e+000 5.07e-001 Ethane 5.49e+000 8.77e-001 Propane 6.63e+000 1.55e+000 Isobutane 1.49e+000 4.61e-001 n -Butane 5.13e+000 1.58e+000 Isopentane 1.30e+000 4.98e-001 n -Pentane 1.96e+000 7.53e-001 Cyclopentane 5.43e-001 2.02e-001 n -Hexane 7.75e-001 3.55e-001 Cyclohexane 1.19e+000 5.33e-001 Other Hexanes 8.87e-001 4.06e-001 Heptanes 1.15e+000 6.11e-001 Methylcyclohexane 1.05e+000 5.46e-001 2,2,4-Trimethylpentane 2.89e-003 1.76e-003 Benzene 7.97e+000 3.31e+000 Toluene 8.72e+000 4.27e+000 Page 15 P112 Agg Ethylbenzene 2.82e-001 1.59e-001 Xylenes 3.62e+000 2.04e+000 C8+ Heavies 1.19e-001 1.08e-001 Total Components 100.00 2.40e+001 COMBUSTION DEVICE OFF GAS STREAM Temperature: 1000.00 deg. F Pressure: 14.70 psia Flow Rate: 5.47e+000 scfh Component Conc. Loading (vol%) (lb/hr) Methane 1.10e+001 2.54e-002 Ethane 1.01e+001 4.38e-002 Propane 1.22e+001 7.77e-002 Isobutane 2.75e+000 2.31e-002 n -Butane 9.45e+000 7.92e-002 Isopentane 2.40e+000 2.49e-002 n -Pentane 3.62e+000 3.77e-002 Cyclopentane 1.00e+000 1.01e-002 n -Hexane 1.43e+000 1.78e-002 Cyclohexane 2.19e+000 2.66e-002 Other Hexanes 1.64e+000 2.03e-002 Heptanes 2.12e+000 3.06e-002 Methylcyclohexane 1.93e+000 2.73e-002 2,2,4-Trimethylpentane 5.33e-003 8.78e-005 Benzene 1.47e+001 1.65e-001 Toluene 1.61e+001 2.14e-001 Ethylbenzene 5.19e-001 7.95e-003 Xylenes 6.67e+000 1.02e-001 C8+ Heavies 2.19e-001 5.38e-003 Total Components 100.00 9.39e-001 Page 16 P113 Inputs GRI-GLYCalc VERSION 4.0 - SUMMARY OF INPUT VALUES Case Name Maria P113 (Dehy 2) File Name: \\dennas00\Data\Environmental\ro20171EGA)1ddf6 Marla ECD Downtime TV Minor Mod\Mnor Mod\GLYCalc\P113\P113(6 Date: October 03, 017 DESCRIPTION: Description: PTE Emissions EGA 6/2017 With Condenser 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 Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene 2.5100 0.2400 70.3768 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 Page 1 P113 Inputs 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 FLASH TANK: Flash Control: Recycle/recompression Temperature: 160.0 deg. F Pressure: 55.0 psig REGENERATOR OVERHEADS CONTROL DEVICE: Control Device: Condenser Temperature: 160.0 deg. F Pressure: 12.0 psia Page 2 P113 Inputs Control Device: Combustion Device Destruction Efficiency: 95.0 Excess Oxygen: 0.0 Ambient Air Temperature: 60.0 deg. F Page 3 P113 Agg GRI-GLYCalc VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name: ';Marla; P113 (Dehy 2) File Name: \\dennas00\Data\Environmental\Air\Colorado\Marla\2017-06 Marla ECD Downtime TV Minor Mod\Minor 4od\GLYCalc\P113\P113 (6-2017 EGA).ddf Date: October 03, 2017 DESCRIPTION: Description: PTE Emissions EGA 6/2017 With Condenser Annual Hours of Operation: 8760.0 hours/yr EMISSIONS REPORTS: CONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.0244 0.586 0.1070 Ethane 0.0732 1.756 0.3205 Propane 0.1298 3.115 0.5684 Isobutane 0.0362 0.870 0.1588 n -Butane 0.1302 3.125 0.5702 Isopentane 0.0347 0.833 0.1520 n -Pentane 0.0551 1.322 0.2413 Cyclopentane 0.0181 0.434 0.0791 n -Hexane 0.0243 0.584 0.1066 Cyclohexane 0.0424 1.017 0.1857 Other Hexanes 0.0272 0.654 0.1194 Heptanes 0.0413 0.992 0.1810 Methylcyclohexane 0.0412 0.988 0.1803 2,2,4-Trimethylpentane 0.0001 0.002 0.0004 Benzene 0.2352 5.645 1.0302 Toluene 0.3218 7.724 1.4096 Ethylbenzene 0.0134 0.322 0.0587 Page 1 Xylenes C8+ Heavies P113 Agg 0.1742 0.0095 4.180 0.7628 0.227 0.0415 Total Emissions Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions UNCONTROLLED REGENERATOR EMISSIONS 1.4323 1.4323 1.3347 0.7690 0.7446 34.376 6.2735 34.376 6.2735 32.033 5.8460 18.457 3.3684 17.871 3.2614 Component lbs/hr lbs/day tons/yr Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene Xylenes C8+ Heavies 0.4888 1.4649 2.6062 0.7301 2.6278 0.7097 1.1343 0.3741 0.5122 0.9105 0.5672 0.9315 0.9381 0.0022 5.1701 8.0473 0.4371 5.9429 2.9220 11.732 35.157 62.548 17.522 63.067 17.032 27.222 8.979 12.293 21.853 13.612 22.355 22.514 0.052 124.083 193.135 10.490 142.629 70.129 2.1410 6.4162 11.4151 3.1978 11.5097 3.1084 4.9681 1.6387 2.2435 3.9881 2.4842 4.0798 4.1087 0.0095 22.6452 35.2472 1.9143 26.0298 12.7985 Total Emissions Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions 36.5168 876.404 36.5168 34.5632 20.1118 19.5974 Page 2 876.404 829.516 482.683 470.337 159.9438 159.9438 151.3866 88.0896 85.8366 P113 Agg FLASH GAS EMISSIONS Note: Flash Gas Emissions are zero with the Recycle/recompression control option. FLASH TANK OFF GAS Component lbs/hr lbs/day tons/yr Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene Xylenes C8+ Heavies 11.4208 10.9374 9.3181 1.8702 5.3071 1.3228 1.7463 0.1502 0.4751 0.2195 0.6774 0.4613 0.1871 0.0021 0.1990 0.2163 0.0073 0.0703 0.3310 274.099 262.499 223.633 44.885 127.370 31.746 41.912 3.604 11.402 5.269 16.257 11.071 4.489 0.049 4.776 5.192 0.176 1.688 7.945 50.0231 47.9060 40.8131 8.1915 23.2450 5.7937 7.6489 0.6578 2.0809 0.9616 2.9669 2.0204 0.8193 0.0090 0.8717 0.9475 0.0321 0.3081 1.4500 Total Emissions Total Hydrocarbon Emissions Total VOC Emissions Total HAP Emissions Total BTEX Emissions EQUIPMENT REPORTS: 44.9193 1078.063 196.7464 44.9193 22.5610 0.9702 0.4930 1078.063 541.465 23.284 11.832 196.7464 98.8173 4.2493 2.1594 Page 3 P113 Agg CONDENSER AND COMBUSTION DEVICE Condenser Outlet Temperature: Condenser Pressure: Condenser Duty: Hydrocarbon Recovery: Produced Water: Ambient Temperature: Excess Oxygen: Combustion Efficiency: Supplemental Fuel Requirement: 160.00 deg. F 12.00 psia 1.09e-001 MM BTU/hr 0.63 bbls/day 9.92 bbls/day 60.00 deg. F 0.00 95.00 1.09e-001 MM BTU/hr Component Emitted Destroyed Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene Xylenes C8+Heavies ABSORBER 5.00% 5.00% 4.98% 4.96% 4.95% 4.89% 4.86% 4.83% 4.75% 4.66% 4.80% 4.44% 4.39% 4.43% 4.55% 4.00% 3.07% 2.93% 0.32% 95.00% 95.00% 95.02% 95.04% 95.05% 95.11% 95.14% 95.17% 95.25% 95.34% 95.20% 95.56% 95.61% 95.57% 95.45% 96.00% 96.93% 97.07% 99.68% NOTE: Because the Calculated Absorber Stages was below the minimum allowed, GRI-GLYCalc has set the number of Absorber Stages to 1.25 Page 4 P113 Agg and has calculated a revised Dry Gas Dew Point. Calculated Absorber Stages: 1.25 Calculated Dry Gas Dew Point: 4.13 lbs. H20/MMSCF Temperature: Pressure: Dry Gas Flow Rate: Glycol. Losses with Dry Gas: Wet Gas Water Content: Calculated Wet Gas Water Content: Calculated Lean Glycol Recirc. Ratio: Component 106.0 deg. F 1000.0 psig 55.0000 MMSCF/day 2.8098 lb/hr Saturated 69.88 lbs. H20/MMSCF 3.26 gal/lb H2O Remaining in Dry Gas Absorbed in Glycol Water Carbon Dioxide Nitrogen Methane Ethane Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene Xylenes C8+ Heavies FLASH TANK 5.89% 99.80% 99.98% 99.98% 99.95% 99.94% 99.92% 99.90% 99.91% 99.89% 99.52% 99.85% 99.29% 99.88% 99.76% 99.32% 99.90% 93.92% 92.46% 91.34% 88.13% 99.49% 94.11% 0.20% 0.02% 0.02% 0.05% 0.06% 0.08% 0.10% 0.09% 0.11% 0.48% 0.15% 0.71% 0.12% 0.24% 0.68% 0.10% 6.08% 7.54% 8.66% 11.87% 0.51% Page 5 P113 Agg Flash Control: Recycle/recompression Flash Temperature: 160.0 deg. F Flash Pressure: 55.0 psig Left in Removed in Component 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 in Glycol Overhead Component Water 23.44% 76.56% Carbon Dioxide 0.00% 100.00% Nitrogen 0.00% 100.00% Methane 0.00% 100.00% Page 6 P113 Agg Ethane 0.00% Propane Isobutane n -Butane Isopentane n -Pentane Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene Xylenes C8+ Heavies STREAM REPORTS: 100.00% 0.00% 100.00% 0.00% 100.00% 0.00% 100.00% 1.42% 98.58% 1.26% 98.74% 0.70% 99.30% 0.96% 99.04% 3.94% 96.06% 2.17% 97.83% 0.75% 99.25% 4.76% 95.24% 2.88% 97.12% 5.18% 94.82% 8.10% 91.90% 10.57% 89.43% 13.08% 86.92% 13.22% 86.78% WET GAS STREAM Temperature: Pressure: Flow Rate: 106.00 deg. F 1014.70 psia 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 Page 7 P113 Agg n -Butane 2.30e+000 8.08e+003 Isopentane 5.28e-001 2.31e+003 n -Pentane 5.99e-001 2.61e+003 Cyclopentane n -Hexane Cyclohexane Other Hexanes Heptanes Methylcyclohexane 2,2,4-Trimethylpentane Benzene Toluene Ethylbenzene 2.56e-002 1.08e+002 1.24e-001 6.47e+002 3.14e-002 1.60e+002 1.97e-001 1.03e+003 9.47e-002 5.74e+002 2.78e-002 1.65e+002 5.99e-004 4.14e+000 1.87e-002 8.83e+001 1.97e-002 1.10e+002 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 8 P113 Agg 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 C8+ 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 Page 9 P113 Agg 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 7.93e+000 Isopentane 4.20e-002 2.04e+000 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 8.97e+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 Page 10 P113 Agg FLASH TANK OFF GAS STREAM Temperature: 160.00 deg. F Pressure: 69.70 psia Flow Rate: 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 3.85e-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) Page 11 P113 Agg 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 4.89e-001 Ethane 3.05e-002 1.46e+000 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+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 Page 12 P113 Agg 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 C8+ Heavies 1.91e-001 2.92e+000 Total Components 100.00 1.91e+002 , 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. Page 13 P113 Agg 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. CONDENSER RECOVERED OIL STREAM Temperature: 160.00 deg. F Flow Rate: 1.83e-002 gpm Component Conc. Loading (wt%) (lb/hr) Water 5.50e-002 4.28e-003 Carbon Dioxide 2.45e-002 1.91e-003 Nitrogen 8.24e-006 6.42e-007 Methane 1.06e-003 8.29e-005 Ethane 1.60e-002 1.25e-003 Propane 1.31e-001 1.02e-002 Isobutane 6.58e-002 5.12e-003 n -Butane 3.03e-001 2.37e-002 Isopentane 1.99e-001 1.55e-002 n -Pentane 4.16e-001 3.24e-002 Cyclopentane 1.62e-001 1.26e-002 n -Hexane 3.26e-001 2.54e-002 Page 14 P113 Agg Cyclohexane 8.02e-001 6.25e-002 Other Hexanes 2.84e-001 2.21e-002 Heptanes 1.35e+000 1.05e-001 Methylcyclohexane 1.47e+000 1.15e-001 2,2,4-Trimethylpentane 3.17e-003 2.47e-004 Benzene 5.58e+000 4.35e-001 Toluene 2.02e+001 1.58e+000 Ethylbenzene 2.15e+000 1.68e-001 Xylenes 3.13e+001 2.44e+000 C8+ Heavies 3.51e+001 2.73e+000 Total Components 100.00 7.79e+000 CONDENSER VENT STREAM Temperature: 160.00 deg. F Pressure: 12.00 psia Flow Rate: 3.26e+002 scfh Component Conc. Loading (vol%) (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 1.45e+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 4.87e-001 Cyclohexane 1.17e+000 8.48e-001 Other Hexanes 7.35e-001 5.45e-001 Heptanes 9.59e-001 8.26e-001 Methylcyclohexane 9.75e-001 8.23e-001 2,2,4-Trimethylpentane 1.96e-003 1.93e-003 Benzene 7.00e+000 4.70e+000 Toluene 8.12e+000 6.44e+000 Page 15 P113 Agg 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 COMBUSTION DEVICE OFF GAS STREAM Temperature: 1000.00 deg. F Pressure: 14.70 psia Flow Rate: 8.17e+000 scfh Component Conc. Loading (vol%) (lb/hr) Methane 7.08e+000 2.44e-002 Ethane 1.13e+001 7.32e-002 Propane 1.37e+001 1.30e-001 Isobutane 2.90e+000 3.62e-002 n -Butane 1.04e+001 1.30e-001 Isopentane 2.23e+000 3.47e-002 n -Pentane 3.55e+000 5.51e-002 Cyclopentane 1.20e+000 1.81e-002 n -Hexane 1.31e+000 2.43e-002 Cyclohexane 2.34e+000 4.24e-002 Other Hexanes 1.47e+000 2.72e-002 Heptanes 1.92e+000 4.13e-002 Methylcyclohexane 1.95e+000 4.12e-002 2,2,4-Trimethylpentane 3.92e-003 9.63e-005 Benzene 1.40e+001 2.35e-001 Toluene 1.62e+001 3.22e-001 Ethylbenzene 5.87e-001 1.34e-002 Xylenes 7.62e+000 1.74e-001 C8+ Heavies 2.58e-001 9.47e-003 Total Components 100.00 1.43e+000 Page 16 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 DENY INLET 915 NO PROBE SPOT ANALYSIS NO. : ANALYSIS DATE: SAMPLE DATE : CYLINDER NO. : SAMPLED BY : SAMPLE TEMP. : AMBIENT TEMP.: 07 JULY 05, 2017 14:34 JUNE 28, 2017 12:05 1943 MATT PICKETT 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 The data presented herein has been acquired by means of current analytical techniques and represents the judicious conclusion liiilPA CT Analytical .Systems. Inc. Results of the analysis can be affected fry the sampling eonditiou.a, therefirre, arc only warranted though proper lab protocol. EM!'; I CT assumes no respansihility for interpretation or any runsequences from application of the reported information and is the sole liability (tithe user. The,eproduction in ant media of this reported inf nneation may not be made. in portion or as a whole, without the written permission of EMPACT A❑al tic -al Systems, The. EMPACT Analytical Systems Inc. 365 S Main St Brighton, CO 80601 303-637-0150 Insignificant Emissions Marla Compressor Station DCP Midstream,LP 1,000 gal, Methanol tank 300 bbl Methanol tank 1,000 gal Lube oil tank 210 bbl, Lube oil tank 1,000 gal TEG glycol tank 1,000 gal Norkool glycol tank 20 bbl slop oil tank 30,000 gal Pressurized Condensate Storage Tank 30,000 gal Pressurized Condensate Storage Tank Pressurized Condensate Truck Loadout Dehy Reboiler H-112 Deily Reboiler H-113 20 bbl, Stormwater tank 80 bbl, Stormwater tank 80 bbl, Stormwater tank 80 bbl, Stormwater tank 80 bbl, Stormwater tank 80 bbl, Produced Water Tank 80 bbl, Produced Water Tank 80 bbl, Produced Water Tank 80 bbl, Produced Water Tank 110 bbl, Produced Water Tank Regulation No. 3, Part C, Section II.E.3.a. Condenser Combustor C-148 vent blowdown C-135 vent blowdown Regulation No. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section II.E.3.aaa Regulation No. 3, Part C, Section II.E.3.aaa Regulation No. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section 11.5.3.8. Regulation No. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section Il.E.3.a. Regulation No. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section II.E.3.8. Regulation NO. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section II.E,3.a. Regulation No. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section 11.5.3.8. Regulation No. 3, Part C, Section II.E.3.a. Regulation No. 3, Part C, Section II.E.3.a. 0.36 0.32 0.43 0.30 0.27 1.52 0.02 0.20 neg. neg. neg. neg. neg. neg. neg. 0.33 0.02 0.02 neg; neg.n neg. neg. neg. 0.10 0.10 0.10 0.10 0.13 0.29 0.36 0:15 5.24 5.24 5.24 5.24 7.21 Total HAP (lt)/yr)' 38.48 398.00 13.48 11.89 16.48 21.73 16.48 - 16.48 16.48 22.66 21.73 21.73 21.73 29.87 51.94 63.07 25.97 55.65 Engineering Estimate TANKS 4.0.9d TANKS 4.0.9d N/A - Not a source of emissions N/A - Not a source of emissions Engineering Estimate AP -42 Section 1.4, Table 1.4-1 AP -42 Section 1.4, Table 1.4-2 PS Memo 09-02 PS Memo 09-02 PS Memo 09-02 PS Memo 09-02 PS Memo 09-02 TNRCC Flares and Vapor Oxidizers, Table 4 Flare Factors Engineering Estimate Engineering Estimate Engineering Estimate ID VCI IL UIuvvuuvv„ Regulation No. 3, Part C, Section II.E.3.a. -- u.or '-- Engineering Estimate C-166 vent blowdown Regulation No. 3, Part C, Section II.E.3.a. -- _ 0.23 1 40.840.81 Engineering Estimate C-174 vent blowdown No. 3, Part C, Section II.E.3.a. — 0.13 _-- 6 EPA Publication No. 453\R-95-017 Table 2-8 C-176 vent blowdown Regulation Regulation No: 3, Part C, Section II.E.3.a- — _- 0.43 1.21 28.06 --- Facility Fugitive Emissions 1.10 2.09 3.01 29.40 116.65 838.33 Total Insignificant Emissions Attachment E Form APCD-102 Marla Compressor Station Form APCD-102 Company Name: DCP Midstream, LP Source Name: Marla Compressor Station Source AIRS ID: 123/0243 • ' Emeat Desert don 123/0243/011 Mm1 C -148/P-102 123/0243/053 En me C -135/P-103 123/0243/054 En-inee-151/P-101 123/0243/059 En me C -166/P-109 123/0243/060 Orion C -174/P-110 123/0243/061 En:ineC-176/P-III 123/0243/062 123/0243/063 P -I 12 TOG Deb P.113 TEG Deh Permitted Sources Sublolal— Colorado Department of Public Health and Environment Air Pollution Control Division Facility Wide Emissions Inventory Form Ver. April, 2015 Uncontrolled Potential to Emil (PTE) Controlled Potential to Emil (PTE) Criteria (TPY) I HAP. ( be/yr) Criteria (TPY) I HAPs ( be/yr) 1SP PMIO PO11.S SO2 NO5 VOL LO I MHO AceInl Ares HL Ill E8 Xyl n -Hex Meth 214-I MP ESP P5110 PM1.5 SO2 /405 VOL LO I HLIIU Acelal Acro HL Tel LW Xyl O-llex Meth 224 -IMP 1.0 1.0 LO 0.0 157.0 21.4 IH,Z-' 2,078 283 267 160 57 3 20 0 310 0 1.0 1.0 1.0 0.0 42.8 14.3 42.8 1 499 141 1]3 SO 28 I 10 0 155 0 1.0 1.0 1.0 0.0 157.0 21.4 114.2 1 2,078 283 267 (00 57 3 20 0 310 0 1.0 10 1,0 0.0 28.3 14.3 42.8 I 499 141 133 i 80 28 I IO 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 10.0 283 I 499 141 133 80 28 I 10 0 155 () 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 1.1 1.1 0.0 32.4 16.2 32.4 1 569 161 152 91 32 I 11 0 177 0 1.1 I.1 1.1 0.0 175.4 24.3 129.8 I 2,371 323 304 183 65 3 23 0 354 0 1.1 1.1 IA 0.0 324 16.2 32.4 1 569 161 152 91 32 1 II 0 177 0 1.1 I.1 1.1 0.0 178.4 243 129.8 I 2,371 323 304 183 65 3 27 0 354 0 1.1 IA I.1 0.0 32.4 16.2 32.4 1 569 161 152 91 32 I 11 0 177 0 0.0 0.0 0.0 0.0 0.13 455.51 0.6: 1 0 0 0 44,041 67,470 3.6:9 48,894 15,436 0 0 0.0 0.0 0.0 0.0 0.13 8.49 0.61 1 0 0 0 2,907 4,107 IB7 2,482 304 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 12.25 0.87 1 0 0 0 4,029 5,09 274 3,650 409 0 0 6.3 6.3 6.3 0.2 1006.6 893.0 733.3 1 13,349 1,07 1,713 101,511 154,701 7,528 112,231 25,815 1,993 0 6.3 6.3 6.3 0.2 183.3 108.0 213.0. i 3,204 908 856 7,450 10,108 470 6,196 713 996 0 I I I I I I I 1 I I I APEN Only Subtotal= PEN Esmnpl/ Inotgnificnnt sources 0.0 0.0 0,0 0.0 0.0 0.0 I 0.0 1 0 0 0 0 0 0 0 0 0 0 0,0 0.0 0.0 0.0 0.0 0.0 0.0 1 0 0 0 0 0 0 0 0 0 0 0.0 0.0 1.1 , 3.0 2.1 I 0 0 0 29 0 0 0 117 0 0 0.0 _ 0.0 0.0 0.0 1.1 3.0 2.1 I 0 0 0 29 0 0 0 Ill 0 0 Insignificant Acifivcs (See Lisl) 0.0 0.0 1 I I I I I I I I I I I Insignificant Subtotal= 0.0 0.0 0.0 0.0 1.1 3.0 2.1 I 0 0 0 29 0 0 0 117 0 0 0.0 0,0 0.0 0.0 1.1 3.0 2.1 - 1 0 0 0 29 0 0 0 117 0 0 Total, All Sources= 6.3 6.3 6.3 0.2 1007.7 896.0 I 735.4 I 13,349 1,817 1,713 101,540 134,701 7,528 112,231 25,531 5,993 Uncontrolled HAP, Summery (TPY) _ 0 6.3 6.3 6.3 0.2 184.4 111.0 215.1 I 3,204 908 856 7,480 10,108 470 6,196 830 996 0 6.7 I 0.9 I 0.9 I 50.8 I 77.4 I 3.8 I 56.1 I 13.0 I 1.0 I 0.0 Uncontrolled Totn1, All HAPs (TPY)= I 210.4 I 'ooleeotes: . This form should be completed to include both existing sources and all proposed new or modifications to existing emissions sources . If the emissions source is new then enter "proposed" under the Permit No. and AIRS ID data columns , HAP abbreviations include: IIZ = Benzene 224-TMP = 2,2,4-TrimethylpentmH Tol = Toluene Acetal = Acetaldehyde CB = Ethylbenzent Arm = Acrolein Xyl = Xylene n -Hex = n -Hexane HCIIO =Formaldehyde Meth = Methanol APEN Exempt/Insignificant Sources should be included 5011e0 warranted. Controlled HAPs Summery (TPY)"I 1.6 I 0.5 I 0.4 I 3.7 5.1 I 0.2 I 3.1 I 0.4 I 0.5 I 0.0 Controlled Total, All HAP, (TPY)= I 19.5 I Attachment F Updated O&M Plan (P-112, P-113) Marla Compressor Station COLORADO Air Pollution Control Division Department of Public Health :7 Env ronrnent I Form APCD-302 Air Pollution Control Division Operating and Maintenance Plan Template for Glycol Dehydration Systems Ver. December 22, 2016 The Air Pollution Control Division (Division) developed this Operating and Maintenance Plan (OEM 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 OEtM 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 OEtM Plan upon commencement of operation. An existing approved OEtM Plan may be modified without a permit modification or permit reissuance, but the operator must adhere to the requirements of the existing approved OEtM Plan until an approval letter is issued for the new OEtM Plan. The operator is required to use the Division -developed OEtM 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 OEtM 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: October 2017 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 Facility Equipment ID Permit Number (if known) AIRS Point ID (if known) Glycol Type Used a Equipped with Flash Tank? (Y/N) Emission Units Covered by this O&M Form P-112 P-113 95OPWE020 95OPWE020 062 063 TEG Y TEG Y a Glycol types are Ethylene Glycol (EG), Diethylene Glycol (DEG), or Triethylene Glycol (TEG). APCD Internal Use Only Approved? Initial Date 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 minimizing 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 OM 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 Ule juLIuLy-vvIUc pc;un«c.. ..... .................. Table 1 Emissions Control or Recycling Method Flash Still Tank Vent (if present) Parameter Monitoring Frequency IPermitted ❑ Permitted Facility Emissions < 80 tpy VOC Facility Emissions ≥ 80 tpy VOC Condenser b ❑ Condenser Outlet Temperature Weekly Monthly 1 Enclosed Flare or Combustor ❑ Pilot Light and Auto- igniter Monitoring d Daily Weekly Visible Emissions Observation e Daily Weekly Elevated Open Flare ` ❑ ❑ Pilot Light and Auto- igniter Monitoring Daily Weekly Visible Emissions Observation e Daily Weekly Thermal Oxidizer ❑ ❑ Combustion Chamber Temperature f Daily Weekly Page 2 of 5 COLORADO Air Pollution Control Division Department of Public. Health & 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 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 �� 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 snau lie. Table 2: Condenser Maximum Outlet Temperature 160 °F ►4 ❑ °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 ❑ ►� Visual Inspection ❑ ❑ Optical Sensor ❑ ❑ Auto -Igniter Signal ►� ❑ 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 combustion device for the presence or absence of smoke (e.g., visible emissions). If smoke is observed during Page 3 of 5 COLORADO Air Pollution Control Division Department of Public Health & Environment 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. B 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 inlet. Page 4 of 5 COLORADO Air Pollution Control Division Department of Public. Health a 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 O&tM 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 condensers and enclosed combustor (ECD) used for still vent control have 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 downtime. Downtime is defined as periods when emissions from the condenser still vents, or emissions directly from the dehy regen overheads, are routed to the atmosphere instead of to the ECD. If unit P- 112 and P-113 are down in addition to the 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 G Redlined Title V Operating Permit 95OPWE020 Conditions Marla Compressor Station 3. P-112 (AIRS 062) Triethylene Glycol Dehydration Unit with condenser and flare; P-113 (AIRS 063) Triethylene Glycol Dehydration Unit with condenser and flare; Note: These limitations apply to each dehydration unit individually. Parameter Permit Condition Number Limitations Compliance Emission Factor Monitoring Method Interval VOC Emissions 3.1 2.82 tons/yr Based on GRI GLYCaIc Model, Version 4.0 or Higher Parametric Daily P-112: 8.49 tons/yr P-113: 12.25 tons/yr HAP Emissions Facility wide: Each individual HAP: 8.0 tons per year Total HAPs: 20.0 tons per year Extended Gas Analysis EPA Reference Methods Quarterly Gas Processed 3.2 P-112: 16,425 million scf per year 492.75 million scf per year (during 3% ECD downtime) P-113: 20,075 million scf per year 602.25 million scf per year (during 3% ECD downtime) Recordkeeping Monthly Hours of Operation 3.3 Record keeping Monthly Flare Opacity 3.4 No visible emissions EPA Method 22 Daily Compliance Assurance Monitoring 3.5 See Condition 4 Volatile Organic Compound Emissions from Oil and Gas Operations 3.6 See Condition 3.6 Lean Glycol Recirculation Rate 3.7 P-112: 6.25 gallons/minute P-113: 8.20 gallons/minute Recordkeeping Weekly NESHAP Subpart HH 3.8 < 1,981 lb/yr benzene or < See Condition 3.8 3MMscf/day 3.1.1 VOC and HAP emissions shall be calculated monthly using the Gas Research Institute's GLYCaIc Model, Version 4.0 or higher. Monitoring of the following parameters to be entered into the GLYCaIc Model shall be monitored weekly: triethylene glycol circulation rate, flash tank temperature and pressure, and inlet (wet) gas pressure and temperature. Monitoring of the following parameters to be entered into the GLYCalc Model shall be monitored daily: condenser outlet temperature and enclosed combustor (ECD) downtime. The condenser outlet temperature recorded shall be the highest temperature reading recorded on the strip chart fer any calendar day (midnight to midnight} average of a minimum of 4 readings taken throughout any calendar day (midnight to midnight) at approximately 6 hour intervals. Values of parameters shall be representative of the unit's operation during the month. 4. Compliance Assurance Monitoring 4.1.2 For the glycol dehydration units, the permittee shall follow the CAM Plan provided in Appendix H of this permit. Excursions, for the purposes of reporting are any calendar day (midnight to midnight) in which the average condenser outlet temperature exceeds 140 °F 160 °F, or the absence of a flame within the flare. Excursions shall be reported as required by Section IV, Conditions 21 and 22.d of the permit. Note: DCP requests the following Subpart HH area source requirements be added after condition 3.8.4 in TV Operating Permit 95OPWE020. There is no change in federal applicability under Subpart HH with regard to the proposed minor modifications in this application. DCP wants the following conditions added in case the indicated Subpart HH exemption criteria are not met. Note: If the exemption criterion in Condition 3.8.1 are not met, the source is subject the requirements in Conditions 3.8.5 and 3.8.6 below: 3.8.5 Each owner or operator of an area source not located in a UA plus offset and UC boundary (as defined in §63.761) shall comply with the provisions specified in paragraphs (d)(2(i) through (iii) of this section. (§63.764(d)(2)) 3.8.5.1 Determine the optimum glycol circulation rate using the following equation: (§63.764 (d)(2)(i)) gal TEG ( Fx(I-O) LopT=1.15X3.0 lb H2O \24 hr/day) Where: LOPT = Optimal circulation rate, gal/hr. F = Gas flowrate (MMscf/D) I = Inlet water content (lb/MMscf) O = Outlet water content (lb/MMscf) 3.0 = The industry accepted rule of thumb for a TEG-to water ratio (gal TEG/ib H2O) 1.15 = Adjustment factor included for a margin of safety. 3.8.5.2 Operate the TEG dehydration unit such that the actual glycol circulation rate does not exceed the optimum glycol circulation rate determined in accordance with paragraph (d)(2)(i) of this section. If the TEG dehydration unit is unable to meet the sales gas specification for moisture content using the glycol circulation rate determined in accordance with paragraph (d)(2)(i), the owner or operator must calculate an alternate circulation rate using GRI— GLYCalcTM, Version 3.0 or higher. The owner or operator must document why the TEG dehydration unit must be operated using the alternate circulation rate and submit this documentation with the initial notification in accordance with §63.775(c)(7). (§63.764(d)(2)(ii)) 3.8.5.3 Maintain a record of the determination specified in paragraph (d)(2)(ii) in accordance with the requirements in §63.774(f) and submit the Initial Notification in accordance with the requirements in §63.775(c)(7). If operating conditions change and a modification to the optimum glycol circulation rate is required, the owner or operator shall prepare a new determination in accordance with paragraph (d)(2)(i) or (ii) of this section and submit the information specified under §63.775(c)(7)(ii) through (v). (§63.764(d)(2)(iii)) 3.8.6 Except as specified in paragraphs (c), (d), and (f) of this section, each owner or operator of a facility subject to this subpart shall maintain the records specified in paragraphs (b)(1) through (11) of this section: (§63.774(b)) 3.8.6.1 The owner or operator of an affected source subject to the provisions of this subpart shall maintain files of all information (including all reports and notifications) required by this subpart. The files shall be retained for at least 5 years following the date of each occurrence, measurement, maintenance, corrective action, report or period. (§63.774(b)(1)) a. All applicable records shall be maintained in such a manner that they can be readily accessed. (63.774(b)(1)(i)) b. The most recent 12 months of records shall be retained on site or shall be accessible from a central location by computer or other means that provides access within 2 hours after a request. (§63.774(b)(1)(ii)) c. The remaining 4 years of records may be retained offsite. (§63 .774(b)(1)(iii)) d. Records may be maintained in hard copy or computer - readable form including, but not limited to, on paper, microfilm, computer, floppy disk, magnetic tape, or microfiche. (§63.774(b)(1)(iv)) 3.8.6.2 The owner or operator of an area source not located within a UA plus offset and UC boundary must keep a record of the calculation used to determine the optimum glycol circulation rate in accordance with §63.764(d)(2)(i) or §63.764(d)(2)(ii), as applicable. (§63.774 (f)) Attachment H Redlined Compliance Assurance Monitoring (CAM) Plan Marla Compressor Station APPENDIX H Compliance Assurance Monitoring Plan — Dehydrators Background a. Emission Unit Description Natural Gas Dehydration Systems using triethylene glycol (P-112, P-113); b. Applicable Regulation, Emission Limit, Monitoring Requirements: Regulations: Operating Permit Section II, Section 3.1 Emission Limitations: VOC ( ach dchy P-112) VOC (P-113) Any Individual HAP (facility -wide) Total HAP (facility -wide) c. Control Technology: 2.82 TPY 8.49 TPY 12.25 TPY 8.O TPY 20.0 TPY Condenser {one for both units} (Separate condensers for each unit, P-112 and P-113) Flare Enclosed Combustor (one for both units) II. Monitoring Approach Indicator No. 1 Indicator No. 2 I. Indicator Measurement Approach Condenser Outlet Temperatures Flare Enclosed Combustor The outlet temperatures is are monitored with a individual thermocouples Condensers are each permitted 3% annual downtime, during which times the outlet temperatures are not required to be monitored. 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 An excursion is any calendar day (midnight to midnight) in which an temperature 110 °F 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. average above 160 °F is recorded. Excursions trigger an inspection and corrective action. Excursions determined individually for each condenser. III. Performance Criteria a. Data Representativeness Temperature is measured at the outlet of the each condenser. Device sensing heat will determine the presence or absence of the flame. b. Verification of Operational Status Thermocouple manufacturer guarantee. The observation of the presence of a flame will indicate that the device is operational. c. QA / QC Practices / Criteria Annual Calibration Sensor will be calibrated and maintained. d. Monitoring Frequency Daily. Heat sensor will be monitored continuously. e. Data Collection Procedures Outlet temperature automatically or manually recorded daily if operating. Excursions and any adjustments or made to the flare enclosed repairs combustor following an excursion shall be recorded in a log. f. Averaging Time Daily average for each condenser. Readings representative of the day (24 -hour period) will be collected (i.e., a minimum of 4 readings will be taken throughout the day at approximately 6 hour intervals). Readings are not required during periods of permitted downtime. Heat sensor will operate continuously and averaging will not be necessary. Hello