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Home My WebLink About20203790.tiff Enclosed Combustor COMB-1 Emissions Enterprise Compressor Station DCP Operating Company, LP Enclosed Combustor Fuel Usage 110 scf/hr Pilot Gas 1,148 BTU/SCF Fuel Heating Value 8,760 hr/yr Hours per Year 0.96 MMscf/yr Fuel Use 0.13 MMBtu/hr Fuel Use 1,106 MMBtu/yr Fuel Use Enclosed Combustor Waste Gas Flow Usage 1994 Btu/scf Still Vent Gas Heat Value 9.11 MMscf/yr Worst-case Still Vent Gas Flowrate 18163 MMBtu/yr Still Vent To Combustor 1105.8 MMBtu/yr Fuel Heat 18,163 MMBtu/yr Still Vent Heat 19,269 MMBTU/yr Combustion Emissions at COMB-1 EF Emissions lb/MMBtu ton/yr NOx 0.068 0.66 CO 0.31 2.99 AP-42 Table 13.5-1 2020-3790 Attachment E Facilitywide Emissions Inventory—Form APCD 102 Enterprise Compressor Station Form APCD-102 Colorado Department of Public Health and Environment Air Pollution Control Division j C D P H E } .x e, Facility Wide Emissions Inventory Form (. /b Vor.April.201.1 CO �"' Company Name,DCP Operating Company.It I3 Source Name:Enterprise Compressor Station 12 Source AIRS ID:123/0277 )realrolled Pulemial l4 Emil(PIE) Controlled Pole.).l to Emil(P(EI 1'tilert.ITPY) 11610 10600 Crilrria 1T0141 11APi(130yr) AIa5444 Eau)niont Deseriplion 13y P0119 P411.5 502 NO, Vol' CO IICIto I Are1O Acro 02 1,0 00 5,) 0-Her Mel, 224-IMP TIP 1,110 P2823 502 NO3 VIE CO WOO Aerial Arra 02 Tal En TO pollen Mob 224TMP 121/0277/051 EngmeC.2(47840 I 17 I05 105_ (042 8570 2"2.424 I.1(0 108) 425 86 54 _ 105 105 105 2415 i 5.445 474 540 162 47 5 10 2771 On INI 526 � 1200277;050 Engine 8 29570.005 I 05 (05 006 24170 21082 0570 2442_4 1,757 1.081 0_S 5377 100 105 105 0 1157 24011 , 2742 5485 050 540 462 43 5 19 260 12,or7/1556 Eneme.(.2001(06 105 010, 24181 21001 85.70 27,44144 1757 1.031 625 86 9 105 105 105 4'_2400 2742 5,445 474 43 19 _ 20) 1200:%'7.070 !(noun C-214.1'-014 105 It1.5 105 t4(42 2(1(43 8;711 27,444 (.752 1031 10 .10 107 10,5 1 05 0 00 2470 2400 2742 5,445 975 • 5 (0 00 12124477:071 0,00,,C217 130 155 155 5 12111 1201 12574 50(70 _,94 1595 IIg5 127 14 57 7.6 155 15 153 0115 37111 1201 1658 7.116 1347 117 J 364 123;0277'0,8 D-51106L)I,(d TLGDehe 40700 4441 23(84+1 90,123 54.747 _ 427 14.455 11,670 217-2542 1578 1`040:01907,4('und0n,e4,54845 2554 -4616 _.,04 1,4 11,43 1128 — 31 115, 8 95 246 .21.772,040 0O16xi.bai8edl'5ndena8te',ruck 1.08074 1428 _ 11 71 123:02774774 COMB-I (/0:0 _99 066 44 . Permine9004ren 500102,)- STS 5.75 5.75 031 528.64 1,742.12 47132 146.204 9624 5,917 245,123 289,202 7,826 91,028 39.671 2,878 0 .5.7S 5.75 ,75 0.34 12064 163.25-144.26 24.255 4.812 2,959 16,918 13,970 2551 2,733 1,424 1.439 0 APE,Only-Perati,Enroll Sonora 1 Y I _ r v1 - APENC 'sobtolal- 0,0 00 0.0 0.0 0.0 0 0.0 0 0 0 u 0 0 0 0 Inh 0. 0 0 0.11 0.0 0.0 0,0 0,0 0.0 0.0 I 0 0 0 0 a 0 0 0 0 0 APES Eonnpt 1Im Vnlrie.nl yo ueea ' 1,9(44(0010160nms 14 20 III I4 _ Ili - 1 - _ _ _ 1 I 1 1 1 _ _ f 1 haipariannt Sebum! an - au_ au • 0.0 1.4 2.0 IT 0 0 0 0 ; 0 0 0 0 0 4 0.0 0.0 0,0 0.0 IA ' 2.0 13 1 0 0 0 0 0 0 0 0 0 0 Tote',All Source,a I 5.8 I 5.8 I 5.8 I 0.3 1 130.0 I I7M.1 1472.8 146,274 I 9,624 I 5,917 1243,123 1 28,32021 7.8261 98,0281 39,6710 2,874 1 0 15.8 I 5.8 I 5,8 I(13 1120.0 1165.3 1 150.5 I 29,281 1 4,312 I 2,909 I 10918 113,970 1 241 12.733 11,824 I 1,439.1 0 1:.5nalr,ll,4 ION Soarmar)(TPYI-I 73.1 I 4.8 I 3,0 I 122.6 I 144.6 I 39 I 49,0 I 19.8 I 4.4 I 0.) I I'.4..80ed 11AP.Surnm0171 0 091-I 14.11 I 2.4 I 1.0 1 8.5 I 7.0 I 0.1 I IA I 0.9 I 0,7 I o..0 rneonlr011ed 070101,an 024',lots,-I 422.3 1 Controlled'I 0401,All(IAP,(TM-I 37.' I Footnotes: I.This form should tse completed to Include both esisting sources mid all proposed new or modifications lo edsung emissmns sources 2 If the 77.331003 310040 I6 0055 then 0,7(0,"proposed"under the Permit No and AIRS ID data columns 1.((Al'abhievluhrinv include D7.=Benzene 224-rm.=2?4-T nmethylpemmne Tut-Toluene Are4al-Acetaldehyde ED=Fthylliesnone Aar°"Acrnlnin , Xyl=Nylene n-Hex=01)01anr 11(11(1-Formaldehyde Meth=Methanol 4 APFN Exempt/Insignificant Sources should he included Alen 5larran(ed company N6mn 1/26/2018 Page 1 of 1 Attachment F Updated O&M Plan—D-2 Enterprise Compressor Station * COPHE COLORADO CO Air Pollution Control Division Form APCD-302 E� Deoar rub!;c H-3itri oi110Cnl Air Pollution Control Division Operating and Maintenance Plan Template for Glycol Dehydration Systems • Ver. January 1, 2018 The Air Pollution Control Division (Division) developed this Operating and Maintenance Plan (O&M Plan) for glycol dehydration systems that use emissions controls, permitted at synthetic minor and major oil and gas facilities in the State of Colorado. An O&M Plan shall be submitted with the permit application when required. One O&M Plan may be used for multiple dehydrators at one facility if each are controlled and monitored in the same manner. If the OEM Plan template is completed correctly, the Division will approve the O&M Plan and a construction permit will be issued with the requirement to follow the O&M Plan as submitted. If the template is not completed correctly, the Division will work with the operator to make corrections. Once a construction permit is issued, the facility operator must comply with the requirements of the OEM Plan upon commencement of operation. An existing approved O&M Plan may be modified without a permit modification or permit reissuance, but the operator must adhere to the requirements of the existing approved OEM Plan until an approval letter is issued for the new O&M Plan. The operator is required to use the Division-developed OEM 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 aim 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: January 2018 Section 1 - Source Identification For new permits, some of this information (i.e., Facility AIRS ID, Permit Number, and AIRS Point ID) may not be known at the time of application. Please only fill in the fields that are known and leave the others blank_ Company Name: DCP Operating Company, LP Facility Location: Weld County Enterprise Compressor Facility Name: Station Facility AIRS ID(for existing facilities) 123 -0277 Emission Units Covered by this OEM Form Facility Equipment ID D2 Permit Number(if known) 95OPWE103 AIRS Point ID (if known) 068 Glycol Type Used a TEG Equipped with Flash Tank? (Y/N) Y a Glycol types are Ethylene Glycol (EG), Diethylene Glycol (DEG), or Triethylene Glycol (TEG). APCD Internal Use Only Page 1 of 5 Approved? O Initial Date CDPHE COLORADO co a Air Pollution Control Division Dooaftni«-rJ of Pubic.Health&ErivilLnti Brit 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 O8M Plan for a period of five (5) years. If applicable state requirements or any Federal NSPS, NESHAP, or MACT require a longer record retention period, the operator must comply with the longest record retention requirement. Section 4 - Monitoring Requirements Control Equipment Information Table 1 below details the monitoring parameters and frequency for control equipment depending on the type of control equipment and the requested permitted emissions at the facility. Indicate the emissions control type(s) by checking the appropriate boxes. In addition, check the appropriate box for "Monitoring Frequency"based on the facility-wide permitted VOC emissions. Table 1 Emissions Control or Recycling Method . Monitoring Frequency parameter Flash ® Permitted n Permitted Still Tank Facility Emissions Facility Emissions Vent (if present) ≥ 80 tpy VOC < 80 tpy VOC Condenser b ® Condenser Outlet Weekly Monthly Temperature Pilot Light and Auto- Daily Weekly Enclosed Flare or igniter Monitoring Combustor Visible Emissions Observation e Daily Weekly Pilot Light and Auto- Elevated Open igniter Monitoring d Daily Weekly Flare` Visible Emissions Daily Weekly Observation Combustion Chamber Daily Weekly Thermal Oxidizer nEl Temperature Visible Emissions Daily Weekly Observation e Page 2 of 5 CDPHE COLORADO CO Air Pollution Control Division s De)al Health`a Env;Ur ,fr Table 1 Emissions Control or Recycling Method Monitoring Frequency Flash Parameter E Permitted n Permitted Still Tank Facility Emissions Facility Emissions Vent (if present) a 80 tpy VOC < 80 tpy VOC Vapor Recovery Monitoring requirements, including parameters and frequency, Unit(VRU)or ® to be determined by the operator and listed below, and Recycled or Closed approved by the Division Loop System g pp Routed to Reboiler Monitoring requirements, including parameters and frequency, Burner as Fuel n ❑ ❑ to be determined by the operator and listed below, and approved by the Division Monitoring requirements including specific parameters and Other ❑ 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 shall be: Table 2: Condenser Maximum Outlet Temperature ❑ 160 °F A maximum temperature greater than 160 °F requires approval from the Division. 140 °F 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 Page 3 of 5 CDPHE COLORADO CO Air Pollution Control Division of Pub!!,-Hea!Ui&Eovi,;rrne'd combustion device for the presence or absence of smoke (e.g., visible emissions). If smoke is observed during the visible emissions inspection, the operator has the option to either (1) immediately shut-in the equipment to investigate the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed; or (2) conduct a formal Method 22 observation to determine whether visible emissions (as defined per Regulation No. 7, Section XVII.A.16.) are present. If a Method 22 is conducted, the record of the observations shall be maintained as required in Section 3 of this OItM 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. i 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 OENM Plan. g Vapor Recovery Unit (VRU)or Recycled or Closed Loop System In the space provided below, please provide a description of the emission control system, including an explanation of parameters monitored, monitoring frequency, and how the system design ensures that emissions are being routed to the appropriate system at all times, or during all permitted runtime. Also, provide a description of how downtime is tracked and recorded. Attach additional pages if necessary. The VRU will route flash tank vapors back to the process. If the VRU is down, the flash tank emissions will be routed to atmosphere (1% or 88 hours). DCP will record the hours of VRU downtime. VRU downtime is defined as periods where the flash tank emissions are routed to the atmosphere instead of recycled to the inlet. Page 4 of 5 CDPHE COLORADO CO Air Pollution Control Division De oarU tort of Put,' Health D F.-rvi ortrr,nl 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&M Activities Please use this section to describe any additional notes or operation and maintenance activities, or if additional space is needed from a previous section. Attach additional pages if necessary. The enclosed combustor (COMB-1) used for still vent control has a 2.25%annual downtime (197 hours)for maintenance and malfunctions, during which times still vent emissions will be directed to the atmosphere. COMB-1 Runtime status will be tracked on at least a daily basis to determine COMB-1 downtime. COMB-1 downtime is defined as periods when emissions from the still vent are routed to the atmosphere instead of to COMB-1. If unit D-2 is down in addition to either the VRU or COMB-1, this does not constitute downtime as no emissions are being produced. Page 5 of 5 Attachment G Proposed Title V Permit Condition Updates—D-2 (AIRS 068)and COMB-I (AIRS 074) Enterprise Compressor Station SECTION II- Specific Permit Terms 3. D-2 -Triethylene Glycol Regeneration Unit Permit Compliance Monitoring Condition Emission Parameter Number Compliance Limits Factor Method Interval VOC 3.1 D2:33.27 tons/year Based on Input Parametric Monthly to GI YCaIc IlAPs Individual:8.0 tons/year Model Total:20.0 tons/year Extended Gas 3.1.3 EPA Reference Annually Analysis x ,.Y. Methods Hours of Operation 3.2 Recordkeeping Monthly Gas Processed 3.3 D2:40.150 MMscf/year Flow Meter Continuous Glycol Flow Rate 3.4 D2:35 gallons/mini Recordkeeping Monthly Control System 3.5 95%reduction See Condition 3.5 Compliance 3.6 ' ,; See Condition 9 Assurance Monitoring MACT Subpart HH 3.7 f,x See Condition 3.7 Area Source .. Requirements MACT Subpart A 3.8 See Condition 3.8 Construction 3.9 See Condition 3.9 Requirements 3.1.2 Flash gas emissions shall be vented back into the process at all times, resulting in zero emissions from the flash tank. A maximum period of 4-3S hour:, 88 hours (5.0% 1.0`/u annual downtime) is reserved for malfunctions and maintenance on the VRU. All flash gas emissions will be routed to enclosed combustor COM1B 1 atmosphere during periods of VRU downtime. Requested Condition — The owner or operator shall monitor and record VRU downtime. VRU downtime shall be defined as times when the flash tank gas is routed to the enclosed combustor atmosphere. The total hours of downtime and volume of gas processed during VRU downtime shall be recorded on a monthly basis and used to calculate actual emissions to demonstrate compliance with the emission limits contained in this permit. it 6. Comb-1 —Dehy Combustor Permit Monitoring Condition Compliance Parameter Number Compliance Limits Emission Factor Method Interval NOx 7.1 t4 0.7 tons/yr 0.068 lb/MMBtu Recordkeeping and Pvionth12. calculation CO 244 3.0 tons/yr u 0.31 lh/MMBtu 12 month rolling total Control Requirements 7.3 95%destruction See Condition 7.3 IState-only] Enclosed 7.4 No visible emissions EPA Method 22 Daily combustor Opacity Pilot Flame 7.5 Present at all times Thermocouple Continuous 6.5 The enclosed combustor shall be operated at all times when emissions are routed to it, except for a maximum annual downtime period of 263 hours 197 hours (3,0% 2.25%, annual downtime) for malfunctions and maintenance. The enclosed combustor shall be operated with a pilot flame present at all times, except for these periods of downtime. The presence of a enclosed combustor pilot flame shall be monitored using a thermocouple or any other equivalent device to detect the presence of a flame. The device shall be equipped with an alarm to indicate no ignition of the pilot flame. Records of the times and duration of all periods of pilot flame outages, and estimated emissions shall be maintained and made available to the Division upon request. 20,% CDPHE Glycol Dehydration Unit APEN - Form APCD-202 Air Pollutant Emission Notice (APEN) and CO s'er Application for Construction Permit Alt sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged on additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for Glycol Dehydration(Dehy)Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition,the General APEN (Form APCD-200)is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division(APCD)website at: www.colorado.Qov/cdphe/aped. 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: 95OPWE103 AIRS ID Number: 123 / 0277 / 068 [Leave blank unless APCD has already assigned a permit a and AIRS ID] Company equipment Identification: D-2 [Provide Facility Equipment ID to identify how this eq,iipment is referenced within your organization] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SW Sec. 30, T2N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 E-Mail Address=: rshankaran@dcpmidstream.com 'Please use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. Permits,exemption letters,and any processing invoices will be issued by APCD via e-mail to the address provided. 374127 a COLORADO Form APCD-2O2 - Gtycol Dehydration Unit APEN Revision 02/2017 1 I Lam`. Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 068 [Leave btank un.ess APCD has already ass; ned a permit M and ALPS ID] Section 2- Requested Action ❑ NEW permit OR newly-reported emission source -OR- Q MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment ❑ Change company name O Add point to existing permit 0 Change permit limit ❑ Transfer of ownership' ❑ 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: Reduce VRU downtime from 5.0% to 1.0%, vent to atm. Reduce ECD downtime from 3.0% to 2.25% +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: D-2 For existing sources, operation began on: 1 / 11 /2001 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 0 Yes O No area Is this unit located at a stationary source that is considered a 0 Yes O No Major Source of(HAP)Emissions LOLORA DO 2 Form APCD 22 Giycat Dehydration Unit APED Revision 0%12017 Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 068 [Leave blank unless_APCD has alr=edy ass,rned a perms and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: Forum Model Number: Custom Unit Dehydrator Serial Custom Unit Reboiler Rating: 2.5 MMBTU/hr Number: ❑ Ethylene Glycol ❑ DiEthylene Glycol TriEthylene Glycol Glycol Used: (EG) (DEG) (TEG) Glycol Pump Drive: ❑ Electric ❑ Gas If Gas,injection pump ratio: Acfm/gpm Pump Make and Model: Rotor Tech GS22 1 2 #of pumps: 1 Glycol Recirculation rate(gal/min): Max: 35 • Requested: 35 Lean Glycol Water Content: 1.5 Wt.% Design Capacity: 110 MMSCF/day Dehydrator Gas Throughput: Requested: 40,150 MMSCF/year Actual: 29829 MMSCF/year Inlet Gas: Pressure: 950 psig Temperature: 120 F Water Content: Wet Gas: lb/MMSCF D Saturated Dry gas: 7.0 lb/MMSCF Flash Tank: Pressure: 50 psig Temperature: 130 'F O NA Cold Separator: Pressure: psig Temperature: 'F 0 NA Stripping Gas: (check one) ID None O Flash Gas O Dry Gas O Nitrogen Flow Rate: scfm Additional Required Information: Q Attach a Process Flow Diagram El Attach GRI-GLYCaIc 4.0 Input Report a Aggregate Report(or equivalent simulation report/test results) Ej Attach the extended gas analysis(including BTEX a n-Hexane, temperature,and pressure) p COLORADO Form APCD 202 Gtycot Dehydration Unit APEN - Revision 02/2017 3 I Z� Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 068 [Leave blan'unless APCD has atreadp ass,?n_c permit 4%and A_PS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 / -104.4877 Dischage:Height, Operator Temp. Flow Rate VelOclty_'" Above,Ground.Level Stack ID No, -. rr) (Ace ? (ft/sec) (Fast) COMB-1 25 Indicate the direction of the stack outlet: (check one) ❑r Upward ❑ Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) Circular Interior stack diameter(inches): 36 ❑Square/rectangle Interior stack width (inches): Interior stack depth(inches): ❑Other(describe): COLORADO Form APCD 202 Giycoi Dehydration Unit APEN Revision 02!2017 4 I A' Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 068 [Ledve blank unless APCD has atready assigned a permit r and AIRS ID] Section 6 - Control Device Information Used for control of: Still Vent stream Type: Make/Model: ❑r Condenser: Maximum Temp 140 Average Temp Requested Control Efficiency Used for control of: Flash Tank vent stream Size: Make/Model: • VRU: Requested Control Efficiency 99 % VRU Downtime or Bypassed 1 Used for control of: Still Vent stream Rating: MMBtu/hr Type: Enclosed Combustor Make/Model:Leed Single Stage 36 High Efficiency Combustor Combustion Requested Control Efficiency: 95 % Device: Manufacturer Guaranteed Control Efficiency 98 Minimum Temperature: Waste Gas Heat Content Btu/scf Constant Pilot Light: 0 Yes O No Pilot burner Rating MMBtu/hr Closed Used for control of: ❑ Loop Description: System: System Downtime Used for control of: ❑ Other: Description: Control Efficiency Requested ° During 1.0%annual downtime for the VRU used for Flash Tank vent control, emissions will vent to atmosphere. During 2.25%annual downtime for the enclosed combustor (COMB-1) used for Still Vent control, emissions will vent to atmosphere. COLORADO Form APCD-2O2 Glycol Dehydration Unit APErI Revision 02/2017 5 I [il COLORADO O Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 068 [Leave bunk unless APCD has elf,ady assigned a permit C and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes 0 No If yes, please describe the control equipment AND state the overall control efficiency(%reduction): Overall Requested Control Pollutant Control Equipment Description Efficiency (%reduction in emissions) PM SO, NO, CO VOC Enclosed Combustor(COMB-1) 95% HAPs Enclosed Combustor(COMB-1) 95% Other: From what year is the following reported actual annual emissions data? 2017 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Emission Re uested Annual Permit Uncontrolled Emission Factor Actual Annual Emissions " Pollutant Emission Factor Source fmfission timit{s, Factor Units (Ap-42, Uncontrolled Controlled5 Uncontrolled Controlled Mfg.etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) PM SO, NO, CO VOC 43.19 lb/MMscf GLYCaIc 292.27 3.22 867.00 33.27 Benzene 5.96 Ib/MMscf GLYCaIc 40.42 0.70 119.72 7.18 Toluene 7.13 Ib/MMscf GLYCaIc 58.38 0.51 143.21 6.81 Ethylbenzene 0.19 lb/MMscf GLYCaIc 1.74 0.01 3.81 0.11 Xylenes 2.39 lb/MMscf GLYCaIc 26.63 0.08 48.06 1.27 n-Hexane 0.87 lb/MMscf GLYCaIc 6.53 0.09 17.37 0.79 2,2,4- Trimethylpentane 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. COLORADO Form APCD 202 Glycc Dehydration Unit APEI Revision 02'2017 6 I '_ COLORADO rD', Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 068 [Leave blank unless APCD has already assigned a permit 4 and AIRS ID] Section 8 - Applicant Certification I hereby certify that alt information contained herein and information submitted with this application is complete, true and correct. 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: I] Draft permit prior to issuance ❑D 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: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692-3175 or(303)692-3148 APCD-SS-B 1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver,CO 8O246-1530 https://www.colorado.gov/cdphe/apcd Make check payable to: Colorado Department of Public Health and Environment Telephone: (303)692-3150 pp COLORADO Form APCD-2O2 Glycol Dehydration Unit APEN - Revision 02/2017 7 CDPHE General APEN - Form APCD-200 CO ; ' Air Pollutant Emission Notice (APEN) and ��`c� Application for Construction Permit AU 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. There may be a more specific APEN for your source(e.g. paint booths, mining operations, engines, etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD)website at: www.colorado.gov/cdphe/aped. 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: 95OPWE103 AIRS ID Number: 123 /0277 /074 Et Pave uf,iess APED ha,already assr3-wJ a permit c ai!d AIRS`D Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location: SW Sec. 30, T2N, R63W Site Location Weld County: NAICS or SIC Code: 4922 Wailing Address: 370 17th Street, Suite 2500 (Include Zip Code) Denver, CO 80202 Permit Contact: Roshini Shankaran Phone Number: 303-605-2039 Portable Source E-Mail Address2: rshankaran@dcpmidstream.com Home Base: Use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on alt documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices wilt be issued by APCD via e-mail to the address provided. 374128 Wly COLORADO porn APCD 200 - General APEN - Re=vision 1/2017 1 j Permit Number: 95OPWE103 AIRS ID Number: 123 /0277 /074 [Leave blank unless APCD has alreae+y ass,?ned a permit a and.AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly-reported emission source(check one below) ❑ STATIONARY source 0 PORTABLE source -OR- Q MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment 0 Change company name ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership3 ❑ Other(describe below) -OR • APEN submittal for update only(Blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info&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: Combustion device for TEG still vent control Manufacturer: Leed Model No.: L30-0018-00 Serial No.: Company equipment Identification No. (optional): COMB-1 For existing sources, operation began on: 4/11/2016 For new or reconstructed sources, the projected start-up date is: 0 Check this box if operating hours are 8,76O hours per year; if.fewer, fill out the fields below: Normal Hours of Source Operation: hours/day days/week weeks/year Seasonal use percentage: Dec-Feb: Mar-May: Jun-Aug: Sep-Nov: COLORADO Form APCD-200 - General APEN - Revision 1/2017 2 AV ,-,,=_.,_m,me, Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 074 [Leave blan.,unless APCD has already assigned a permd `anon AIRS ID] Section 4 - Processing/Manufacturing Information a Material Use p Check box if this information is not applicable to source or process From what year is the actual annual amount? Design Process Actual Annual Requested Annual Description Rate Amount Permit Limit4 (Specify Units) (Specify Units) (Specify Units) Material Consumption: Finished Product(s): 4 Requested values will become permit limitations. Requested limit(s)should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.1910 / -104.4877 ❑Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Qperator t)ischarge yeight , '` G iund Level Temp. Flow-Rate V ocity Stack ID do a #above lr Feet) r acrm) (fttsec) COMB-1 25 Indicate the direction of the stack outlet: (check one) El Upward 0 Downward 0 Upward with obstructing raincap ❑ Horizontal O Other(describe): Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter(inches): 36 ❑Square/rectangle Interior stack width (inches): Interior stack depth(inches): ❑Other(describe): Form APCD-20O General A77COLORADO rAPB td Revision t!20l 7 3 1 Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 074 [Leave blank unless APED has already ass"-fined a permit=and AIRS ID] Section 6 - Combustion Equipment Ft Fuel Consumption Information 0 Check box if this information is not applicable to the source (e.g. there is no fuel-burning equipment associated with this emission source) Design Input Rate Actual Annual Fuel Use Requested Annual Permit Limit4 (MMBTU/hr) (Specify Units) (Specify Units) 0.13 (Fuel Only) 2.70 MMscf/yr 10.07 MMscf/yr(waste gas+fuel) From what year is the actual annual fuel use data? 2017 Indicate the type of fuel used5: ❑Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑Q Field Natural Gas Heating value: 1,148 BTU/SCF ❑Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑Coal Heating value: BTU/lb Ash Content: Sulfur Content: El Other(describe): Waste Gas Heating value(give units): 1 ,994 Btu/scf 4 Requested values will become permit limitations.Requested limit(s)should consider future process growth. s If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. Section 7 - Criteria Pollutant Emissions Information t C e to Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes No If yes, describe the control equipment AND state the overall control efficiency(%reduction): Pollutant Control Equipment Overall Collection Efficiency Overall Control Efficiency Description (%reduction in emissions) TSP(PM) PM10 PM2.5 SOX NO,, CO VOC Other: AV' COLORADO Form APCD-204 General APEN - Revision 1/2017 4 I Q3 CO hE AD Permit Number: 95OPWE103 AIRS ID Number: 123 /0277 /074 [Leave blank unless APCD has already assigned a permit»and AIRS ID) Section 7(continued) From what year is the following reported actual annual emissions data? 2017 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Emission Requested Annual Permit Uncontrolled Actual Annual Emissions Emission Factor Emission Limit(s) Factor Source (Specify Units) (A''42,Mfg. Uncontrolled Controlled6 Uncontrolled Controlled etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) TSP(PM) PM,o PM25 SO), NO„ 0.068lb/MMBtu AP-42 0.15 0.15 0.66 0.66 CO 0.31 lb/MMBtu AP-42 0.80 0.80 2.99 2.99 VOC Other: 4 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. Section 8 - Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP-hazardous air pollutant)emissions equal to or greater than ❑Yes rQ No 250 tbs/year? If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: Uncontrolled Uncontrolled Controlled CAS Chemical Overall Emission Emission Factor Actual Actual Numbers Name Control Factor Source Emissions Emissions6 Efficiency (AP-42,Mfg.etc) (specify units) (Ibs/year) (lbs/year) 6 Annual emission fees will be based on actual controlled emissions reported.If source has not yet started operating,leave blank. COLORADO Form APCD 200 General APEN Revision 1/2017 5 I Permit Number: 95OPWE103 AIRS ID Number: 123 /0277 / 074 [Leave biank unless APCD has already assigned a permit "and AIRS ID] Section 9 -Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. I 72(7?(4 Signature of Legally Authorized Person(not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name(print) Title Check the appropriate box to request a copy of the: 0 Draft permit prior to issuance Q 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 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: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303)692-3150 �j COLORADO Form APCD-2OO GeneralAPE1I Revision 1/2017 6 Li]`. DO INFO TO SUPPORT 1/29/2018 Modification c RCVD 11/13/2020 DCP Midstream P 95OPWE103 370 17th Street,Suite 2500 Denver,CO 80202 Midstream. EJC 11/13/2020 303-605-2039 November 13, 2020 Delivered via Email Mrs. Elie Chavez Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B 1 Denver, CO 80246-1530 Re: DCP Operating Company,LP; Enterprise Compressor Station (123/0277) Title V Permit 95OPWE103 Minor Modification Cancellation Mrs. Chavez: DCP Operating Company, LP (DCP) is submitting this letter for the Enterprise Compressor Station, located in SWSW Section 30, Township 3N, Range 63W, Weld County, Colorado. DCP is requesting official cancellation of the Title V Minor Modification application submitted January 26, 2018 for Title V permit 95OPWE103. This minor modification application requested updates to unit D-2 (AIRS 068) and enclosed combustor COMB-1 (AIRS 074). However, these changes have since been superseded by more recent applications. If you have any questions or require any additional information regarding this request,please feel free to contact me at (303) 605-2039 or rshankaran@dcpmidstream.com. Sincerely, DCP Operating Company,LP ("1 Roshini Shankaran Senior Environmental Engineer 11/2O/2O18 Minor Modification Application DCP Midstream 370 17th Street,Suite 2500 Den ver,r,CO 80202 Mu/stream 303-6(15-2039 November 19, 2018 Sent via UPS Tracking#: 1Z F46 915 02 9525 2478 Ms. Elie Schuchardt Colorado Department of Public Health and Environment C' L> Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-Bl NOV? 0 2019 Denver, CO 80246-1530 301; 11> Re: DCP Operating Company,LP; ��'' Enterprise Compressor Station (123/0277) Title V Operating Permit Minor Modification (95OPWE103) Natural Gas Compressor Engines (AIRS 053, 055,056,070, 071) Ms. Elie Shuchardt: DCP Operating Company, LP (DCP) is submitting the attached Title V minor modification application for the Enterprise Compressor Station, located in SWSW Section 30, Township 3N, Range 63W, Weld County, Colorado. DCP is requesting the changes detailed in this application to Title V Operating Permit 95OPWE103. A timely renewal application for this facility was submitted July 26, 2016. This renewal application is currently undergoing review with the state. Application History • July 26,2016—Title V Renewal and Minor Modification Application: DCP requested 5.0% annual downtime for the VRU used for emission control of D-2's flash tank, during which emissions vent to COMB-1. A 3.0% annual downtime for COMB-1 was also requested, during which D-2's still vent emissions vent to atmosphere. • January 26, 2018—Minor Modification Application: DCP requested removal of COMB-1 as the backup control device during VRU annual downtime.VRU downtime was decreased from 5.0% to 1.0%, and COMB-1 downtime was decreased from 3.0% to 2.25%. Other minor updates to the underlying GLYCalc properties for D2 were also requested. There were no overall changes in VOC emissions from D2 requested as part of this application, as increases due to the above changes in control were balanced out by reductions in control device downtime. DCP is withdrawing the January 26, 2018 minor modification application at this time. Additional details are provided in the Title V significant modification application for unit D2 that DCP is submitting alongside this minor modification. DCP is including this note to clarify why the facilitywide emissions detailed in the included Form APCD-102 have reverted back to those provided with the July 26, 2016 renewal application.' Summary of Changes • Compressor Engines C-238, C-235, C-236, C-234, C-237(AIRS 053, 055, 056, 070, 071) o Update the fuel use limits for all five 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 1,136.3 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-238, C-235, C-236, C-234 from 185.01 MMscf/yr to 206.10 MMscf/yr • Increase annual fuel use limits for engine C-237 from 273.08 MMscf/yr to 304.22 MMscf/yr Please find redlined operating permit conditions,reflecting the above changes to annual fuel use for these units included as Attachment F to this application. 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 (MMBM/yr) and resulting emission estimates will remain unchanged. o Updates to all five engine serial numbers,reflecting the various AOS permanent engine replacements that have occurred since the last issuance of operating permit 95OPWE103 in 2012, were requested in the combined renewal & minor modification application submitted July 26, 2016. DCP has only provided Title V redlines for the annual fuel use limitations changing with this application. Regulatory Analysis There is no change in underlying state or federal regulatory applicability due specifically to the requested changes in the annual fuel use limitations for these engines.DCP will continue to comply with all applicable state and federal regulatory requirements for these engines. Please note that the list of insignificant activities at this facility has been updated since the 2016 renewal application was submitted,and the estimated emissions for these activities have changed. An updated list of insignificant activities has been provided in the Title V significant modification application for D2. This Title V operating permit minor modification application includes the following attachments: A. Responsible Official Minor Modification Certification B. APEN Fees C. Updated APENs (C-238, C-235, C-236, C-234, C-237) D. Emission Calculations and Supporting Documentation E. Form APCD-102 F. Redlined Title V Operating Permit 95OPWE 103 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 RShankaran(a:DCPMidstream.com. Sincerely, DCP Operating Company, LP Roshini Shankaran Senior Environmental Engineer Enclosures Min Attachment A Responsible Official Minor Modification Certification Enterprise 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 l Signature of Responsible Official Date Attachment B APEN Fees-$955.65 Enterprise Compressor Station Attachment C APEN Forms C-238,C-235,C-236,C-234,C-237 Enterprise Compressor Station Attachment D Emission Calculations and Supporting Documentation Enterprise Compressor Station Engine Emission Calculations Enterprise Compressor Station DCP Operating Company,LP Caterpillar 03612S1 Engine C.2381P003 123(92771053 4 Stroke,Lean Bum Uni R00ng 3 590 Op ESFC 5 too bluPp.ar Maximum Heat Input 24 00 mm05014 Operating Schedule' 0 010,nr/il Pd-anent PIN 1 0.51 ba:iaci r Maximum Potenter Fuel Use- 20610 mmncia r Year Fuel Use Heat Value (MA1aci/yr) (6 0001) 405usdf 1446 1141 14 FebPoary 1218 1100 96 Mar<0 1127 1143 65 Apnl 776 111075 may 1144 1110 75 Juno 1180 1116 75 July 1262 109389 August 1250 113957 8e610ntbar 1198 1119.63 Ocgber 1165 107551 November 12.82 1075.81 060Omber 14.04 1975.61 144 31 11109 7 Crnerra Pollutant Emission Calculations Uncontrolled Controlled 1 Potential Coml301.< 'i<4,. E 4909On Factors Potential Ean ssiens 000$O nce Factors Emission Factors Emissions Factors e Pollutant (ton/yr) (IAIMM9tu) (00ny1) (tonyr) nbnlMew) l99ytl HOC 07'3105p-hr 2490 023 18.27 570*9.0r 24.00 023 18.25 CC. 25g110-Er 85.70 962 6525 08 Obly.hr 27.42 0.26 20.86 V0C' 02Ybhp-hr 219.82 — 2.01 16082 07 00l-r 24.0a 023 1626 PM. 9.99E-0315Anm0tu 186 990E-03 960 99➢5,030*nnmelu 185 00'0-03 0.86 SW' 588E04W7mm91u 0.062 588E-04 0847 588E-04WAnm861 6,082 586E-04 0.047 •Manulaclulefa emasidm 1acMs NOC=bpi hldrocar0arel Unn4,E4kd emacma factors tom bsmi..Leant m 8458.08 osu Des fmm.Wd2 0+x5623 Tama 32-2.11251 Non-Critoria Paperlabla Pollutant Calculations 009600bd Controlled Adam • - Uncontrolled Potential Uncontrolled Actual Control Potential Emimkals Emissions Emissions Efficiency Emisaio. Pollutant HAP Em&sl0n factors. Data source ti6yr) 11hyr) % 80/511 (8991) 1,1,2.2-TGVapl0roef6ano 0400E-051bhnm8N EPA 841 640 50% 420 320 1.1,2-Tn^hloroe6ane <3180-05159:10915 EPA 589 509 50% 3.34 255 I 1.1 Dic9Oroeman0 <2335-051b/mmete EPA 038 378 50% 0.18 189 I 1,2D0chicroelhane <238E-05lblmm9YU _ EPA 038 378 50% 018 189 12 DIGioropmpan0 <2.60E-051tNmmSre EPA 041 431 50% 020 215 i,3-Buteolene 280E-04m?mm8tu EPA 5613 4274 50% 2805 2137 1,0-01dtlorepapene <2.04E-05lbnun615 EPA 555 423 _ 50% 277 211 ,< < ue. .69 . .. i78T3 .,89020 ' .. .9.9043 .'. ' t 1980.6'0 4 .04 - __68%' OW 4a .a' ., < 1 E ., 1 _ 80480 ._ > . 491.45 i.'. 892,$4 0318on Tatacnbn4a <3157E-0515/mm01u EPA 7.72 588 50% 366 294 Cnlcmnancena <304E-05 ip?mm5tu EPA 639 487 50% 320 243 emfarm <285E-051b/mm8tu EPA 599 4.56 50% 300 228 E6y+baozma 2.48E-05WImmPtu EPA 521 3.97 50% 26' 1.98 Ernelme 01bromide <443E-0516/mm01u EPA 931 709 50% 4,00 355 Mooylarre CMando 200E-05 Wlmm6tu EPA 4.20 320 50% 210 180 Naphthalene 744E-0510/mm81u EPA 1584 1191 50% 782 5.95 PAN 289E-04 Ib/mm1W 21 EPA 5605 4306 60% 28.27 ,53 55^Nran0 <238E-05*590m010 EPA 498 378 50% 248 1.89 Toluene 4:08E-0416/mm0u EPA 8571 6531 50% 4289 3255 Wei ChIond0 <140E-0513.anm81u EPA 3.13 238 50% 157 119 %lenesnn p.0) 184E'04I001In810 EPA 3868 2945 50% 1934 14.73 TOTAL — <32034 <24402 <7790 <6937 °unccce lad em0000,tauten corn 4ya0ke.Lean-Win 148181 a<luno ft-TAP-42...p.;3.fan:3.2-2 1759} DCP 8penhn9 Company LP 9110'2018 Engine Emission Calculations Enterprise Compressor Station DCP Operating Company,LP Caterpillar 0351251 Engine C-2351P-005 12310277/055 4 Stroke,Lean Born Una Rating• 3 5°f hp 05F0. 3700 bi/,/ho-tit Maaenum Heat Input: 24,0 mnblolm Ope1Slif655500ule: S.750 hr/y0 FHV- 102 bt*401' Macmum fu.,U. 20610 mmscey, Year Fuel Use Host 3014.1 (t8Msetlyr) (etufscf5 /a00m5 1156 1141 14061 FNvary 1097 11004.5143 March 075 1/4354797 And - 457 11157468 Hey 11.17 11167406 Juno_ 8.81 1116 7438 210 124$ 1093.87508 001 12.00 1135 5733 £eplembal 1204 111003140 October 1030 107551094 140vg;lt0r 1280 1070010004 00<630er 1402 1075 01094 :..iitt‘V0204Wrt=4 12305 11097 Criteria Pollutant Emission Calculations OI....,.tiolle4 Connnfle0 Potential. Compliance Emies0n Factors Potential Emissions Compllanm factors Emission Factors Emissions Factors Pollutant (ton/yri llnrtemaml 1101068 (10Nyd. )lb540ntul {t %D:° OT 92h{rhr 24.00 023 1550 07 gmonP,hr 24.00 023 1-8515.51 CO' 255111p-hr 6070 082 05.47 08gkhp-hr 27.42 025 17:70 VOW' 5290131/1 210.62 201 13445 07 othphr 24.00 023 16.91 PM' 9.09E 03 15/mmelu 1.05 994E-03 0.08 998E-03 0/mmelu - 1.05 9.09E-03 - 0,33 SOz' 588.E-04 1h/1139)4 0,002 588E-34 0.040 5885.04 Ib/mm6tu 0.002, 5.38E-04 0.040 'Nan0 501er'e emissions 1soots/'njr s 015114/0 rbonst °Ul50100804 omission 1 11/S tram inkn.tee1 0,1481.0;an9mea I/5/<20 2.1hsMm'1.Ta1:,•3 221730, NomColeria.Reportable PoltuMnt Calculations Controlled Controlad Actual Unco0irotkd Potential Uncontrolled actual Control Potential Emissions E0%sla10 Emissions EO@l.noy Emissions Pollutant HAP Emission tasters° 0Am sovc, 10,1'1) Willi % 4Eh77 llti,T) 1.1,2,2Tem4chIaoethane <400E-05 X1633554 EPA 8.41 544 50% 420 212 1,1,2-1 bInsoethana 03.18E-05 ro/m:met, EPA 509 433 50% 8.34 218 1,1 Dichloroethane <2.20E-05 16,500815 EPA 035 321 50% 018 181 1,2 DIc5loroelhane 3238E-051Pd3n8os EPA 038 321 50% 0.14 181 126khloroprcpa110 s289E-0564/mmEtu EPA - 041 300 59% 020 1.03 1',3.6utsclume 2.87E-04 WmmoP, EPA 5913 3833 50% 2806 1815 1;3-Dichlcro•.,.-e 32.5.4E-05 iC!mmetu EPA 555 359 50% 277 180 Carta:Tetrad:222e 355'0 EPA 772 599 88' MIIIIEEallIll 3304E-00.10.18,0 EPA 539 614 ®®® <2 85E-03.lactrti8Va EPA 694 383 15111 300 1 94 Eth benzene 2.48E-05 llimmtiat EPA 521 3.37 261 1 69 =4 SSE-05 Rai et EPA 931 063 455 351 Meth- - 2WEDS a tnerei4 EPA 420 212 50% 2 19 1 30 ti,04/11sane 7.44E-05 Ibtomea, EPA 1504. 10.12 50% 732 - 005 PAN 288E-04!b/r,.m'c1u EPA 5855 0400 50% 2827 1830 Styrene c 2 33E-95 5/3m6tu EPA 498 321 00% 248 161 Toluene 408E-04 iWmmdtu EPA 8577 5551 00% 4289 27/0 6lna Chla00e e 149E-05;h/m30tu EPA 313 203 50% 157 1.01 Xstenesfrn p of 18400415/mm0tu EPA 38 es 2503 00% 10,84 1252 TOTAL — 332034 520742 37754 35040 oncost..6'm95Wfrtwo,Y5 h..4,35w.5,...5.55/45181.50104`100 AP-55 C.ww 3 14.32.2 0000; OCP 0po'slog Cancany.LP P/1012013 i Engine Emission Calculations Enterprise Compressor Station DCP Operating Company,LP Caterpillar 2361251 Engine C-236/P-006 123002771058 4 Stroke,Lean Bum • Unit Rating: 0.550 hp 0070 ' 0/)AuR4Nr rsnum Ma Heat tnent 24 0 mmbtulu Operating Sdxdula' 3 l04'57/yr FM(: , 12=btufscf Mennen Fusi Uwe 206 10 mmsc57,4 Year NM the Haat Venn (MMsct/yrl (Btt✓ec5 ..a^.uay 4.37 1141.14001 Fabnsa15 4.32 1100 90143 41ach (184 114304797 Anil 998 1110.7408 May 12,75 11187408 June 1153 11107406 Jul 12.80 108387506 A..141 1235 1120 5033 3401511<00 1213 1118.83149 Ocieber 11,03 1075 61994 November il 1243 1075 81094 Cinnamon 14.08 1075 61094 �etiew. "a`""I(3 12404 1109 7 Criteria Pollutant Emiss/on Calculations Uncantrull0 Controted 5#''K S r..F Pot''Ual Cen'Ftlunce .'.':ri fi d Emles)ort Factors P0(lsNal Emeslars Compfance Factcn 6M.,,;,, t*. n,< Endssmn factor. Ent oloelo Fins P81/otant ice) (ldMMetu) (tonlyt) (tloyr) , (90812 /) (l�yr) HOs° 0.7 gthp-hr 2460 023 1504 079bhn1x 2490 023 1562 CO" 2.5gbephr 05.00 082 85.08 089bf:phr 77.42 028 4798 00C" 5.2m/hp-hr 210.82 241 137.41 079b6Phr 2400 023 15.02 PM° 999E.0310/mm8tu 1.05 999E-03 0.80 9.95E40 oirmnntu 1.05 958E-03 008 i 50ae 588E-0a lo/nmBtu 0.002 588E-04 0.040 598E-04 Nammatu 0.082 I 5.88E-69 0.040 • nutac0:roes*ma faemra[WC=0900/1//lbU arbcen) i Ma Une010N148m3Man(acme horn 4.trdte.Leeftum(45L81nree /tam 0/'120hager37ap030.7,1/0: Non-Criteria Reportable Pollutant Calculations 0000,0044 Contoked Astral Uncontrolled Poten091 Uncontrolled Actual Control Potential Emissions Emissions Emisslona Efficiency Emissions Pollutant HAP Em§alon factors° Data Source I2s'ye) (agyn 5 (/.y4 11021) 1.1.2.2 Tanachktoemane 4400E-05 lbmrn010 EPA 841 543 50% 420 2.74 41,2-Tn<hbrosthane <318E-05 b/a/Btu EPA 8.89 4.38 50% 334 218 1.1 OchfortPatrAn. <2.30E{S i6/mm8/u EPA 0.38 323 50% 0.10 162 t 2 D0chbroethana <236E-05 09?mm89 EPA 038 323 50% 0.18 1 52 1.2 Dnhbropmpuee <2 09E-05 h/mniatu EPA 041 3.09 50% 020 104 l adn,5-b na 267E-04 Ib/mm8h EPA 5613 3658 50% 28.00 18.29 ' &Du KK <2O4E-05 1pmmetu EPA 555 382 50% 2.77 181 omen e ' 4.40E-08 ...,it, ETA .,5263 1tit5E0 ': 4; x.,,57274 .,. 'd4t. �4"�sa 't� �.�: *=C4`v.xk gz'1' #7'� 3£"t4 4,'.56,44,,,.../4,/,4,:,-- ,1.5.,,,...:-.[,-.,.` .4,4G0-43 10/04407 EPA:.., .. 00% +t'.% t.f :?'3/0,540.. 00/601 Tepaoh6Mde <367E-05 VineibSU EPA 7.72 503 50% 388 252 C.M0ebenlane <304E-005/mmblu EPA 038 417 50% 320 2.08 Cnfornromt <2.05E-0510/mmBtu EPA 595 3.91 50% 3.00 1.35 Ethy98ennone 2 4866blmm8N EPA 5.21 340 50% 281 170 Eth9xne 2001410 <4436631hmmON EPA 9.31 807 50% 408 303 1s<06/5 r72 r<.. y 0 084-/r' . ., ., _.._.._._....�—._..._ v._-1 2152349 .."T349104.8 a .lO`b :,,,A` ''a'r ?g.,;4s=,x 3.a3Ez�Rr°3- .- � <.?t.5•`$ 5.3 .,.,,, ,/{ szt,:e' :s Mo//yata C.Wsde 200E-05 i0mnBh4 _ EPA 4.20 274 80% .210 1.37 Naretterne 7.44E-05/6/2089 EPA 15.04 1019 50:% 782 510 PAH 200E-04 00/0009 EPA , 5655 30.00 50% 2821 1543- Styrene 4230E-051Wmm69 EPA 4.98 323 50% 248 1.62. Toluene 400E-041Nmmstu EPA 8577 5590 50% 4289 2755 Vinyl Clew. 4149E-05 m/mm90o EPA 513 2.04 50% 1.57 1 02 %yler05insp.o) 1.84E-04Iblmm5N EPA 3868 2521 50% 19.34 1201 TOTAL •. 432034 420888 47700 45082 oac,e0494/moan,'soave/rare 4abcke./,0000/0/8568)005000 loan Nd2.Claps 3.2.9.32-2.(75)0/ • DCP 20800109 Company_4P 0/11/2018 Engine Emission Calculations Enterprise Compressor Station OCP Operating Company,LP Caterpillar 0301251 Engine 0.2341P-018 123(02771070 4 Stroke,Lean Bum . Unit Rating. 3 462 hp SSEC -9,.,,5 rr.r r Marenem Heat Input: 24-0 8,55fiehr. Operating Schodule' e 113.1 new PI-5,/ '1/20 Veitcf 1Aaa0um Fuel Use 205.02 mmscnyr Year Fuel Use 1 Heat Value (MNIsoltyr) (81514#) January 12.46 1141.14 Feb< <' _ 11.15 1100996 March 10 05 1143.6. April 11.18 1114,75 Mao 1070 1119.75 J,Pe 10.90 111875 .IW1 12-5,- 1083.58 Au(tust. 12.26 1115.57 Sep:alnba- 11.87 1119.83 October 11.72, 1615.41 Novemter 1200 1075.81 Oatmeal- 04.02 107561 141.SP 1196.7 Crllerla Pollutant Emission Ca0uf0tiona Uncontrolled Controlled Potential Con-9000 a Emission Factors Potential Emission Compiktr¢a Fa:iws _ Emission Factors Emissions factors Pollutant - (1942]9 (itansela) (t0,27,) (100,7]) (td0aew) gniyr)= NC ' 0.7 9bha-nr 24.00 0.23 17.0 0 T 9Nhp-nr 14.00 0.21. 1759 CO' _.. 2 90M1p41r 65.70 0.82 - 53,07 0.877705-hr 27.42 028 20.48 YCC` 8.2 92n5-hr 2/0112 2:01 15736 0.7 oneho.le 24:00 0.23 17,00 PM° 990E-0315/mnetu 1.05 0.900.03 0.76 999E.03 t/rnmEtu 1.05 9.04E-03 0.70 , SO,' 5:885,0410/mmPN 0.062 588E-04 0.048 5.89E-041Gfmnatu 0.082 5,88E-04 0.046 annladur5e Sniwaions/0492 °Unool/co t,nissavl la:W'irora4-strike,Lean-bum(40,816,5565s taw/AP-42.Chap'.,3.T390173 475'41 Non-Criteria Reportable Pollutant Calculations Cantn,6ad Controlled Actual Uncontrolled Potential Uncontrolled Actual Control Potential Enyss1uns Emissions Emissions Efficiency Emissions Pollutant HAP Emission facto's' Data Sonece (sa'Or) (0✓Nr) % p3tyr). (542]3 1,1,2.2-Tetrachbroeitene 0404E-05>rtm000 EPA 8,41 8.28 50% 420 3.14 1,1,2-Tdchlaoalhame - <3.13E-05 bnmota EPA 509 499 50% 3.34 200 1,1 Dichlacettana 42.34E-05 7_155800 EPA 0.36 370 60% 018 1 es 1,2 Dlcnlor0ethane <2.36E-0511:mm0tu EPA 0.38 3.70 50% 5.18 1.85 1,2DkM1lwapropana <2.09E-05 IFmndtu EPA 041 4.22 50% 029 2.11 1,3-Butadiene 267E-041Gc+n5tu EPA 46.13 41.90 50% 2,306 20.95 1,3-Dch:c_ocropone e 264E+ iFm 5 'm9lu EPA 5 55 4.14 50% 277 207 ^ft- •4 EA, "an 3 M,, /ykl `w -5 2€ 9 ,-W, A sm _ 4/ r '1/1 �., ,cu .,c, . Carbon T :untie 438 05.5 2555,2 EPA 772 /70 51% 3EE 258 CM1349049iere 4304=-059,9mEIu EPA 039 4.77 50,5 320 2'30 Chfwciornl 4285E-07 latnmBw EPA 599 4.47 50% 3/A 2.29 Emyben8ene 2.48E-05 14mm8tu EPA 5 21 3.89 50% -281 1.55 Ethylene 12,11rDnkla 4443E-95 II6mmgh, EPA 931 6.05 50% 4336 348 a �2 `64/-? / 8 ,.T 4) 4714 1. /l /�, 't 'f,3 w okra i4 430 , .�.,.: i, ..aaxa t, '� „*49*1,.41-3,Y01,O,- ;:, .., y <00440 , -10 , Methylene Chief., 290E-050/rnman, EPA 4.20 314 09%.... 210 1 5 Naohmatmae 744E-0516/mmB1u EPA 1084 1188 '00% 782 5.54 PAH 2.59E0416tmmEl, EPA 5855 4221 50% 28.27 21.11 Styrene <236E-06 t9//mn0tu EPA 4.96 370 50% 2,48 1,85 TNuane 408E-0 F'rnmytu EPA 85.77 8403 50% 4280 3201 Ant Chkrtde 41 49E-05 lbimm5N EPA 3.13 2.34 50% 1.37 117 Xyknes?m.p.oi 1,04E-04 IINmnr0tu EPA 3808 28.88 50% 19.04 14:44 TOTAL., — X32034 023024 0.7700 35623 ..roxtrs-0o,1 en/ssor laumra.1mn14 sNdu-Lain-horn(4SL8)orglns loon,AP-42.Chaplar 3,T5N.32-2.(7'801 CCP Opertl a Company,lP 900/2018 i Engine Emission Calculations Enterprise Compressor Station OCP Operating Company,LP Caterpillar G3018 Engine C-237 123/0277/071 I 4 Stroke,Lean Bum Unit Rang 4.735 hp 8570 7481 btu/hp-hr < Maximum HeatOp.4: 354 mmblulM Cgerean9 8duduro 8 760 hr/yr 7110 1020 Wu( Ma0mum Fuel Use 304.22 mmscf/yr Year Fuel Use Heat Oak's (MMsceyr) (0244011 January 20.25 1141 14061 Fe4nlay 1830 1100 96143 March 1652 114364707 AM 1782 1110 7408 May 11.93 1110 7486 June 17.31 1118 7408 Jury 18.54 1093 87508 August 1824 1139 5733 September 1770 111053140 - 00100 r 17.12 107501094 November 19/5 107551094 D4cember 20.87 1075.81094 Criteria Pollutant Emission Calculations Uncontrolled Controlled Potential Compliance Emiaabn Fatten Pdontrel Emissions Comp9anoa F4dtas Emission Factors Emissions Factors Pollutant (109,14) (IMMemo) (tonty1) (oonlyr) (80MM6tu) ttonyr1 - NO<' 07 gbhp-hr 32.01 0.216 2445 0 7 gbhlNv 32.01 0 21 24.42 00' 26gbhp-hr 125.74 085 90.05 _ 0.8ybhp-hr 38.50 0298 USE 00:' 6.2 gbhp-hr 281.19 1 812 214.80 0 7 gbhp4v 32.51 0.21 24.42 PM' 990E-031Nmmelu 1.66 999E-03 1.18 9.92E-0081/0/08/u 1.56 9.99E-03 1.10 0050' 5080.041Wmmetu 0.001 588E-04 0.070 5.88E-048/mmelu 0.091 588E-04 0.070 •Manufacture's arnemns rectos 'Uncontrolled<nem.lectors from aaarke.Lawn ecn/4048/4900.ftum 84-02 C/op/e 3.Table 32-2.(7410r Non-Criteria Reportable Pollutant Calculations • • Controlled CpnLn®ed Ptluel Uncontrolled Potential Uncontrolled Actual Conb0/ 400000145 Enaalan Endsakns Ont Efficiency o/cns Effcie Emissions P0l0Wt HAP Emission factors` Data Solace 110/7) (917yr) % 7byr) Malt) 1.1.2,2-Tehach/a0e8lee <400505 lb/mmBlu EPA 0241 048 50% 5.2, 4.74 1,1.2-T ohior0etlae0e <318EE-0516/mmBer . EPA 987 754 50% 493 3.77 1,1 DChlaoelikane 0236E-051WmnBtu EPA 0.38 559 50% 9.18 2.80 1.2D5hblonthane 02.36E-05lblmmotu EPA 036 559 50% 018 280 1,2 D0hbrnprapate 42,80E-0516/mmON EPA 0.41 538 50% 020 3.19 1.3.00108ena 287E-04Iblmm8lu EPA 8285 0329 50% 4100 31.64 1.3-DCMaoprapmo 02.64E-0516/1nmON EPA 819 020 50% 4,10 3.13 avelakiettpfe 856lllelUti EPA 2684.16 •103Y#s `.erk 1207.68 11.43 8480080 L1004450r' 0 .: EPA 109447 .12.1.01'39 • .;:40% 707: 50921 Carbon Tetrat05rke <3.67E-05 lb/mmBN EPA 1140 8.71 50% 570 4.35 Chksobennsne <304E-0561/mmBtu EPA 943 721 50% 472 3.80 Chkadenn 02.85E-OS9Nmmeb, EPA 884 678 50% 442 338 ENylbemmne 2,48E-OSb/mmBbl EPA 770 568 50% 335 294 Ethylene Plbromide <4.43E-061b/mmB10 EPA 1375 10.50 50% 687 525 #, � ». , ..34:08314 .:191°% '.₹317,85 +. __ �.. ..t .."r tee,. € 770,50 . 711 , .4 358.96 w- .». Mo0,tole Ch/onde 2.00E-051Wmm81u EPA 821 474 60% - 310 237 Naphthalene 744E-05lblmm mu EPA 2309 1764 50% 1154 882 - '.. PAH 209E-0416/mmBN EPA 8347 8076 55% 41.74 3180 Styrene 02.36E-O516/mmBlu EPA 7.32 559 50% 3,66 280 , Toluene 408E-045Wmm Btu EPA 12860 00,71 50% 8330 4838 Vinyl Chortle <14904)5 lb/mmotu EPA 462 353 59% 231 177 Xylenes(m,p,o) 1.04E-04W/mmBN EPA 5710 43.62 50% 2855 21.81 TOTAL — 0 43387 <33157 <10714 0 8196 'unconverted emeann tactile from aneoke.Leanbum(45Lei nonce*nom 07.12 01,0 ter l 1ado32-2{740) PCP Operating Canpeny.LP 5/18/2/18 it Attachment E Form APCD-102 Enterprise Compressor Station Form APCD-102 C D P H E 4 s„,:::::,... ... ,-;,..;:r. Company Name: DC?Operating Compc CO ,'"-;',:/-3',---:'' 0, Source Name: Enterprise Compressor rti, Source AIRS ID: 123/0277 'otential to Emit(PTE) HA Ps(Ibs/yr) AIRS ID Equipment Description TSP PM10 PSi2.3al Acro BZ Tol EB Xyt n-lies Meth 224-TMP 053 Engine C-238 105 1 05 105 9 540 462 43 5 19 -- 263 -- 055 Engine C-235 1.05 1.05 I 05 5 540 402 43 5 19 -- 263 -- 056 Engine C-236 1 05 I.05 I.05'9 540 162 43 _ 19 - 203 - 063 P-013 Stabilized Condensate Tanks — -- — -- II 115 8 85 246 — — 066 P-016 Stabilized Condensate Truck Loadout -- — — - -- 4 5 0 1 28 - -- 068 D-2.110 NI.Alscrd TEG Dehy — — — - -- 15.453 14,315 220 2,559 1,610 -- - 070 Engine C-234 P-018 105 105 - 1 05'9 540 462 43 a 19 — 263 -- 071 Engine C-237 1.55 155 1.55 97 797 683 63 7 29 -- 388 -- 074 COMB-1 — — — — -- -- — , -- -- — -- Permitted Sources Subtotal= 5.75 5.75 5.7512 2,959 18,020 14.670 253 2.751 1.884 1,439 0 A PEN Only-Permit Exempt Sources APEN Only Subtotal= 0.0 0.0 0.0 1 0 0 0 0 0 0 0 0 APEN Exempt I Insignificant sources Insignificant Activities — -- — - — 54 — -- — 441 — -- r Insignificant Subtotal= 0.0 0.0 0.0 1 0 54 0 0 0 441 0 0 Total,All Sources=I 5.7 I 5.7 I 5.7 12 I 2,959 I 18,074 1 14,670 I 253 I 2,751 I 2,325 I 1,439 I 0 4 I 1.5 I 9.0 I 7.3 10.1 I 1.4 I 1.2 I 0.7 I 0.0 Footnotes: I This form should be completed to include both existing sources and all propost 2 If the emissions source is new then enter"proposed"under the Permit No and 3 HAP abbreviations include ,()_N1B-1, detailed in tite lisle V BZ=Benzene pp11CatIt�i1. Tol=Toluene EB=Ethylbenzene XyI=Xylene HCHO=Formaldehyde 4 APEN Exempt/Insignificant Sources should be included when warranted DCP Operating Company,LP Page 1 of 1 Attachment F Proposed Updates to Operating Permit 95OPWE103 Enterprise Compressor Station 1. C-238 -Caterpillar G3612 3550 HP Compressor Engine with oxidation catalyst C-235 - Caterpillar G3612 3550 HP Compressor Engine with oxidation catalyst C-236 -Caterpillar G3612 3550 HP Compressor Engine with oxidation catalyst P018- Caterpillar G3612 3550 HP Compressor Engine with oxidation catalyst NOTE:The following terms and conditions apply to each engine individually Permit Monitoring Condition Parameter Number Compliance Limits Emission Factor Method Interval NOx 1.1 24.00 tons/year 0.228 lb/MMBtu Recordkeeping& Monthly Calculation CO 27.42 tons/year 0.261 lb/MMBtu 12 month rolling VOC 1.2 24.00 tons/year 0.228 lb/MMBtu total Portable Monitoring 1.1.2 - " £ ' Flue Gas Analyzer Quarterly Natural Gas Consumption 1.3 185.01 206.10 _ Plant Fuel Meter Monthly million scf/year ' 12 month rolling total Btu Heat Content 1.4 } xx ASTM or other Semi-Annually €• gar Division Approved Method Operating Hours 1.5 Recordkeeping Monthly Opacity 1.6 Except as provided below,not to exceed 20% Fuel Restriction Only Natural Gas is Used During startup,not to exceed 30% Oxidation Catalyst 1.7 Recordkeeping Monthly NESHAP ZZZZ 1.8 P018 only:Reduce CO by 93%or 1,imit See Condition 1.8 HCHO emission to 14 ..mvd at 15%O2 NESHAP Subpart A 1.9 r • ` ' See Condition 1.9 '‘,4,1,•••• n w++rs itea Compliance Assurance 1.10 7 __ ` � See Condition 9 Monitoring t� � 2. C-237 -Caterpillar G3616 4735 HP Compressor Engine with oxidation catalyst Permit Monitoring Condition Compliance Parameter Number Limits Emission Factor Method Interval NOx 2.1 32.01 tons/year 0.206 Ib/MMBtu Recordkeeping& Monthly Calculation CO 36.58 tons/year 0.236 lb/MM Btu 1,2 month rolling total VOC 2.2 32.01 tons/year 0.206 Ib/MMBtu Portable Monitoring 2.1 2 Flue Gas Analyzer Quarterly Natural Gas Consumption 2.3 273 08 304.22 ;' Plant Fuel Meter Monthly MMscf/year f 12 month rolling total Btu Heat Content 2.4 k ASTM or other Semi-Annually Division Approved sat: Method +t s4 y Operating Hours 2 5 Recordkeeping Monthly Opacity 2.6 Except as provided below,not to Fuel Restriction Only Natural exceed 20% Gas is Used During startup,not to exceed 30% Oxidation Catalyst 2.7 -.-,tr:* ...;,*-,-4, 1t9.1•;,:„.. try -•• See Condition 2.7 [Federal-Only]NSPS 2.8 NOx- 1.0 g'hp-hr or 82 ppmvd* Performance Tests Every 8,760 Subpart 1JJJ CO-2.0 g/hp-hr or 270 ppmvd* hours of VOC-0.7 g/hp-hr or 60 ppmvd* operation or 3 years NESHAP Subpart ZZZZ 2.9 Reduce CO by 93%or Limit HCHO See Condition 2.9 emission to 14 ppmvd at 15%O, [Federal-Only]NSPS 2 10 ° s �* See Condition 2.10 Subpart A NESHAP Subpart A 2.11 M ` ' See Condition 2.11 Construction 2.12 See Condition 2.12 Requirements , x Compliance Assurance 2 13 See Condition 9 sr , r Monitoring 04 1p 1.° Spark Ignition Engine APEN vco• CDPHE ≤„ z� CO Form APCD-201 ? Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in Longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for spark ignition(e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e.g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source(e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-2OO)is available if the specialty APEN options do not meet your reporting needs.A list of all available APEN forms can be found on the Air Pollution Control Division(APCD)website at: www.colorado.00v/cdphe/aped. 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: 95OPWE103 AIRS ID Number: 123 /0277/053 (L��ai,e b unfess APCD has airead.,assigned a permit and ARS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30, T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 Portable Source E-Mail Address Z:Home Base: 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 wilt require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. 390476 Aviv COLORADO Form APCD 201 "a�,_zrl ignition Engine APEN - Revision 7'2018 1 I �� Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 053 anti ,CPC 1 t 3�_�!i .u' - l ,33 Gee r A R-IT 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$1,875 must be submitted along with the APEN filing fee. -OR- Q MODIFICATION to existing permit(check each box below that applies) Add point to existing ❑ Change fuel or equipment O Change company name O permit 0 Change permit limit O Transfer of ownerships 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 replacement6 Additional Info Et Notes: Revised Fuel Heat Value (FHV) used for fuel use limit calculations 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted. s For transfer of ownership,a completed Transfer of Ownership Certification Form(Form APCD-104)must be submitted. 6 This does not apply to General Permit GP02,as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? Yes If yes, provide the Company Equipment Identification No. C-238 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 2/27/2008 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) ❑✓ Yes 0 N Normatl iours,1yrlrce 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% COLOfADD Form APED =2 Sp:ir4!_ E. - e APEN Pin 7'2018 2 1 AV F� � I Permit Number: 95OPWE103 AIRS ID Number: 123 10277/ 053 rsaa'. APCD has a'ae 3., _ss,;led fee it ,gin_!APS ID! Section 4 - Engine Information Engine Function: O Primary and/or Peaking Power O Emergency(max. 500 hrs/year) 0 Compression ❑Pump Jack O Water Pump ❑Other: What is the maximum number of hours this engine will be used for emergency back-up power? 0 hours/year Engine Make: Caterpillar Engine Model: G3612 Serial Number': BKE00356 What is the maximum designed horsepower rating? 3,550 hp What is the maximum manufacturer's site-rating? 3,550 hp kW What is the engine Brake Specific Fuel Consumption at 100%Load? 6,760 BTU/hp-hr Engine Features: Cycle Type: O 2-Stroke 0 4-Stroke Combustion: 0 Lean Burn O Rich Burn Aspiration: O Natural Turbocharged Is this engine equipped with an Air/Fuel ratio controller(AFRC)? ❑Yes 0 No If yes, what type of AFRC is in use? ❑O2 Sensor(mV) ❑NOx Sensor(ppm) O Other: Is this engine equipped with a Low-NOx design? 0 Yes O No Engine Dates: What is the manufactured date of this engine? 12/01/2006 What date was this engine ordered? 2006 What is the date this engine was first located to Colorado? 2/27/2008 What is the date this engine was first placed in service/operation? 2/27/2008 What is the date this engine commenced construction? 2/27/2008 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: 'The serial number must be submitted if coverage under GP02 is requested. i COLORADO Form ;1PC D Z01 � .��ls i,r,i:ion Engine APEN Revision 7'2018 3 �, "�` Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 053 µ=CD-3,,il •)1y ass,n d a p,irmt a,i 4iRS Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 / -104.4877 Operator Discharge Height Temp. Flow Rate Velocity Above Ground Level Stack ID No. CP) (ACFM) (ft/sec) (feet) C-238 52.5 858 23,461 124 Indicate the direction of the Stack outlet: (check one) ✓❑Upward ❑Downward D Upward with obstructing raincap ❑Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) El Circular Interior stack diameter(inches): 24 ❑Square/Rectangle Interior stack diameter(inches): Interior stack depth (inches): ❑Other(describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100%Load Actual Annual Feet Use Requested Annual Permit Limits (SCF/hour) (MMSCF/year) (MMSCF/year) 23,527.5 144.31 206.10 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) El Landfill Gas Heating Value: BTU/scf El Other(describe): Residue Gas Heating Value(give units): 1,109.7 Btu/scf 8 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 9 If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. Pipeline Natural Gas fuel heat value (FHV) of 1,020 Btu/scf assumed for requested permit limit calculations. Residue Gas 11IV of 1,109,7 Btu/scf used for 2017 actual fuel use calculations. COLORADO Form A°cam __. ��_� E-51"" ��P�ti �s� r 7.2)I B 4 I �� Permit Number: 95OPWE103 AIRS ID Number: 123 10277/ 053 [L,,,v,bi-t,,;.,,,A,--,,APCD >: '.I AIRS.D[ Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form.The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑No If yes, describe the control equipment AND state the overall control efficiency(%reduction): Overall Requested Control Pollutant Primary Control Equipment Description Efficiency (%reduction in emissions) TSP(PM) • PM10 PM2.5 SOx NOx VOC Oxidation Catalyst 89% CO Oxidation Catalyst 68% Other: Oxidation Catalyst•HAPs Formaldehyde-80%.Other HAPs-50% Use the following tables to report criteria and non-criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Criteria Pollutant Emissions Inventory Emission Factor Actual Annual Emissions" Requested Annual Permit Emission Limit(s)8 Pollutant Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis Units (AP-42, Emissions Emissions Emissions Emissions Mfg.etc) (tons/year) (tons/year) (tons/year) (tons/year) TSP(PM) 9.99E-03 lb/MMBtu AP-42 0.80 0_80 1.05 1.05 PM10 9.99E-03 lb/MMBtu AP-42 0.80 0.80 1.05 1.05 PM2.5 9.99E-03 lb/MMBtu AP-42 0.80 0.80 1.05 1.05 SOx 5.88E-04 lb/MMBtu AP-42 0.05 0.05 0.06 0.06 NOx 0.228 lb/MMBtu Mfg. 18.25 18.25 24.00 24.00 VOC 0.228 lb/MMBtu Mfg. 160.52 18.25 210.82 24.00 CO 0.261 lb/MMBtu Mfg. 65.25 20.89 85.70 27.42 Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 D Yes ❑No lbs/year? If yes, please use the following table to report the non-criteria pollutant(HAP)emissions from source: Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions10 Abstract Chemical Name Source Uncontrolled Controlled Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions Number Basis Mfg.etc) (pounds/year) (pounds/year) Formaldehyde 50000 0.40 9/11)-0r Mtg. 20,880.83 4.176.17 Acetaldehyde 75070 8.36E-03 lb/MMBtu AP-42 1.338.15 669.07 Acrolein 107028 5.14E-03 Ib/MMBtu AP-42 822.74 411.37 Benzene 71432 4.40E-03 lb/MMBtu AP-42 704.29 352.14 Other: 67561-Methanol 2.50E-03 lb/MMBtu AP-42 400.16 200.08 6 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. Av COLORADO Farm APCD-2O1 Spark Ignition Engine APEta - Revision 7/20i8 5 I "fa,, Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 053 :)CD dv;i�i:1 ti pe!mit-;:u. ?, 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. 14\:4441)2/;.7"*. 10(104e 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: 0 Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type,etc.).See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with$191.13 and the General Permit For more information or assistance call: registration fee of$1,875, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692-3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www.colorado.govIcdpheiapcd AMIN COLORADO `orm _,`.fl v _0 Sp-erl. W ?ln��APFrJ t Revis m 712018 6 I Spark Ignition Engine APEN soy 2 o ia1e A CDPHE r CD CO tt Form APCD-201 Ptataiai ry %' Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates.An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for spark ignition (e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e.g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source(e.g.compression ignition engine, mining operations, asphalt plant,crusher,screen, etc.). In addition, the General APEN (Form APCD-200)is available if the specialty APEN options do not meet your reporting needs.A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at: www.cotorado.govlcdphe/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: 95OPWE103 AIRS ID Number: 123 /0277/055 [Leave b am u 't s ADC has al;•_a-y assi ,,ed 3 PeMilt arid Ai S ia] Section 1 -Administrative Information Company Name': DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30, T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 Portable Source E-Mail Address2 Home Base: rshankaran@dcpmidstream.com ' Use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. 390473 VW COLORADO Furor'P TD•201 Spark ignition Engine APEN Re,,siun 7-20 , 1 I Av., Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 055 l-2a',2 Li -mss APCE r.,al!= 7, a>,u , '1n 1 AtRS[D 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$1,875 must be submitted along with the APEN filing fee. -OR- D MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment O Change company name4 O Add point to existing permit O Change permit limit O Transfer of ownerships O Other(describe below) -OR- ❑ APEN submittal for update only(Blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- El APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario(AOS)permanent replacement° Additional Info a Notes: Revised Fuel Heat Value (FHV) used for fuel use limit calculations 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted. s For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. 6 This does not apply to General Permit GP02,as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? Yes If yes, provide the Company Equipment Identification No. C-235 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 1994 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.govicdphe/attainment) ✓❑Yes El No Normal Hours of.S9rirce Operation: 24 hours/day 7 days/week 52 weeks/year " ` Seasonal'Lite percentage: Dec-Feb: 25% Mar-May: 25% June-Aug: 25% Sept-Nov: 25% i=7-g. APEN 4 2 �� CO,e0,77 'ne - Rev, ['7,201, ">s Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 055 [Lew;' -t-t, ,=,-YC1D r-1 { 2u' 1�i AIRS IR, Section 4 - Engine Information Engine Function: O Primary and/or Peaking Power ❑Emergency(max. 500 hrs/year) ❑✓ Compression O Pump Jack O Water Pump O Other: What is the maximum number of hours this engine will be used for emergency back-up power? 0 hours/year Engine Make: Caterpillar Engine Model: G3612 Serial Number': 1YG00047 What is the maximum designed horsepower rating? 3,550 hp What is the maximum manufacturer's site-rating? 3,550 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 6,760 BTU/hp-hr Engine Features: Cycle Type: ❑2-Stroke 0 4-Stroke Combustion: Q Lean Burn O Rich Burn 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? ❑0z Sensor(mV) ❑NOx Sensor(ppm) O Other: Is this engine equipped with a Low-NOx design? 0 Yes O No Engine Dates: What is the manufactured date of this engine? 4/29/1994 What date was this engine ordered? < 1994 What is the date this engine was first located to Colorado? 9/30/1994 What is the date this engine was first placed in service/operation? 1994 What is the date this engine commenced construction? < 1994 What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? O Yes Q No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 'The serial number must be submitted if coverage under GP02 is requested. A � COLORADO Perm APCD 201 Spark Ignition Ensue APEN , �visicn 7 2013 3 I .431 H.a-tf 4 Erv=mrau.. Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 055 Imo ' i,k sn�-ass A?CG h is _ _J_t p.,i r r.:,3n,i _-I;Jf Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 1 -104.4877 Discharge Height Operator Temp. Flow Rate Velocity Above Ground Level Stack ID No. ( F) (ACFM) (ft/sec) (feet) P005 52.5 858 23,461 124 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward ❑Downward ❑Upward with obstructing raincap D Horizontal O Other(describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter(inches): 24 ❑Square/Rectangle Interior stack diameter(inches): Interior stack depth (inches): ❑Other(describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate®100%Load Actual Annual Fuel Use Requested Annual Permit Limit8 (SCF/hour) (MMSCFlyear) (MMSCF/year) 23,527.5 123.06 206.10 From what year is the actual annual amount? 2017 Indicate the type of fuel used9: 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 0 Other(describe): Residue Gas Heating Value(give units): 1,109.7 Btu/scf 8 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 9 If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. Pipeline Natural Gas fuel heat value (FHVj of 1.020 Btuscf assumed for requested permit limit calculations. Residue Gas FHV of 1,109.1 Btu'scf used for 2017 actual fuel use calculations. COLORADO r , : D Spar s� , Fi 7'E, Rer 3i:^, 7 L:118 4 " ,, • Permit Number: 95OPWE103 AIRS ID Number: 123 10277/ 055 p;I' i:�'' d '1-" r',R i ID] fLe''d��t7 blank ur „ - t 31;, ,��i�r �, -Section 7- Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form.The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ✓0 Yes 0 No if yes, describe the control equipment AND state the overall control efficiency(%reduction): Overall Requested Control Pollutant Primary Control Equipment Description Efficiency (%reduction in emissions) TSP(PM) PMio PM2.5 SOx NOx VOC Oxidation Catalyst 89% CO Oxidation Catalyst 68% Other: Oxidation Catalyst-HAPs Formaldehyde-80%.Other HAPs-50% Use the following tables to report criteria and non-criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Criteria Pollutant Emissions Inventory Emission Factor Actual Annual Emissions10 Requested Annual Permit Pollutant Emission Limit(s)e Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis Units (AP-42, Emissions Emissions Emissions Emissions Mfg.etc) (tons/year) (tons/year) (tons/year) (tons/year) TSP(PM) 9.99E-03 lb/MMBtu AP-42 0.68 0.68 1.05 1.05 PM10 9.99E-03 lb/MMBtu AP-42 0.68 0.68 1.05 1.05 PM 2.5 9.99E-03 lb/MMBtu AP-42 0.68 0.68 1.05 1.05 SOx 5.88E-04 lb/MMBlu AP-42 0.04 0.04 0.06 0.06 NOx 0.7 9/l1P-hr Mfg. 15.51 15.51 24.00 24.00 VOC 6.2 gRtp-hr Mfg. 136.45 15.51 210.82 _ 24.00 CO 2.5 g/hp-hr Mfg. 55.47 17.76 85.70 27.42 Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP - hazardous air pollutant)equal to or greater than 250 L✓ Yes ❑No lbs/year? If yes, please use the following table to report the non-criteria pollutant(HAP)emissions from source: Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions14 Abstract Chemical Name Source Uncontrolled Controlled Service(CAS) Uncontrolled Basis Units (AP-42, Emissions Emissions Number Mfg.etc) (pounds/year) (pounds/year) Formaldehyde 50000 0.40 g/hp-hr Mfg. 17,749.07 3,549.81 Acetaldehyde 75070 8.36E-03 lb/MMBtu AP-42 1.137.45 568.72 Acrolein 107028 5.14E-03 lb/MMBtu AP-42 699.34 349.67 Benzene 71432 4.40E-03 Ib/MMBtu AP-42 598.66 299.33 Other: 67561-Methanol 2.50E-03 lb/MMBtu AP-42 340.15 170.07 8 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. A® COLORADO Form APCD-201 Spark Ignition Fnt2ine APEN Revision 7'2018 5 Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 055 Wr k APCD n333-= 1 .. 1_ ,IRS,J] 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. I 1/19 /MN, 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: El Draft permit prior to issuance Q Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with$191.13 and the General Permit For more information or assistance call: registration fee of$1,875, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692-3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www.colorado.qov/cdphe/apcd VW COLORADO ' r�`L�. 20' Spark ��,��,`.�.�1 C( .7i�. APE kr=f 1(; 7 013 6 ati a.,n....... r , .. , „Ecovr,$) CDPHE Spark Ignition Engine APEN Nov 2 0 2018 Form APCD-201 COA c� • Air Pollutant Emission Notice (APEN) and ':rce' Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates.An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for spark ignition(e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e.g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source(e.g.compression ignition engine, mining operations, asphalt plant,crusher,screen, etc.). In addition, the General APEN(Form APCD-200)is available if the specialty APEN options do not meet your reporting needs.A list of all available APEN forms can be found on the Air Pollution Control Division(APCD)website at: www.colorado.govfcdphe/aped. 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: 95OPWE103 AIRS ID Number: 123 /0277/056 APCD:`a a.r assigned a permit=and AIRS ID] Section 1 -Administrative Information Company Name': DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30, T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 Portable Source Home Base: 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 the APCD via e-mail to the address provided. 390474 © COLORADO Form APCD 201 Spark I r=tion Erg ne APtN - R .run 7,2018 1 I A. Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 056 ACC,` .,c#, AT: ID; Section 2 - Requested Action ❑ NEW permit OR newly-reported emission source(check one below) ❑ STATIONARY source O PORTABLE source ❑ Request coverage under a Construction Permit O Request coverage under General Permit GP023(Natural Gas Only) If General Permit coverage is requested,the General Permit registration fee of$1,875 must be submitted along with the APEN filing fee. -OR- Q MODIFICATION to existing permit(check each box below that applies) ElChange fuel or equipment O Change company name ❑ Add point to existing permit 0 Change permit limit ❑ Transfer of ownerships O Other(describe below) -OR- ❑ APEN submittal for update only(Blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ID APEN submittal for permit-exempt/grandfathered source O Notification of Alternate Operating Scenario(AOS)permanent replacement6 Additional Info a Notes: Revised Fuel Heat Value (FHV) used for fuel use limit calculations 3 Only one engine may be reported per APEN for GP02 coverage.Coverage under GP02 is voluntary. 4 For company name change,a completed Company Name Change Certification Form(Form APCD-106)must be submitted. 5 For transfer of ownership,a completed Transfer of Ownership Certification Form(Form APCD-104)must be submitted. 6 This does not apply to General Permit GP02,as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? Yes If yes, provide the Company Equipment Identification No. C-236 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 1/01/1993 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://www.cotorado.gov/cdphe/attainment) ❑✓ Yes El No Normal Hours gff4uc-e 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% COLORADO Eor .,PCB 2)1 Sp la 1 uqr' Er, _ ',Pty, 3 2 1 La H ..,. ,... 1 Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 056 APCI _arravI7 2..s13 ' _L'=f�; i i_ ..c:J AIRS ID1 Section 4 - Engine Information Engine Function: ❑Primary and/or Peaking Power ❑Emergency(max. 500 hrs/year) Q Compression ❑Pump Jack O Water Pump ❑Other: What is the maximum number of hours this engine will,be used for emergency back-up power? 0 hours/year Engine Make: Caterpillar Engine Model: G3612 Serial Number': 1YG00028 What is the maximum designed horsepower rating? 3,550 hp What is the maximum manufacturer's site-rating? 3,550 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 6,760 BTU/hp-hr Engine Features: Cycle Type: ❑2-Stroke 0 4-Stroke Combustion: 0 Lean Burn O Rich Burn Aspiration: 0 Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller(AFRC)? ❑Yes 0 No If yes, what type of AFRC is in use? ❑O2 Sensor(mV) ❑NOx Sensor(ppm) O Other: Is this engine equipped with a Low-NOx design? 0 Yes ❑No Engine Dates: What is the manufactured date of this engine? 1/27/1993 What date was this engine ordered? < 1993 What is the date this engine was first located to Colorado? 5/19/1993 What is the date this engine was first placed in service/operation? 1993 What is the date this engine commenced construction? < 1993 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: 7 The serial number must be submitted if coverage under GP02 is requested. COLORADO Form APCC 201 Sp3rk I n r Erb r e„PE Bevis o,r 7:2018 3 IeV' Ni L „., Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 056 [.ea`., b_anP_n n',b, -1L'- .. =an Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 / -104.4877 Discharge Height Operator Temp. Flow Rate Velocity Above Ground Level Stack ID No. ('F) (ACFM) (ft/sec) (feet) P006 52.5 858 23,461 124 Indicate the direction of the Stack outlet: (check one) ✓❑Upward ❑Downward ❑Upward with obstructing raincap ❑Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter(inches): 24 ❑Square/Rectangle Interior stack diameter(inches): Interior stack depth (inches): ❑Other(describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100%Load Actual Annual Fuel Use Requested Annual Permit Limits (SCFlhour) (MMSCF/year) (MMSCF/year) 23,527.5 124.09 206.10 From what year is the actual annual amount? 2017 Indicate the type of fuel used9: Q Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) o 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): Residue Gas Heating Value(give units): 1,109.7 Btu/scf 8 Requested values will become permit Limitations. Requested limit(s)should consider future process growth. 9 If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. Pipeline Natural Gas fuel heat value (FHV) of 1,020 Btu!!scf assumed for requested permit limit calculations. Residue Gas F flV of 1,10977 litu/scf used for 2017 actual fuel use calculations. COLORADO F��i,i ,AP`i 2el Spark ;Tv-o, ' zCIS 4 I Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 056 [Lea,- hl ,G ,,,`n ha, '/3aion !.a permit ala .SRS 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? 2 Yes 0 No If yes,describe the control equipment AND state the overall control efficiency(%reduction): - Overall Requested Control Pollutant Primary Control Equipment Description Efficiency (%reduction in emissions) TSP(PM) PM 10 PM2.5 SOx NOx VOC Oxidation Catalyst 89% CO Oxidation Catalyst 68% Other: Oxidation Catalyst-HAPs Formaldehyde-80%.Other HAPs-50% Use the following tables to report criteria and non-criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Criteria Pollutant Emissions Inventory Emission Factor Actual Annual Emissions" Requested Annual Permit Emission Limit(s)8 Pollutant Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis Units (AP-42, Emissions Emissions Emissions Emissions Mfg.etc) (tons/year) (tons/year) (tons/year) (tons/year) TSP(PM) 9.99E-03 Ib/MMBtu AP-42 0.68 0.68 1.05 1.05 PM10 9.99E-03 lb/MMBlu AP-42 0.68 0.68 1.05 1.05 PM2.5 9.99E-03 lb/MMBtu AP-42 0.68 0.68 1.05 1.05 SOx 5.88E-04 Ib/MMBtu AP-42 0.04 0.04 0.06 0.06 NOx 0.7 g/hp-hr Mtg. 15.62 15.62 24.00 24.00 VOC 62 g/hp-hr Mfg. 137.41 1562 210.82 24.00 CO 2.5 yRtp-hr Mfg. 55.86 17.88 85.70 27.42 Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 0✓ Yes ❑No lbs/year? If yes, please use the following table to report the non-criteria pollutant(HAP)emissions from source: Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions') Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions Number Basis Mfg.etc) (pounds/year) (pounds/year) Formaldehyde 50000 0.40 gmp-hr Mfg. 17.874.36 3.574.87 Acetaldehyde 75070 8.36E-03 Ib/MMBtu AP-42 1.145.48 572.74 Acrolein 107028 5.14E-03 Ib/MMBtu AP-42 704.28 352.14 Benzene 71432 4.40E-03 Ib/MMBtu AP-42 602.88 301.44 Other: 67561-Methanol 2.50E-03 Ib/MMBtu AP-42 342.55 171.27 8 Requested values will become permit limitations.Requested limit(s)should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. COLORADO Form APCD-201 Spark i,r _ion Engle ADEN • Revision 7;20 Ig 5 1 Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 056 epe r7 _Id !DI 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. II/ICl /301g 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 El Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment,change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with$191.13 and the General Permit For more information o e or assistance call: registration fee of$1,875, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692.3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692-3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www.colorado.gov/cdphe/aped ,,r E ' - �qY COLORADO Fv r�� APCD 201 S .k I�n .i..�. ,� 722Q1Q 6 I Ali�:!li � � • $OV 2 0 1018 cDPHE Spark Ignition Engine APEN 11, Form APCD-201 ::, ,uorkary COAir Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for spark ignition (e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e.g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source(e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen,etc.). In addition, the General APEN (Form APCD-200)is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division(APCD)website at: www.colorado.gov/cdphe/aped. 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: 95OPWE103 AIRS ID Number: 123 /0277/070 :L ,ace bI ank unte ,APCD ,ir. ,a a g a r rit A 2 i0 Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30, T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 Portable Source •Home Base: 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 the APCD via e-mail to the address provided. 3904'72 COLORADO Form APCD-2O1 Spark Ignition Engine APEN - Revision 7 r'2013 1 I Q1C COLORADO D • Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 070 (_earl_h, .r___ __ APC_ tD:p. r 'c�n�i.,i 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$1,875 must be submitted along with the APEN filing fee. -OR- Q MODIFICATION to existing permit(check each box below that applies) 4 Add point to existing ID Change fuel or equipment 0 Change company name 0 permit ❑� Change permit limit ❑ Transfer of ownerships ❑ 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 replacement6 Additional Info Et Notes: Revised Fuel Heat Value (FHV) used for fuel use limit calculations 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change,a completed Company Name Change Certification Form(Form APCD-106)must be submitted. 5 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. 6 This does not apply to General Permit GP02,as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? Yes If yes, provide the Company Equipment Identification No. C-234 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 1994 For new or reconstructed sources, the projected start-up date is: Wilt this equipment be operated in any NAAQS nonattainment area? ❑ '(httpr/ yhkv,colorado.gov/cdphe/attainment) ✓ Yes 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% �� eo�os�oo Fvriilr-plr f�_... S�� r� i.l _ �_- __. 7 _e18 2 I Permit Number: 95OPWE103 AIRS ID Number: 123 10277/ 070 [Leave blank unttsss.APCD has at,e . l assio .3 .;:t,; rn1 iRs ID] Section 4 - Engine Information Engine Function: O Primary and/or Peaking Power ❑Emergency(max. 500 hrs/year) ❑✓ Compression ❑Pump Jack ❑Water Pump ❑Other: What is the maximum number of hours this engine will be used for emergency back-up power? 0 hours/year Engine Make: Caterpillar Engine Model: G3612 Serial Number7: 1YG00029 What is the maximum designed horsepower rating? 3,550 hp What is the maximum manufacturer's site-rating? 3,550 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 6,760 BTU/hp-hr Engine Features: Cycle Type: ❑2-Stroke Q 4-Stroke Combustion: ❑Lean Burn O Rich Burn Aspiration: ❑Natural ❑✓ Turbocharged Is this engine equipped with an Air/Fuel ratio controller(AFRC)? ❑Yes No If yes,what type of AFRC is in use? ❑02 Sensor(mV) ❑NOx Sensor(ppm) O Other: Is this engine equipped with a Low-NOx design? ✓❑Yes O No Engine Dates: What is the manufactured date of this engine? < 01/1993 What date was this engine ordered? < 01/1993 What is the date this engine was first located to Colorado? <01/1993 What is the date this engine was first placed in service/operation? < 01/1993 What is the date this engine commenced construction? <01/1993 What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑Yes Q No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested. COLORADO Form APCD-2v1 Spark Ignition Engine APEN • Revision 7201& 3 l , � �°°�^,e^,. 1 Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 070 [Lt - y C)r AiPS �2� Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 / -104.4877 Discharge Height Operator Temp. Flow Rate Velocity Above Ground Level Stack ID No. (-F) (ACFM) (ft/sec) (feet) P018 52.5 858 23,461 124 Indicate the direction of the Stack outlet: (check one) Upward O Downward O Upward with obstructing raincap ❑Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter(inches): 24 ❑Square/Rectangle Interior stack diameter (inches): Interior stack depth(inches): ❑Other(describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100%Load Actual Annual Fuel Use ,Requested Annual Permit Limits (SCF/hour) (MMSCF/year) (MMSCF/year) 23,527.5 141.56 206.10 From what year is the actual annual amount? 2017 Indicate the type of fuel used9: ❑✓ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑Field Natural Gas Heating value: BTU/scf o Propane (assumed fuel heating value of 2,300 BTU/scf) ❑Landfill Gas Heating Value: BTU/scf Other(describe): Residue Gas Heating Value(give units): 1,109.7 Btu/scf B Requested values will become permit limitations. Requested limit(s)should consider future process growth. 9 If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. Pipeline Natural Gas fuel heat value (FHA) of 1,020 Btu/scf assumed for requested permit limit calculations. Residue Gas FlIV of 1,1095 Btu;scf used for 2017 actual fuel use calculations. g� COLORADO Farm AFCD.2C1 S�� I � �u �r, 72318 4 I LEI Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 070 [Lea‘:e ba k un!,,ss AFC)hi-c, 711.-:,3'..7!? Alf? ID; Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form.The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑No If yes, describe the control equipment AND state the overall control efficiency(%reduction): Overall Requested Control Pollutant Primary Control Equipment Description Efficiency (%reduction in emissions) TSP(PM) PM10 PM2.5 SOx NOx VOC Oxidation Catalyst 89% CO Oxidation Catalyst 68% Other: Oxidation Catalyst-HAPs Formaldehyde-80%,Other HAPs-50% Use the following tables to report criteria and non-criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Criteria Pollutant Emissions Inventory Emission Factor Actual Annual Emissions" Requested Annual Permit Pollutant Emission Limit(s)8 Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis Units ' (AP-42, Emissions Emissions Emissions Emissions Mfg.etc) (tons/year) (tons/year) (tons/year) (tons/year) TSP(PM) 9.99E-03 lb/MMBtu AP-42 0.78 0.78 1.05 1.05 PM10 9.99E-03 lb/MMBtu AP-42 078 0.78 1.05 1.05 • PM2.5 9.99E-03 lb/MMBtu AP-42 0.78 0.78 1.05 1.05 SOx 5.88E-04 lb/MMBtu AP-42 0,05 0.05 0.06 0.06 NOx 0.7 Ib/MMBtu Mfg. 17.89 17.89 24.00 24.00 VOC 6.2 lb/MMBtu Mfg. 157.38 - 17.89 210.82 24.00 CO 2.5 lb/MMBtu Mfg. 63.97 20.48 85.70 27.42 Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 p✓ Yes O No lbs/year? If yes, please use the following table to report the non-criteria pollutant(HAP)emissions from source: Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions10 Abstract Chemical Name Source Uncontrolled Controlled Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions Number Basis Mfg.etc) (pounds/year) (pounds/year) Formaldehyde 50000 0.40 9/hP-h/ Mfg. 20,471.81 4,094.36 Acetaldehyde 75070 8.36E-03 Ib1MMBtu AP-42 1,311.94 655.97 Acrolein 107028 5.14E-03 lb/MMBtu AP-42 806.62 403.31 Benzene 71432 4.40E-03 lb/MMBtu AP-42 690.49 345.25 Other: 67561-Methanol 2.50E-03 lb/MMBtu AP-42 392.33 196.16 8 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. [� COLORADO Forth APCD-201 Spark Ignition Engine APEN - Rev'sion 7 20n8 Ql 5 I COLORADO Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 070 [Lf3a AIRS 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. 11 M/WIC 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: 0 Draft permit prior to issuance El Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.).See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of$1,875, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692-3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www.colorado.gov/cdphe/apcd �4V CC IORJ�DO f� .r APCD �'�' Sp _ c _ Kam. . „ 7 2v#8 6 � NpV ,�p1p16 CDPHE Spark Ignition Engine APENI, 41 LI CO Form APCD-201 ; .ovorY q Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for spark ignition(e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e.g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source(e.g.compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at: www.colorado.govlcdphe/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: 95OPWE103 AIRS ID Number: 123 /0277/071 APCD has a[ ad assigned a pernijt =and AiPS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30, T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran • Phone Number: 303-605-2039 Portable Source E-Mail Address2 Home Base: 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 the APCD via e-mail to the address provided. 390475 [W COLORADO Form APCD 201 Spark i n s Engine e APEN - Revision 7.2018 1 I M, "" , Permit Number: 95OPWE103 AIRS ID Number: 123 10277i 071 IDI 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 O Request coverage under General Permit GP023(Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of$1,875 must be submitted along with the APEN filing fee. -OR- (l MODIFICATION to existing permit(check each box below that applies) O Change fuel or equipment ❑ Change company name O Add point to existing permit p Change permit limit O Transfer of ownerships ❑ Other(describe below) -OR- ❑ APEN submittal for update only(Blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- El APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario(AOS)permanent replacement6 Additional Info Et Notes: Revised Fuel Heat Value (FHV) used for fuel use limit calculations 3 Only one engine may be reported per APEN for GP02 coverage.Coverage under GP02 is voluntary. 4 For company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted. s For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. 6 This does not apply to General Permit GP02,as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? Yes If yes, provide the Company Equipment Identification No. C-237 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 8/31/2012 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQ5 nonattainment area? Ej (http://www.colorado.gov/cdpheiattainment) Yes E]No Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year 00, Seasonal tis 1) tdentage: Dec-Feb: 25% Mar-May: 25% June-Aug: 25% Sept-Nov: 25% p COLORADO rm/.PCD-2O1 Span,, 15,n 1:1,)n)n i A E Vie, s- �n 7,%) 2 Q � Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 071 a,PCD has air assigned a permit and aiRS Section 4 - Engine Information Engine Function: O Primary and/or Peaking Power O Emergency(max. 500 hrs/year) ❑✓ Compression O Pump Jack ❑Water Pump O Other: What is the maximum number of hours this engine will be used for emergency back-up power? 0 hours/year Engine Make: Caterpillar Engine Model: G3616 Serial Number7: BLB00490 What is the maximum designed horsepower rating? 4,735 hp What is the maximum manufacturer's site-rating? 4,735 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,481 BTU/hp-hr Engine Features: Cycle Type: ❑2-Stroke 04-Stroke Combustion: Lean Burn O Rich Burn Aspiration: ❑Natural ✓❑Turbocharged Is this engine equipped with an Air/Fuel ratio controller(AFRC)? ❑Yes 0 No If yes, what type of AFRC is in use? O O2 Sensor(mV) ❑NOx Sensor(ppm) O Other: Is this engine equipped with a Low-NOx design? 0 Yes O No Engine Dates: What is the manufactured date of this engine? < 8/2012 What date was this engine ordered? < 8/2012 What is the date this engine was first located to Colorado? <8/2012 What is the date this engine was first placed in service/operation? 2012 What is the date this engine commenced construction? <8/2012 What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? O Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: The serial number must be submitted if coverage under GP02 is requested. �j COLORADO Form APCD-20 cF A°EN Revision 7;2018 3 I AV C.; "»`.,, Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 071 L._.. h 'C a r- p -,1 A P ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 / -104.4877 Operator Discharge Height P Temp, Flow Rate Velocity Above Ground Level- (fit)Stack ID No. (•F') (ACFM) (ft/sec) C-237 52.5 876 32,336 Indicate the direction of the Stack outlet: (check one) ✓❑Upward ❑Downward ❑Upward with obstructing raincap ❑Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter(inches): ❑Square/Rectangle Interior stack diameter(inches): Interior stack depth (inches): ❑Other(describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100%Load Actual Annual Fuel Use Requested Annual Permit Limits (SCF/hour) (MMSCF/year) • (MMSCF/year) 34,728.43 213.74 304.22 From what year is the actual annual amount? 2017 Indicate the type of fuel used9: 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): Residue Gas Heating Value(give units): 1,109.7 Btu/scf 8 Requested values will become permit limitations. Requested limit(s)should consider future process growth. • 9 If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. Pipeline Natural Gas fuel heat value (HIV) of 1,020 Btu/so-assumed for requested permit limit calculations. Residue Gas HI\' of 1,109.7 Btu%scf used for 2017 actual fuel use calculations. COLORADO Firm AFC-) Spa, =r F n 7 2018 4 I AV Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 071 r' . " ,PCDh,v, it,eddy aSil.-,,,ed?,oermIt d.iI.1 ivs Section 7 - Emissions Inventory Information Attach alt emission calculations and emission factor documentation to this APEN form.The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? 0 Yes O No If yes, describe the control equipment AND state the overall control efficiency(%reduction): Overall Requested Control Pollutant Primary Control Equipment Description Efficiency (%reduction in emissions) TSP(PM) PM10 PM2.5 SOx "NOx VOC Oxidation Catalyst 89% CO Oxidation Catalyst 71% Other: Oxidation Catalyst-HAPs Formaldehyde-80%,Other HAPs-50% Use the following tables to report criteria and non-criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Criteria Pollutant Emissions Inventory Requested Annual Permit Emission Factor Actual Annual Emissionst0 Emission Limit(s)8 Pollutant Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis Units (AP-42, Emissions Emissions Emissions Emissions Mfg.etc) (tons/year) (tons/year) (tons/year) (tons/year) TSP(PM) 9.99E-03 lb/MMBtu AP-42 118 1.18 1.55 1.55 PM 10 9.99E-03 Ib/MMBtu AP-42 1.18 1.18 1.55 1.55 PM 2.5 9.99E-03 Ib/MMBtu AP-42 1.18 1.18 1.55 1.55 SOx 5.88E-04 IbIMMBtu AP-42 0.07 0.07 0.09 0.09 NOx 0.7 g/hp-hr Mfg. 24.42 24.42 32.01 32.01 VOC 6.2 gthp-hr Mfg. 21480 24.42 281.19 32.01 CO 2.8 g/hp-hr Mfg. 96.05 27.97 125.74 36.58 Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 ❑✓ Yes O No lbs/year? If yes, please use the following table to report the non-criteria pollutant(HAP)emissions from source: Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissionst0 Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions Number Basis Mfg.etc) (pounds/year) (pounds/year) Formaldehyde 50000 ciao g/hp-hr Mfg. 27.94219 5.568.44 Acetaldehyde 75070 8.36E-03 Ib/MMBtu AP-42 1,981.66 990.83 Acrolein 107028 5.14E-03 Ib/MMBtu AP-42 1,218.39 609.20 Benzene 71432 4.40E-03 Ib/MMBtu AP-42 1,042.98 521.49 Other: 67561-Methanol 2.50E-03 Ib/MMBtu AP-42 592.60 296.30 8 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. Aver COLORADO Form APCD 20' Spark Iniior Engine APEN - Revision 712018 5 I Lll*V; 'srn."»":.. Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 071 2.DCD h3, ass≤ =d 3 remit AR S Di 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.t\-i4)4 • •C'' 11/ICI 120t% 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: El Draft permit prior to issuance Q Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of$1,875, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692-3150 Denver,CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www.colorado.Rov/cdpheiapcd AVIVCOLORADO Form APIs; 201 k 1,;m ti;i„ _ > APEd - Re isi:)n 7.`2015 6 ( Jai& of l-olio �oHE Spark Ignition Engine APEN A • Form APCD-201 CO Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for spark ignition(e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e.g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source(e.g. compression ignition engine,mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN(Form APCD-200)is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at:www.colorado.gov/cdphe/apcd. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment,change in fuel type,etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/053 [Leave blank unless APCD has already assigned a permit E and AIRS ID] Section 1 -Administrative Information Company Name': DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30, T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 Portable Source E-Mail AddressZ: rshankaran@dcpmidstream.com midstream.com Home Base: °� p ' Use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. 390476 Q COLORADO Form APCD-201 Spark Ignition Engine APEN - Revision 7/2018 1 I ,C� Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 053 f, • i =i!= t , a v= Hitt iil?.t A Ii.',_Jz 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$1,875 must be submitted along with the APEN filing fee. -OR- ✓❑ MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment O Change company name4 O Add point to existing permit 0 Change permit limit O Transfer of ownerships 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 o Notification of Alternate Operating Scenario(AOS) permanent replacement° Additional Info Et Notes: Revised Fuel Heat Value (FHV) used for fuel use limit calculations 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change,a completed Company Name Change Certification Form(Form APCD-106)must be submitted. s For transfer of ownership,a completed Transfer of Ownership Certification Form(Form APCD-104)must be submitted. 6 This does not apply to General Permit GP02,as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? Yes If yes, provide the Company Equipment Identification No. C-238 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 2/27/2008 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://www.cotoradiLgov/cdphelattainflleng ❑✓ Yes ❑No NormatHours gfESource 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% CD lt7R AR0 1=ttiln f1prf) 70? tt,ls1< I-, F) ,.Pi i, /11t718 2 Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 053 [Leave blank unless APCD has already assigned a permit:-7 and AIRS ID] Section 4 - Engine Information Engine Function: D Primary and/or Peaking Power O Emergency(max. 500 hrs/year) ✓❑Compression ❑Pump Jack ❑Water Pump ❑Other: What is the maximum number of hours this engine will be used for emergency back-up power? 0 hours/year Engine Make: Caterpillar Engine Model: G3612 Serial Number7: BKE00356 What is the maximum designed horsepower rating? 3,550 hp What is the maximum manufacturer's site-rating? 3,550 hp kW What is the engine Brake Specific Fuel Consumption at 100%Load? 6,760 BTU/hp-hr Engine Features: Cycle Type: ❑2-Stroke ❑✓ 4-Stroke Combustion: ❑✓ Lean Burn O Rich Burn Aspiration: ❑Natural ❑✓ Turbocharged Is this engine equipped with an Air/Fuel ratio controller(AFRC)? O Yes D No If yes, what type of AFRC is in use? ❑O2 Sensor(mV) ❑NOx Sensor(ppm) O Other: Is this engine equipped with a Low-NOx design? 0 Yes O No Engine Dates: What is the manufactured date of this engine? 12/01/2006 What date was this engine ordered? 2006 What is the date this engine was first located to Colorado? 2/27/2008 What is the date this engine was first placed in service/operation? 2/27/2008 What is the date this engine commenced construction? 2/27/2008 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: 7 The serial number must be submitted if coverage under GP02 is requested. COLORADO Form APCD-2O1 Spark Ignition Engine APEN - Revision 7/2018 3 I kiV H.atb Ery.n.n.rl Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 053 J i _ ,:Ar(1 IOU ,i: „S ID! Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 / -104.4877 Operator Discharge Height p Temp. Flow Rate Velocity Above Ground Level Stack ID No. (.F) (ACFM) (ft/sec) (feet) C-238 52.5 858 23,461 124 Indicate the direction of the Stack outlet: (check one) 0✓ Upward O Downward O Upward with obstructing raincap ❑Horizontal Other(describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter(inches): 24 O Square/Rectangle Interior stack diameter(inches): Interior stack depth (inches): O Other(describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate 100%Load Actual Annual Fuel Use Requested Annual Permit Limits (SCF/hour) (MMSCF/year) (MMSCF/year) 23,527.5 144.31 206.10 From what year is the actual annual amount? 2017 Indicate the type of fuel used9: 0 Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑Field Natural Gas Heating value: BTU/scf O Propane (assumed fuel heating value of 2,300 BTU/scf) O Landfill Gas Heating Value: BTU/scf 0 Other(describe): Residue Gas Heating Value(give units): 1,109.7 Btu/scf e Requested values will become permit limitations. Requested limit(s)should consider future process growth. 9 If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. Pipeline Natural Gas fuel heat value(FHV) of 1,020 Btu/scf assumed for requested permit limit calculations. Residue Gas PI-IV of 1,109.7 Btu/sct used for 2017 actual fuel use calculations. _ �qyy COLORADO I'UI1n FuP(r..2,-, +,'�i I` f �i I 71 l lull //)i)I,; 4 1 is Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 053 [Leave blank unless APCD has already assigned a permit 4 and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form.The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑No If yes, describe the control equipment AND state the overall control efficiency(%reduction): Overall Requested Control Pollutant Primary Control Equipment Description Efficiency (%reduction in emissions) TSP(PM) PM 10 PM2.5 SOx NOx VOC Oxidation Catalyst 89% CO Oxidation Catalyst 68% Other: Oxidation Catalyst-HAPs Formaldehyde-80%,Other HAPs-50% Use the following tables to report criteria and non-criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Criteria Pollutant Emissions Inventory Requested Annual Permit Emission Factor Actual Annual Emissions10 Emission Limit(s)8 Pollutant Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Units (AP-42, Emissions Emissions Emissions Emissions Basis Mfg.etc) (tons/year) (tons/year) (tons/year) (tons/year) TSP(PM) 9.99E-03 Ib/MMBtu AP-42 0.80 0.80 1.05 1.05 PM10 9.99E-03 Ib/MMBIu AP-42 0.80 0.80 1.05 1.05 PM2.5 9.99E-03 Ib/MMBtu AP-42 0.80 0.80 1.05 1.05 511 b Sox 5.88E-04 Ib/MMBtu AP-42 0.05 0.05 0.06 0.06 %V.• �I Q� NOx c�. .e228° Ib/MMStcr se hp-ix-Mfg. 18.25 18.25 24.00 24.00 \.•�-a O i , VOC 10.2 9223' 4b/MMeat•/iv-�1r Mfg. 160-52 18.25 210.82 24.00 CO 1,15 o.2,91 .lb/MMMBhe g/hp-w,Mfg. 65.25 20.89 85.70 27.42 Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 0 Yes 0 No lbs/year? If yes, please use the following table to report the non-criteria pollutant(HAP)emissions from source: Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions" Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions Number Basis Mfg.etc) (pounds/year) (pounds/year) Formaldehyde 50000 0.40 gmp-hr Mfg. 20,880.83 4,176.17 Acetaldehyde 75070 8.36E-03 Ib/MMBtu AP-42 1,338.15 669.07 Acrolein 107028 5.14E-03 Ib/MMBtu AP-42 822.74 411.37 Benzene 71432 ea.• II1yh1Metw .*P:4E' 40449. '962:1K' Other: 67561-Methanol 2.50E-03 Ib/MMBtu AP-42 400.16 200.08 / 'W /�, K o,! ti 8 Requested values will become permit limitations. Requested limit(s)should consider future process growth. )8 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. COLOADO Form APCD-201 Spark Ignition Engine APEN - Revision 7/2018 5 I V ` """`R � Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 053 k` : 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. l CI/fig 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 Q✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. • Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of$1,875, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692-3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https:I'www.colurado.gov/cdpherapcd 6 j eo i;-�.�iici� 71�Q(�� CDPHE Spark Ignition Engine APEN Nov 2 0 zone Form APCD-201CO 1. Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates.An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for spark ignition(e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e.g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source(e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN(Form APCD-200)is available if the specialty APEN options do not meet your reporting needs.A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at:www.colorado.gov/cdphe/aped. 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: 95OPWE103 AIRS ID Number: 123 /0277/055 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30, T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: (Intrude zip code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 Portable Source Home Base: E-Mail AddressZ: rshankaran@dcpmidstream.com l Use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. 390473 A W COLORADO Form APCD-201 Spark Ignition Engine APEN - Revision 7/2018 11 Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 055 df'CD I=1;dif A'R",!i�] 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 O Request coverage under General Permit GP023(Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of$1,875 must be submitted along with the APEN filing fee. -OR- ✓❑ MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment O Change company name4 O Add point to existing permit O Change permit limit ❑ Transfer of ownerships O Other(describe below) -OR- • APEN submittal for update only(Blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ID APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario(AOS)permanent replacement6 Additional Info a Notes: Revised Fuel Heat Value (FHV) used for fuel use limit calculations 3 Only one engine may be reported per APEN for GP02 coverage.Coverage under GP02 is voluntary. For company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted. 5 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. 6 This does not apply to General Permit GP02,as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? Yes If yes, provide the Company Equipment Identification No. C-235 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 1994 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? htt w//ww.colorado,00v/cd-he attainment ❑✓ Yes No Normal Hours of S rrce Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use per'centage: Dec-Feb: 25% Mar-May: 25% June-Aug: 25% Sept-Nov: 25% ar4 coloRADo 20I �I)dsI` Fil?IiIC/I' iI !(,i3 2 Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 055 [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 4 - Engine Information Engine Function: ❑Primary and/or Peaking Power ❑Emergency(max. 500 hrs/year) 0 Compression ❑Pump Jack O Water Pump ❑Other: What is the maximum number of hours this engine will be used for emergency back-up power? 0 hours/year Engine Make: Caterpillar Engine Model: G3612 Serial Number7: 1Y000047 What is the maximum designed horsepower rating? 3,550 hp What is the maximum manufacturer's site-rating? 3,550 hp kW What is the engine Brake Specific Fuel Consumption at 100%Load? 6,760 BTU/hp-hr Engine Features: Cycle Type: ❑2-Stroke 0 4-Stroke Combustion: Lean Burn O Rich Burn Aspiration: O Natural ❑✓ Turbocharged Is this engine equipped with an Air/Fuel ratio controller(AFRC)? ❑Yes 0 No If yes, what type of AFRC is in use? O 02 Sensor(mV) ❑NOx Sensor(ppm) O Other: Is this engine equipped with a Low-NOx design? 0 Yes O No Engine Dates: What is the manufactured date of this engine? 4/29/1994 What date was this engine ordered? < 1994 What is the date this engine was first located to Colorado? 9/30/1994 What is the date this engine was first placed in service/operation? 1994 What is the date this engine commenced construction? < 1994 What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? O Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested. Avr COIORAOO Form APCD 201 Spark Ignition Engine APEN Revision 7/20183 l f tE4E Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 055 Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 / -104.4877 Operator Discharge Height., p Temp. Flow Rate Velocity Stack ID Na, Above Ground Level (feet) (`F) (AGFM) (ft/sec) P005 52.5 858 23,461 124 Indicate the direction of the Stack outlet: (check one) ✓❑Upward O Downward ❑Upward with obstructing raincap O Horizontal O Other(describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter(inches): 24 ❑Square/Rectangle Interior stack diameter(inches): Interior stack depth(inches): ❑Other(describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate a 1OO%Load Actual Annual Fuel Use Requested Annual Permit Limit8 (SCF/hour) (MMSCF/year) (MMSCF(year) 23,527.5 123.06 206.10 From what year is the actual annual amount? 2017 Indicate the type of fuel used9: ✓❑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 0 Other(describe): Residue Gas Heating Value(give units): 1,109.7 Btu/scf 8 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 9 If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. Pipeline Natural Gas fuel heat value (Fl€V)of 1,020 Btu/scf assumed for requested permit limit calculations. Residue Gas pl-W of 1,1091 Btu/scf used for 2017 actual fuel use calculations, . COLORADO APCD 201 S0 O l9nnion En rn,ADM `;evi, in 7 7711P 4 I e4b,rc:r Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 055 [Leave blank unless APCD has already assigned a permit 7 and AIRS ID] Section 7- Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form.The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑No If yes,describe the control equipment AND state the overall control efficiency(%reduction): Overall Requested Control Pollutant Primary Control Equipment Description Efficiency (%reduction in emissions) TSP(PM) PMio PM2.5 SOx NOx VOC Oxidation Catalyst 89% CO Oxidation Catalyst 68% Other: Oxidation Catalyst-HAPS Formaldehyde-80%,Other HAPs-50% Use the following tables to report criteria and non-criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Criteria Pollutant Emissions inventory Emission Factor Actual Annual Emissions10 Requested Annual Permit Emission Lt(s) Pollutant $imi Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis Units (AP-42, Emissions Emissions Emissions Emissions Mfg.etc) (tons/year) (tons/year) (tons/year) (tons/year) TSP(PM) 9.99E-03 Ib/MMBIu AP-42 0.68 0.68 1.05 1.05 PM10 9.99E-03 Ib/MMBtu AP-42 0.68 0.68 1.05 1.05 PM2.5 9.99E-03 lb/MMBlu AP-42 0.68 0.68 1.05 1.05 SOX 5.88E-04 lb/MMBIu AP-42 0.04 0.04 0.06 0.06 NOx 0.7 gfip-hr Mfg. 15.51 15.51 24.00 24.00 VOC 6.2 g/hp-hr Mfg. 136.45 15.51 210.82 24.00 CO 2.5 g/hp-hr Mfg. 55.47 17.76 85.70 27.42 Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP-hazardous air pollutant)equal to or greater than 250 ❑✓ Yes O No lbs/year? If yes, please use the following table to report the non-criteria pollutant(HAP)emissions from source: Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions10 Abstract Chemical NameSource Uncontrolled Controlled Service(CAS) U ncontrolled Units (AP-42, Emissions Emissions Number Basis Mfg.etc) (pounds/year) (pounds/year) Formaldehyde 50000 0.40 g/hp-hr Mfg. 17,749.07 3,549.81 Acetaldehyde 75070 8.36E-03 lb/MMBtu AP-42 1,137.45 568.72 Acrolein 107028 5.14E-03 lb/MMBIu AP-42 699.34 349,67 �_ p Benzene 71432 9:3 G � ffs' Other: 67561-Methanol 2.50E-03 Ib/MMB ,yty>5tu AP-42 340.15 170.07 )A-letii .-t 3 Requested values will become permit limitations. Requested limit(s)should consider future process growth. i°Annual emissions fees wilt be based on actual controlled emissions reported. If source has not yet started operating,leave blank. ipirg COLORADO Form APCD-201 Spark Ignition Engine APEN - Revision 7/2018 5 I ``_" `°`";. �.nF�r Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 055 11 eav hirwk ti APO t + ',Apo Jod F I`S Hs): 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. ke-g&Or1/1 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$191.13 and the General Permit For more information or assistance call: registration fee of$1,875, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692-3150 Denver,CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https: Iwww.colorado.govicdphelapcd A,WA COLORADO F_'.:i APCD 201 Spark I It o �;; �l_ ?-`i f:'__ `' 6 I co Spark Ignition Engine APEN Nov 1 0 1010 441/4 44,• Form APCD-201 _ i natal' Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates.An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for spark ignition(e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e.g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source(e.g.compression ignition engine, mining operations, asphalt plant,crusher, screen, etc.). In addition, the General APEN(Form APCD-200)is available if the specialty APEN options do not meet your reporting needs.A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at: www.calorado.gov/cdohelapcd. 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: 95OPWE103 AIRS ID Number: 123 /0277/056 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 1 -Administrative Information Company Namet: DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30, T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: (Include zip code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 Portable Source E-Mail Address2: Home Base: 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 the APCD via e-mail to the address provided. 390474 COLORADO Form APCD 201 Spark I8nition Engine APEtI -Revisi©n 7/2O18 1 I Mk7i3F f��p Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 056 Section 2 - Requested Action ❑ 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$1,875 must be submitted along with the APEN filing fee. -OR- MODIFICATION to existing permit(check each box below that applies) Add point to existing O Change fuel or equipment O Change company name4 O permit El Change permit limit O Transfer of ownerships 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 replacement6 Additional Info&Notes: Revised Fuel Heat Value (FHV) used for fuel use limit calculations 3 Only one engine may be reported per APEN for GP02 coverage.Coverage under GP02 is voluntary. 4 For company name change,a completed Company Name Change Certification Form(Form APCD-106)must be submitted. s For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. 6 This does not apply to General Permit GP02,as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? Yes If yes, provide the Company Equipment Identification No. C-236 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 1/01/1993 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http_11 www,Colorado.Qovlcdphe'attainInernt) ✓❑Yes El No Normal Ho1irs qf(` rce 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% COLORADO E l.rr, ,�C I)-LQI Si,ar{. I�-il31o�, l,; ,,i ;, , 7,? 2 I Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 056 [Leave blank unless APCD has at ready assigned a permit 4 and AIRS ID] Section 4 - Engine Information Engine Function: ❑Primary and/or Peaking Power ❑Emergency(max. 500 hrs/year) ['Compression ❑Pump Jack O Water Pump O Other: What is the maximum number of hours this engine will be used for emergency back-up power? 0 hours/year Engine Make: Caterpillar Engine Model: G3612 Serial Number': 1YG00028 What is the maximum designed horsepower rating? 3,550 hp What is the maximum manufacturer's site-rating? 3,550 hp kW What is the engine Brake Specific Fuel Consumption at 100%Load? 6,760 BTU/hp-hr Engine Features: Cycle Type: ❑2-Stroke ❑✓ 4-Stroke Combustion: ✓❑Lean Burn O Rich Burn Aspiration: O Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller(AFRC)? O Yes El No If yes, what type of AFRC is in use? O O2 Sensor(mV) ❑NOx Sensor(ppm) O Other: Is this engine equipped with a Low-NOx design? El Yes O No Engine Dates: What is the manufactured date of this engine? 1/27/1993 What date was this engine ordered? < 1993 What is the date this engine was first located to Colorado? 5/19/1993 What is the date this engine was first placed in service/operation? 1993 What is the date this engine commenced construction? < 1993 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: 7 The serial number must be submitted if coverage under GP02 is requested. COLORADO Form APCD-201 Spark Ignition Engine APEPi-Revision 7/2018 3 I coVr � �s Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 056 r Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 / -104.4877 Operator Discharge Height Temp, Flow Rate Velocity stack ID No. Above Ground Level (feet) (.F) (AcfM) l ft /sec) P006 52.5 858 23,461 124 Indicate the direction of the Stack outlet: (check one) ✓(�Upward D Downward ❑Upward with obstructing raincap O Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) D Circular Interior stack diameter(inches): 24 Square/Rectangle Interior stack diameter(inches): Interior stack depth(inches): O Other(describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100%Load Actual Annual Fuel Use Requested Annual Permit Limit$ (SCF/hour) (MMSCF/year) (MMSCF/year); 23,527.5 124.09 206.10 From what year is the actual annual amount? 2017 Indicate the type of fuel used9: ✓Q 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): Residue Gas Heating Value(give units): 1,109.7 Btu/scf a Requested values will become permit limitations. Requested limit(s)should consider future process growth. 9 If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. Pipeline Natural Gas fuel heat value(F1-IV)of h020 Btu/sef assumed for requested permit limit calculations. Residue Gas FHV of 1,109.7 Btu/set-used for 2017 actual fuel use calculations. COLORADO us+it:\':'t.il 201 Spai1 In ea-F.t = ; 1 r, I 4 F.> Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 056 [Leave blank unless APCD has already assigned a permit 4 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 D No If yes, describe the control equipment AND state the overall control efficiency(%reduction): • Overall Requested Control Pollutant Primary Control Equipment Description Efficiency (%reduction in emissions) TSP(PM) PM10 PM2.5 SOx NOx VOC Oxidation Catalyst 89% CO Oxidation Catalyst 68% Other: Oxidation Catalyst-HAPs Formaldehyde-80%,Other HAPs-50% Use the following tables to report criteria and non-criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Criteria Pollutant Emissions Inventory Requested Annual Permit Emission Factor Actual Annual Emissions1° Emission Limit(s)8 Pollutant Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Basis Units (AP-42, Emissions Emissions Emissions Emissions Mfg.etc) (tons/year) (tons/year) (tons/year) (tons/year) TSP(PM) 9.99E-03 Ib/MMBtu AP-42 0.68 0.68 1.05 1.05 PM10 9.99E-03 lb/MMBtu AP-42 0.68 0.68 1.05 1.05 PM2.5 9.99E-03 tb/MMBtu AP-42 0.68 0.68 1.05 1.05 SOx 5.88E-04 ib/MMBtu AP-42 0.04 0.04 0.06 0.06 NOx 0.7 glhp-hr Mfg. 15.62 15.62 24.00 24.00 VOC 6.2 g/hp-hr Mfg. 137.41 15.62 210.82 24.00 CO 2.5 glhp-hr Mfg. 55.86 17.88 85.70 27.42 Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 0 Yes O No lbs/year? If yes, please use the following table to report the non-criteria pollutant(HAP)emissions from source: Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissionst° Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions Number Basis Mfg.etc) (pounds/year) (pounds/year) Formaldehyde 50000 0.40 g/hp-hr Mfg. 17,874.36 3,574.87 Acetaldehyde 75070 8.36E-03 lb/MMBlu AP-42 1,145.48 572.74 Acrolein 107028 5.14E-03 Ib/MMBlu AP-42 704.28 352.14 v per Benzene 71432 •'r.4oE-tr3 -ttr/MMstu .AP-4a -602..88- ..901-.44,4- �p Other: 67561-Methanol 2.50E-03 Ib/MMBlu AP-42 342.55 171,27 ewi14I `h/y,ed PIG 8 Requested values will become permit limitations.Requested limit(s)should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. - • AV COLORADO Form APCD-201 Spark Ignition Engine APEN - Revision 7/2018 5 I :�,«r ' `,, Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 056 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. • 11(ICI fa fig 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: 0 Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of$1,875, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692-3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https:i/www.colorado.govcdphe%aped E06RADD Form AP(D ?01 )pttrl< I��ur i � �,�_ U`H ;, , ,n 1:)()I36 0 C NV 2 0 2010 caPHE Spark Ignition Engine APEN Al-CD� ,-� Form APCD-201 ,.0.CO Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates.An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for spark ignition(e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e.g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source(e.g.compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN(Form APCD-200)is available if the specialty APEN options do not meet your reporting needs.A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at: www,colorado.aov/cdphe/aped. 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: 95OPWE103 AIRS ID Number: 123 /0277/070 (Leave blank unless APCD has all assigned a permit 4.and AIRS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30, T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: (Include Zip code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 Portable Source Home Base: E-Mail Address 2: rshankaran@dcpmidstream.com ' Use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. 3904"72 COLOR ADO Form APCD-2O1 Spark Ignition Engine APEN Revision 7/2018 1 I �� 1 " "°%t, Permit Number: 95OPWE1 03 AIRS ID Number: 123 /0277/ 070 / xss9, - i, . d!iIAia5!DI Section 2 - Requested Action ❑ NEW permit OR newly-reported emission source(check one below) ❑ STATIONARY source O PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023(Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of$1,875 must be submitted along with the APEN filing fee. -OR- Q MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment O Change company name4 O Add point to existing permit O Change permit limit O Transfer of ownerships O Other(describe below) -OR- ❑ APEN submittal for update only(Blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- (2 APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario(AOS)permanent replacement6 Additional Info It Notes: Revised Fuel Heat Value (FHV) used for fuel use limit calculations 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change,a completed Company Name Change Certification Form(Form APCD-106)must be submitted. 5 For transfer of ownership,a completed Transfer of Ownership Certification Form(Form APCD-104)must be submitted. 6 This does not apply to General Permit GP02,as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? Yes If yes, provide the Company Equipment Identification No. C-234 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 1994 For new or reconstructed sources, the projected start-up date is: Wilt this,equipment be operated in any NAAQS nonattainment area? (hrtp://,v i r,catorado.gov t dphe.attainment) ❑✓ Yes 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% cotos.soo Form APC0 201 - Spar{ 1;r1 ;t =i n 7//I)I l 2 Ss< Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 070 [Leave blank unless APCD has already assigned a permit and AIRS ID] Section 4 - Engine Information Engine Function: O Primary and/or Peaking Power O Emergency(max. 500 hrs/year) 0 Compression ❑Pump Jack ❑Water Pump O Other: What is the maximum number of hours this engine will be used for emergency back-up power? 0 hours/year Engine Make: Caterpillar Engine Model: G3612 Serial Number7: 1YG00029 What is the maximum designed horsepower rating? 3,550 hp What is the maximum manufacturer's site-rating? 3,550 hp kW What is the engine Brake Specific Fuel Consumption at 100%Load? 6,760 BTU/hp-hr Engine Features: Cycle Type: ❑2-Stroke ❑✓ 4-Stroke Combustion: ❑✓ Lean Burn ❑Rich Burn Aspiration: O Natural ❑✓ Turbocharged Is this engine equipped with an Air/Fuel ratio controller(AFRC)? ❑Yes ❑✓ No If yes,what type of AFRC is in use? O O2 Sensor(mV) ❑NOx Sensor(ppm) ❑Other: Is this engine equipped with a Low-NOx design? ❑✓ Yes O No Engine Dates: What is the manufactured date of this engine? < 01/1993 What date was this engine ordered? <01/1993 What is the date this engine was first located to Colorado? <01/1993 What is the date this engine was first placed in service/operation? <01/1993 What is the date this engine commenced construction? < 01/1993 What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? O Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested. COLORADO Form APCD-201 Spark Ignition Engine APEN - Revision 7/2018 3 In " ` , Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 070 r , ._ � 5:1 Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 / -104.4877 Operator Discharge Height p Temp. Flow Rate Velocity Stack ID No. Above Ground Level (feet) ('F) w(ACFM) (ft/sec) P018 52.5 858 23,461 124 Indicate the direction of the Stack outlet: (check one) ✓❑Upward ❑Downward ❑Upward with obstructing raincap O Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) Q Circular Interior stack diameter(inches): 24 ❑Square/Rectangle Interior stack diameter(inches): Interior stack depth (inches): ❑Other(describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100%Load Actual Annual Fuel Use Requested Annual Permit Limits (SCF/hour) (MMSCF/year) (MMSCF/year) 23,527.5 141.56 206.10 From what year is the actual annual amount? 2017 Indicate the type of fuel used9: p Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑Field Natural Gas Heating value: BTU/scf O Propane (assumed fuel heating value of 2,300 BTU/scf) ❑Landfill Gas Heating Value: BTU/scf 0 Other(describe): Residue Gas Heating Value(give units): 1,109.7 Btutscf s Requested values will become permit limitations. Requested limit(s)should consider future process growth. 9 If fuel heating value is different than the listed assumed value,provide this information in the"Other"field. Pipeline Natural (3as fuel heat value(FHV) of 1,020 13tu/scf assumed for requested permit limit calculations. Residue(sas I°fIV of 1,109.7 Btu/set'used for 2017 actual ittel use calculations. COLOBd00 Font,t\"CD.2(I S t.I i; 7/7013 4 I F,w , Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 070 [Leave blank unless APCD has already assigned a permit r,.. 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): Overall Requested Control Pollutant Primary Control Equipment Description Efficiency (%reduction in emissions) TSP(PM) PM10 PM2.5 SOx NOx VOC Oxidation Catalyst 89% CO Oxidation Catalyst 68% Other: Oxidation Catalyst-HAPs Formaldehyde-80%,Other I-IAPs-50% Use the following tables to report criteria and non-criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Criteria Pollutant Emissions Inventory Requested Annual Permit Emission Factor Actual Annual Emissions1° Emission Limit(s)6 Pollutant Uncontrolled Source Uncontrolled Controlled ; Uncontrolled Controlled Basis Units (AP-42, Emissions Emissions Emissions Emissions Mfg.etc) (tons/year) (tons/year) (tons/year)„ (tons/year) TSP(PM) 9.99E-03 Ib/MMBtu AP-42 0.78 0.78 1.05 1.05 PM10 9.99E-03 Ib/MMBtu AP-42 0.78 0.78 1.05 1.05 PM2.5 9.99E-03 Ib/MMBtu AP-42 0.76 0.78 1.05 1.05 .' 6 SOx 5.88E-04 lb/MMBtu AP-42 0.05 0.05 0.06 0.06 �L(tr..t,..: NOx 0.7 IblMA1BtO, Mfg. 17.89 17.89 24.00 24.00 i�/a 8 ‘[*6 VOC 6.2 Ib/MMstuAl ri). Mfg. 157.38 17.89 210.82 24.00 1 CO 2.5 4bIMMBW aori b061,Mfg. 63.97 20.48 85.70 27.42 Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 0 Yes O No lbs/year? If yes, please use the following table to report the non-criteria pollutant (HAP)emissions from source: Non-Criteria Reportable Pollutant Emissions inventory Chemical Emission Factor Actual Annual Emissionst0 Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) (JncontroII d Units (AP-42, Emissions Emissions Number Basis mfg.etc) (pounds/year) (pounds/year) Formaldehyde 50000 0.40 g/hp-hr Mfg. 20,471.81 4,094.36 Acetaldehyde 75070 8.36E-03 lb/MMBtu AP-42 1.311.94 655.97 Acrolein 107028 5.14E-03 lb/MMBtu AP-42 806.62 403.31 Cr.644(' Benzene 71432 ...4:40E'-'03 anlM ..A Mee, ..AP-42- ..690:49. Ilea_ Other: 67561-Methanol 2.50E-03 IbIMMBtu AP-42 392.33 196.16 124.16/1A Ci 8 Requested values will become permit limitations.Requested limit(s)should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. vair COLORADO Form APCD-201 Spark Ignition Engine APEPI - Revision 7/2018 5 1 AV ;,:c.:1',-,`;7,,`!:!M, Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 070 _Meek = _'sit a Rs 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. 11/1117.1:4(g 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: D Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type,etc.). See Regulation No. 3, Part A, II,C. for revised APEN requirements. Send this form along with$191.13 and the General Permit For more information or assistance call: registration fee of$1,875, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692-3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www,cotorado.gavlcdphelapca AVW COLORADO F=iti tApo) 201 5, tr" F F.t >;. <<n 1�LJ! 6 I AW ®� ,�pX018 �apH� Spark Ignition Engine APEN Form APCD-201 "CrOtt G} Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for spark ignition(e.g. gas-fired)reciprocating internal combustion engines(RICE). If your engine is a compression ignition engine(e.g. diesel-fired)or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source(e.g.compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN(Form APCD-200)is available if the specialty APEN options do not meet your reporting needs.A list of all available APEN forms can be found on the Air Pollution Control Division (APCD)website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made(significant emissions increase, increase production, new equipment,change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/071 (Leave blank unless APCD has already assigned a permit li and AIRS ID] Section 1 - Administrative Information Company Name: DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30,T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Zip Code)c Address: (Include 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 Portable Source Home Base: E-Mail Address 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 the APCD via e-mail to the address provided. 390475 46,43 COLORADO Form APCD-201 Spark Ignition Engine APEN - Revision 7/2O18 - 1 I Mg =V,-;:`,';'=`"= Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 071 rd `f); 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$1,875 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 O Add point to existing permit D Change permit limit ❑ Transfer of ownerships 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 O Notification of Alternate Operating Scenario(AOS)permanent replacement6 Additional Info&:Notes: Revised Fuel Heat Value (FHV) used for fuel use limit calculations 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change,a completed Company Name Change Certification Form(Form APCD-106)must be submitted. 5 For transfer of ownership,a completed Transfer of Ownership Certification Form(Form APCD-104)must be submitted. b 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-237 General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: 8/31/2012 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? 0ittp://www.cotorado.govicdphelattainmerit) ✓ Yes ED No Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use-ptceentage: Dec-Feb: 25% Mar-May: 25% June-Aug: 25% Sept-Nov: 25% is, C0L0RAD0 2 Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 071 [Leave blank unless APCD has already assigned a permit tr and AIRS ID] Section 4 - Engine Information Engine Function: ❑Primary and/or Peaking Power ❑Emergency(max. 500 hrs/year) 0✓ Compression Pump Jack ❑Water Pump O Other: What is the maximum number of hours this engine will be used for emergency back-up power? 0 hours/year Engine Make: Caterpillar Engine Model: G3616 Serial Number7: BLB00490 What is the maximum designed horsepower rating? 4,735 hp What is the maximum manufacturer's site-rating? 4,735 hp kW What is the engine Brake Specific Fuel Consumption at 100%Load? 7,481 BTU/hp-hr Engine Features: Cycle Type: O 2-Stroke p✓ 4-Stroke Combustion: 0 Lean Burn O Rich Burn Aspiration: ❑Natural D Turbocharged Is this engine equipped with an Air/Fuel ratio controller(AFRC)? ❑Yes 0 No If yes, what type of AFRC is in use? O O2 Sensor(mV) ❑NOx Sensor(ppm) O Other: Is this engine equipped with a Low-NOx design? Yes O No Engine Dates: What is the manufactured date of this engine? <8/2012 What date was this engine ordered? < 8/2012 What is the date this engine was first located to Colorado? <8/2012 What is the date this engine was first placed in service/operation? 2O12 What is the date this engine commenced construction? <8/2012 What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? O Yes p✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested. WS COLORADO Form APCD-201 Spark ignition Engine APEN - Revision 7/2018 3 1 .co Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 071 (Lc,- CCU ;Air Id/ si,1c 1 Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 / -104.4877 Operator Discharge Height Temp. Flow Rate Velocity Above Ground Level Stack ID No. C F) (ACFM) (ft/sec) (feet) C-237 52.5 876 32,336 Indicate the direction of the Stack outlet: (check one) ✓❑Upward ❑Downward 0 Upward with obstructing raincap ❑Horizontal O Other(describe): Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter(inches): ❑Square/Rectangle Interior stack diameter(inches): Interior stack depth (inches): ❑Other(describe): Section 6 - Fuel Data and Throughput Information Fuel Use Rate® 100%Load Actual Annual Fuel Use Requested Annual Permit Limit8 (SCF/hour) (MMSCF/year) (MMSCF/year) 34,728.43 213.74 304.22 From what year is the actual annual amount? 2017 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): Residue Gas Heating Value(give units): 1,109.7 Btu/sal 8 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. Pipeline Natural Gas fuel heat value (FHV) of 1,020 Btu/scf assumed for requested permit limit calculations. Residue Gas FHV of 1,109.7 Btu/scf used for 2017 actual fuel use calculations. CGlORAOO Furor APCI 201 it! I, i e i 7O018 4 I A Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 071 [Leave blank unless APCD has already assigned a permit re.and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form.The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? 0 Yes O No If yes, describe the control equipment AND state the overall control efficiency(%reduction): Overall Requested Control Pollutant Primary Control Equipment Description Efficiency (%reduction in emissions) TSP(PM) PM 10 PM2.5 SOx NOx VOC Oxidation Catalyst 89% CO Oxidation Catalyst 71% Other: Oxidation Catalyst-HAPs Formaldehyde-80%,Other HAPs-50% Use the following tables to report criteria and non-criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2017 Criteria Pollutant Emissions Inventory Requested Annual Permit Emission Factor Actual Annual Emissions" Emission Limit(s)8 Pollutant Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis Units (AP-42, Emissions Emissions Emissions Emissions Mfg.etc) (tons/year) (tons/year) (tons/year) (tons/year) TSP(PM) 9.99E-03 lb/MMBtu AP-42 1.18 1.18 1.55 1.55 PM10 9.99E-03 Ib/MMBtu AP-42 1.18 1.18 1.55 1.55 PM2.5 9.99E-03 lb/MMBtu AP-02 1.18 1.18 1.55 1.55 SOx 5.88E-04 lb/MMBtu AP-42 0.07 0.07 0.09 0.09 NOx 0.7 g/hp-hr Mfg. 24.42 24.42 32.01 32.01 VOC 6.2 g/hp-hr Mfg. 214.80 24.42 281.19 32.01 CO 2.8 glhp-hr Mfg. 96.05 27.97 125.74 36.58 Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 0 Yes ❑No lbs/year? If yes, please use the following table to report the non-criteria pollutant(HAP)emissions from source: Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissionst0 Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions Number Basis Mfg.etc) (pounds/year) (pounds/year) Formaldehyde 50000 0.40 g/hp-hr Mfg. 27,942.19 5,588.44 Acetaldehyde 75070 8.36E-03 Ib/MMRtu AP-42 1,981.66 990.83 Acrolein 107028 5.14E-03 lb/MMBtu AP-42 1,218.39 609.20 Benzene 71432 -4:40E-113 lxiMMBlu ,4P-42 4-,,04248 421_49 P` Other: 67561-Methanol 2.50E-03 lb/MMBtu AP-42 592.60 296.30 64,,,,� i /z '‘-'Cl ' 8 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 318 10 Annual emissions fees wilt be based on actual controlled emissions reported.If source has not yet started operating,leave blank. . will= COLORADO Form APCD-2O1 Spark Ignition Engine APEN - Revision 7/2018 5 I Li =r" "'""``. Permit Number: 95OPWE103 AIRS ID Number: 123 /0277/ 071 s an 1 AIRS:Di 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. .�' It/Iq /2O( 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: E✓ Draft permit prior to issuance E✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of$1,875, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692-3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www.cotorado.gov/cdphelapcd COIORA DO Foriii APCD 201 ), ir IC I n c r= A� I, LZ-_=ai n 7'101 6 12/17/2018 State.co.us Executive Branch Mail-Enterprise 11-19-18 Minor Mod Completeness and Questions '!!". STATE OF COLORADOSchuchardt-CDPHE, Elie<elie.schuchardt@state.co.us> Enterprise 11-19-18 Minor Mod Completeness and Questions Shankaran,Roshini<RShankaran@dcpmidstream.com> Mon, Dec 3,2018 at 1:29 PM To: "Schuchardt-CDPHE, Elie"<elie.schuchardt@state.co.us> Hi Elie, I hope you are enjoying your vacation! Thank you for going through this! Here are responses to the issues you noted: 1)The uncontrolled EF's for engine C-238 should be redlined to the following: N0x=0.7 g/hp-hr, CO=2.5 g/hp-hr, V0C=6.2 g/hp-hr.There are no required changes to the reported emissions. 2)The benzene EF for all 5 engines should be 4.40E-04 instead of 4.40E-03 as indicated.This correction results in Benzene emissions no longer being reportable for all five engines.All five APENs should be redlined to remove Benzene completely from the HAP tables. 3) One additional redline we should request:the units associated with the NOx, CO, and V0C uncontrolled EF's for engine C-234 are incorrect.They should be redlined from "lb/MMBtu"to"g/hp-hr." No required changes to reported emissions. 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 Midstream https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1618863972628490834&simpl=msg-f%3A16188639726... 1/2 12/17/2018 State.co.us Executive Branch Mail-Enterprise 11-19-18 Minor Mod Completeness and Questions From:Schuchardt-CDPHE, Elie [mailto:elie.schuchardt@state.co.us] Sent:Tuesday, November 27, 2018 2:08 PM To:Shankaran, Roshini<RShankaran@dcpmidstream.com> Subject: Enterprise 11-19-18 Minor Mod Completeness and Questions [Quoted text hidden] ***WARNING:This email originated from outside of DCP Midstream.Do not click links or open attachments unless you recognize the sender and know the content is safe.Safety and security starts with each of us.*** https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1618863972628490834&simpl=msg-f%3A16188639726... 2/2 INFO TO SUPPORT 11/20/2018 Modification *Note that the information presented in this modification application was subsequently modified with the 12/3/2018 email. See redlined APEN (included above) j CDPHE COLORADO CO Department of Public Health El Environment Dedicated to protecting and improving the health and environment of the people of Colorado Roshini Shankaran DCP Operating Company, LP 370 17th Street, Suite 2500 Denver, CO 80202 November 27, 2018 RE: Complete Application for Minor Modification to Operating Permit 95OPWE103 Dear Ms. Shankaran: The Division received your request to modify the Operating Permit for the Enterprise Compressor Station on November 20, 2018. The modifications requested include modifying the fuel gas consumption limitation for engines C-234, C-235, C-236, C-237 and C-238 based on an updated fuel gas heat content. The Division agrees that the requested modifications meet the requirements of a minor permit modification (Reg 3, Part C, Section X.A) and considers that your submittal comprises a complete application for a minor permit modification. The Division considers your application for a minor operating permit modification to be complete as of November 20, 2018. As specified in Colorado Regulation 3, Part C, Section X.I, "a source shall be allowed to make the changes proposed in its application for minor permit modification immediately after it files such [complete] application." Note that if you choose to make the changes proposed in your minor permit application before the Division issues the revised permit that Colorado Regulation 3, Part C, Section X.I requires that: "...the source must comply with both the applicable requirements governing the change and the proposed permit terms and conditions. During this time the source does not need to comply with existing permit terms and conditions it seeks to modify, but if the source fails to comply with its proposed permit terms and conditions during this period, the existing permit terms and conditions it seeks to modify shall be fully enforceable by the Division," In addition, if you choose to make the changes proposed in your minor permit application before the Division issues the revised permit, the new or modified equipment shall be addressed in subsequent semi-annual monitoring and permit deviation reports and annual compliance certifications. The compliance status of the new or modified equipment shall be based on the provisions specified in the draft permit submitted with the minor permit application. Typically, the next step for this permit modification is the EPA 45-day review period. Since the renewal application for your facility was submitted on July 26, 2016, the Division will incorporate this modification into your renewal permit. If you have any further questions please contact me at (303) 692-6332. OF COC 4300 Cherry Creek Drive S., Denver, CO 80246.1530 P 303-692-2000 www.colorado.gov/cdphe r/F John W. Hickenlooper, Governor Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer 4,, S*1876' Sincerely, Elie Schuchardt Permit Engineer Operating Permit Unit Stationary Sources Program Air Pollution Control Division cc: Craig Giesecke, APCD Inspector (electronic copy) 11/27/2018 State.co.us Executive Branch Mail-Enterprise 11-19-18 Minor Mod Completeness and Questions ''!` STATE OF l COLORADO Schuchardt-CDPHE, Elie<elie.schuchardt@state.co.us> Enterprise 11-19-18 Minor Mod Completeness and Questions 1 message Schuchardt-CDPHE, Elie<elie.schuchardt@state.co.us> Tue, Nov 27, 2018 at 2:08 PM To: "Shankaran, Roshini"<RShankaran@dcpmidstream.com> Hi Roshini, I got through this mod and the major stuff looks good (draft permit,throughput limits),so I'm going to call it complete- please find the letter attached!Again, since it is a minor mod,these limitations are effective the date of the letter. Because I'm currently working on the Enterprise renewal, I'm just going to incorporate this mod with the renewal instead of issuing the mod separately-but with this completeness letter you're good to operate with these new limits. I did notice a couple of things on the APENs I wanted to run by you-they're minor changes and I'd be happy to redline, just let me know! • C-238 Uncontrolled EF's- I think the uncontrolled emission factors for VOC and CO listed on the APEN for engine C-238 (AIRS 053)are actually controlled EF's. Can I redline to 0.815 for CO and 2.022 for VOC?Or, alternatively, I could revert the NOx, CO, and VOC emission factors to the g/bhp-hr units of 0.7, 2.5 and 6.2 for each pollutant respectively(like the other engines in the package). • Benzene EF- I think AP-42 has an emission factor for benzene of 4.4 x 10^-4 instead of 10^-3, so I'm getting different HAP emissions than what is reported on the APEN and calculation pages.Would you like me to redline these? Other than that, the mod looked good! Let me know if you'd like me to redline and I can get that done for you when I get back! Thanks so much, Elie Schuchardt Permit Engineer Title V Operating Permit Unit Stationary Sources Program Air Pollution Control Division P 303.692.6332 4300 Cherry Creek Drive South, Denver, CO 80246-1530 elie.schuchardt@state.co.us I www.colorado.gov/cdphe/aped COPHE COLORADO co ,.f Air Pollution Control Division Are you curious about ground-level ozone in Colorado?Visit our ozone webpage to learn more. n 11-20-18 DCP Enterprise Source Completeness Letter.pdf 86K https://mail.google.com/mail/u/0?ik=85031 f4oe8&view=pt&search=all&permthid=thread-a%3Ar3634209064195732191&simpl=msg-a%3Ar236424484... 1/1 j CDPHE COLORADO CO VI Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Mr. D. J. Law Office of Partnerships and Regulatory Assistance Air and Radiation Programs, 8P-AR U. S. EPA, Region VIII 1595 Wynkoop Street Denver, CO 80202-1129 November 27, 2018 Dear Mr. Law: The Division received a complete application for a minor modification to the Operating Permit for the following Colorado facility: Applicant/Facility Name: DCP Operating Company, LP - Enterprise Compressor Station AIRS ID#: 123-0277 Permit No: 95OPWE103 Facility Address: SWSW Section 30, T3N, R63W Facility City, State, ZIP: Weld County, CO The Division agrees that the requested modification can be processed under the minor permit modification procedures identified in Colorado Regulation No. 3, Part C, Section X. As required by Colorado Regulation No. 3, Part C, Section X.F, the Division is notifying you that a complete application for a minor permit modification has been submitted. The application was deemed complete on November 20, 2018. The Division is not intending to actually issue this minor modification permit since the renewal application has been submitted and is currently under review. The Division will include these minor modification requests in the renewal permit. Please do not hesitate to contact me if you have any questions at 303-692-6332 or elie.schuchardt@state.co.us Sincerely, rcitta5datr(CL124 Elie Schuchardt Engineer Operating Permit Unit Stationary Sources Program Air Pollution Control Division cc� Ate', :,Pv 4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe /, 9 John W. Hickenlooper, Governor Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer '. 11/27/2018 State.co.us Executive Branch Mai-DCP Enterprise Minor Modification Submitted STATE OF F j = GOLa Schuchardt-CDPHE, Elie<elie.schuchardt@state.co.us> %kWDCP Enterprise Minor Modification Submitted 1 message Schuchardt-CDPHE, Elie <elie.schuchardt@state.co.us> Tue, Nov 27, 2018 at 2:18 PM To: law.donald@epa.gov Cc:fallon.gail@epa.gov Mr. Law, Please find attached the notification letter of a minor modification to DCP Operating Company, LP's Enterprise Compressor Station (123-0277; 95OPWE103). I have accepted this modification and will be incorporating it into the renewal operating permit,which I am currently working on. Please let me know if you have any questions. Thanks so much, Elie Schuchardt Permit Engineer Title V Operating Permit Unit Stationary Sources Program Air Pollution Control Division P 303.692.6332 4300 Cherry Creek Drive South, Denver, CO 80246-1530 • elie.schuchardt@state.co.us I www.colorado.gov/cdphe/aped CDPHE COLORADO co f .Atr Pollution Control Division Are you curious about ground-level ozone in Colorado?Visit our ozone webpage to learn more. 11-20-18 DCP Enterprise EPA Notice Letter.pdf 50K https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permthid=thread-a%3Ar6080324453594712554&simpl=msg-a%3Ar-431100230... 1/1 A COPHE COLORADO CO ' Department of Public -' Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Balaji Vaidyanathan Permit Section Manager Arizona Department of Environmental Quality - Air Quality Division 1110 West Washington Street Phoenix, AZ 85007 November 27, 2018 RE: DCP Operating Company, LP - Enterprise Compressor Station Operating Permit No. 95OPWE103 SUBJECT: Notification to Affected States of Requested Operating Permit Modification Dear Balaji Vaidyanathan, The Air Pollution Control Division (APCD) of the Colorado Department of Public Health and Environment (CDPHE) received a complete application for a minor modification to the above referenced Operating Permit. The Division agrees that the requested modification can be processed under the minor permit modification procedures identified in Colorado Regulation No. 3, Part C, Section X. This facility is located at SWSW Section 30, T3N, R63W in Weld County. As required by Colorado Regulation No. 3, Part C, Section X.G, the Air Pollution Control Division is notifying you that a complete application for a minor permit modification has been submitted. As specified in Colorado Regulation No. 3, Part C, Section X.I, the source is allowed to make the changes proposed in its application for minor permit modification immediately after it files such [a complete] application. The application was deemed complete on November 20, 2018. If you have any questions or require any additional information, please contact Elie Schuchardt at 303-692-6332 or elie.schuchardt@state.co.us. Sincerely, .#kg* Matthew S. Burgett Operating Permit Unit Stationary Sources Program Air Pollution Control Division Y COWL-;._ 4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe I i�� 'off; �I John W. Hickenlooper,Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer �, tt \ i ..rsi , -. 6_..° A CDPHE COLORADO Co Department of Public �. Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Ms. Marian Massoth Air Permitting Chief Kansas Dept. of Health Et Environment 1000 SW Jackson Suite 310 Topeka, KS 66612-1366 November 27, 2018 RE: DCP Operating Company, LP - Enterprise Compressor Station Operating Permit No. 95OPWE103 SUBJECT: Notification to Affected States of Requested Operating Permit Modification Dear Ms. Massoth, The Air Pollution Control Division (APCD) of the Colorado Department of Public Health and Environment (CDPHE) received a complete application for a minor modification to the above referenced Operating Permit. The Division agrees that the requested modification can be processed under the minor permit modification procedures identified in Colorado Regulation No. 3, Part C, Section X. This facility is located at SWSW Section 30, T3N, R63W in Weld County. As required by Colorado Regulation No. 3, Part C, Section X.G, the Air Pollution Control Division is notifying you that a complete application for a minor permit modification has been submitted. As specified in Colorado Regulation No. 3, Part C, Section X.I, the source is allowed to make the changes proposed in its application for minor permit modification immediately after it files such [a complete] application. The application was deemed complete on November 20, 2018. If you have any questions or require any additional information, please contact Elie Schuchardt at 303-692-6332 or elie.schuchardt@state.co.us. Sincerely, 'MIT, 4 Matthew S. Burgett Operating Permit Unit Stationary Sources Program Air Pollution Control Division :6.a9- 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.govlcdphe 4. .� , ‘,9_,' John W. Hickenlooper,Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer I '* ,' '- *i - a -- iis / As CDPHE COLORADO CO Department of Public • Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado NDEQ Air Permitting Section Supervisor Nebraska Dept. of Environmental Quality P.O. Box 98922 Lincoln, NE 68509-8922 November 27, 2018 RE: DCP Operating Company, LP - Enterprise Compressor Station Operating Permit No. 95OPWE103 SUBJECT: Notification to Affected States of Requested Operating Permit Modification Dear NDEQ Air Permitting Section Supervisor, The Air Pollution Control Division (APCD) of the Colorado Department of Public Health and Environment (CDPHE) received a complete application for a minor modification to the above referenced Operating Permit. The Division agrees that the requested modification can be processed under the minor permit modification procedures identified in Colorado Regulation No. 3, Part C, Section X. This facility is located at SWSW Section 30, T3N, R63W in Weld County. As required by Colorado Regulation No. 3, Part C, Section X.G, the Air Pollution Control Division is notifying you that a complete application for a minor permit modification has been submitted. As specified in Colorado Regulation No. 3, Part C, Section X.I, the source is allowed to make the changes proposed in its application for minor permit modification immediately after it files such [a complete] application. The application was deemed complete on November 20, 2018. If you have any questions or require any additional information, please contact Elie Schuchardt at 303-692-6332 or elie.schuchardt@state.co.us. Sincerely, 1/97-jr Matthew S. Burgett Operating Permit Unit Stationary Sources Program Air Pollution Control Division 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe /� I" to John W. Hickenlooper,Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer CDPHE COLORADO Co j' Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Major Sources Permitting Program Manager New Mexico Environment Department - Air Quality Bureau 525 Camino de los Marquez Suite 1 Santa Fe, NM 87505-1816 November 27, 2018 RE: DCP Operating Company, LP - Enterprise Compressor Station Operating Permit No. 95OPWE103 SUBJECT: Notification to Affected States of Requested Operating Permit Modification Dear Major Sources Permitting Program Manager, The Air Pollution Control Division (APCD) of the Colorado Department of Public Health and Environment (CDPHE) received a complete application for a minor modification to the above referenced Operating Permit. The Division agrees that the requested modification can be processed under the minor permit modification procedures identified in Colorado Regulation No. 3, Part C, Section X. This facility is located at SWSW Section 30, T3N, R63W in Weld County. As required by Colorado Regulation No. 3, Part C, Section X.G, the Air Pollution Control Division is notifying you that a complete application for a minor permit modification has been submitted. As specified in Colorado Regulation No. 3, Part C, Section X.I, the source is allowed to make the changes proposed in its application for minor permit modification immediately after it files such [a complete] application. The application was deemed complete on November 20, 2018. If you have any questions or require any additional information, please contact Elie Schuchardt at 303-692-6332 or elie.schuchardt@state.co.us. Sincerely, it Matthew S. Burgett Operating Permit Unit Stationary Sources Program Air Pollution Control Division Cat t C . 4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303-692-2000 www.colorado.govlcdphe jFT •' ' jN John W. Hickenlooper, Governor j Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer 7.„ ,; 4. CDPHE COLORADO CO Department of Public • . Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado Mr. Richard Kienlen Oklahoma Department of Air Quality P.O. Box 1677 Oklahoma City, OK 73101-1677 November 27, 2018 RE: DCP Operating Company, LP - Enterprise Compressor Station Operating Permit No. 95OPWE103 SUBJECT: Notification to Affected States of Requested Operating Permit Modification Dear Mr. Kienlen, The Air Pollution Control Division (APCD) of the Colorado Department of Public Health and Environment (CDPHE) received a complete application for a minor modification to the above referenced Operating Permit. The Division agrees that the requested modification can be processed under the minor permit modification procedures identified in Colorado Regulation No. 3, Part C, Section X. This facility is located at SWSW Section 30, T3N, R63W in Weld County. As required by Colorado Regulation No. 3, Part C, Section X.G, the Air Pollution Control Division is notifying you that a complete application for a minor permit modification has been submitted. As specified in Colorado Regulation No. 3, Part C, Section X.I, the source is allowed to make the changes proposed in its application for minor permit modification immediately after it files such [a complete] application. The application was deemed complete on November 20, 2018. If you have any questions or require any additional information, please contact Elie Schuchardt at 303-692-6332 or elie.schuchardt@state.co.us. Sincerely, I/9/4-f Matthew S. Burgett Operating Permit Unit Stationary Sources Program Air Pollution Control Division ra�co/� 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe .;e ,00, John W. Hickenlooper, Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer s� - A CDPHE ( COLORADO z ti CO % , Department of Public Health 8 Environment Dedicated to protecting and improving the health and environment of the people of Colorado Air Quality Program Manager Southern Ute Indian Tribe - Air Quality Program P.O. Box 737,MS #84 Ignacio, CO 81137 November 27, 2018 RE: DCP Operating Company, LP - Enterprise Compressor Station Operating Permit No. 95OPWE103 SUBJECT: Notification to Affected States of Requested Operating Permit Modification Dear Air Quality Program Manager, The Air Pollution Control Division (APCD) of the Colorado Department of Public Health and Environment (CDPHE) received a complete application for a minor modification to the above referenced Operating Permit. The Division agrees that the requested modification can be processed under the minor permit modification procedures identified in Colorado Regulation No. 3, Part C, Section X. This facility is located at SWSW Section 30, T3N, R63W in Weld County. As required by Colorado Regulation No. 3, Part C, Section X.G, the Air Pollution Control Division is notifying you that a complete application for a minor permit modification has been submitted. As specified in Colorado Regulation No. 3, Part C, Section X.I, the source is allowed to make the changes proposed in its application for minor permit modification immediately after it files such [a complete] application. The application was deemed complete on November 20, 2018. If you have any questions or require any additional information, please contact Elie Schuchardt at 303-692-6332 or elie.schuchardt@state.co.us. Sincerely, Matthew S. Burgett Operating Permit Unit Stationary Sources Program Air Pollution Control Division 4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303-692-2000 www.cotorado.gov/cdphe John W. Hickenlooper, Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer # o A CDPHE COLORADO Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Mr. Jesse Chacon Manager - Title V Section Texas Natural Resources Conservation,Commission P.O. Box 13087 Mail Code 163 Austin, TX 78711-3087 November 27, 2018 RE: DCP Operating Company, LP - Enterprise Compressor Station Operating Permit No. 95OPWE103 SUBJECT: Notification to Affected States of Requested Operating Permit Modification Dear Mr. Chacon, The Air Pollution Control Division (APCD) of the Colorado Department of Public Health and Environment (CDPHE) received a complete application for a minor modification to the above referenced Operating Permit. The Division agrees that the requested modification can be processed under the minor permit modification procedures identified in Colorado Regulation No. 3, Part C, Section X. This facility is located at SWSW Section 30, T3N, R63W in Weld County. As required by Colorado Regulation No. 3, Part C, Section X.G, the Air Pollution Control Division is notifying you that a complete application for a minor permit modification has been submitted. As specified in Colorado Regulation No. 3, Part C, Section X.I, the source is allowed to make the changes proposed in its application for minor permit modification immediately after it files such [a complete] application. The application was deemed complete on November 20, 2018. If you have any questions or require any additional information, please contact Elie Schuchardt at 303-692-6332 or elie.schuchardt@state.co.us. Sincerely, Matthew S. Burgett Operating Permit Unit Stationary Sources Program Air Pollution Control Division 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe / 4%. a To` John W. Hickenlooper,Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer * o' �z. CDPHE ( COLORADO • I Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Mr. David Beatty Section Manager - Operating Permits Utah Department of Environmental Quality - Division of Air Quality P.O. Box 144820 Salt Lake City, UT 84114 November 27, 2018 RE: DCP Operating Company, LP - Enterprise Compressor Station Operating Permit No. 95OPWE103 SUBJECT: Notification to Affected States of Requested Operating Permit Modification Dear Mr. Beatty, The Air Pollution Control Division (APCD) of the Colorado Department of Public Health and Environment (CDPHE) received a complete application for a minor modification to the above referenced Operating Permit. The Division agrees that the requested modification can be processed under the minor permit modification procedures identified in Colorado Regulation No. 3, Part C, Section X. This facility is located at SWSW Section 30, T3N, R63W in Weld County. As required by Colorado Regulation No. 3, Part C, Section X.G, the Air Pollution Control Division is notifying you that a complete application for a minor permit modification has been submitted. As specified in Colorado Regulation No. 3, Part C, Section X.I, the source is allowed to make the changes proposed in its application for minor permit modification immediately after it files such [a complete] application. The application was deemed complete on November 20, 2018. If you have any questions or require any additional information, please contact Elie Schuchardt at 303-692-6332 or elie.schuchardt@state.co.us. Sincerely, /146,,F -- Matthew S. Burgett Operating Permit Unit Stationary Sources Program Air Pollution Control Division 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe /izr 'rtO ', John W. Hickenlooper,Governor ! Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer II*,. k *fir>,≤"Y..;4 r'. A CDPHE COLORADO CoDepartment of Public * Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Title V Operating Permit Program Supervisor Wyoming Department of Environmental Quality - Air Quality Division 122 W 25th Street Cheyenne, WY 82002 November 27, 2018 RE: DCP Operating Company, LP - Enterprise Compressor Station Operating Permit No. 95OPWE103 SUBJECT: Notification to Affected States of Requested Operating Permit Modification Dear Title V Operating Permit Program Supervisor, The Air Pollution Control Division (APCD) of the Colorado Department of Public Health and Environment (CDPHE) received a complete application for a minor modification to the above referenced Operating Permit. The Division agrees that the requested modification can be processed under the minor permit modification procedures identified in Colorado Regulation No. 3, Part C, Section X. This facility is located at SWSW Section 30, T3N, R63W in Weld County. As required by Colorado Regulation No. 3, Part C, Section X.G, the Air Pollution Control Division is notifying you that a complete application for a minor permit modification has been submitted. As specified in Colorado Regulation No. 3, Part C, Section X.I, the source is allowed to make the changes proposed in its application for minor permit modification immediately after it files such [a complete] application. The application was deemed complete on November 20, 2018. If you have any questions or require any additional information, please contact Elie Schuchardt at 303-692-6332 or elie.schuchardt@state.co.us. Sincerely, /et," Matthew S. Burgett Operating Permit Unit Stationary Sources Program Air Pollution Control Division 4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303-692-2000 www.colorado.govlcdphe i,' 4".v- Ite5 John W. Hickenlooper, Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer '* i, t 1876*„--/ 11/20/2018 Significant Modification Application 1c:'FJ 370 17th Street.Suite 2500 Midstream Den,er.�°9°202 X03-6«5-3u;9 November 19, 2018 Sent via UPS Tracking No. 1Z F46 915 02 9525 2478 Ms. Elie Schuchardt ~' Colorado Department of Public Health and Environment oV 1 5 1018 Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-B 1 oratrY Denver, CO 80246-1530 }C=` Re: DCP Operating Company, LP; Enterprise Compressor Station (123/0277) Title V Operating Permit Modification Application (95OPWE103) D-2 Natural Gas Dehydrator(AIRS 068) COMB-1 Enclosed Combustor(AIRS 074) Ms. Schuchardt: DCP Operating Company, LP (DCP) is submitting the attached Title V modification application for the Enterprise Compressor Station, located in SWSW Section 30. Township 3N, Range 63W, Weld County, Colorado. DCP is requesting the changes to Title V Operating Permit 95OPWE 103 detailed in this application. A timely renewal application for this facility was submitted July 26. 2016. This renewal application is currently undergoing review with the state. Application History • July 26,2016—Title V Renewal and Minor Modification Application:DCP requested 5.0% annual downtime for the VRU used for emission control of D-2's flash tank, during which emissions vent to COMB-1. A 3.0% annual downtime for COMB-1 was also requested, during which D-2's still vent emissions vent to atmosphere. • January 26, 2018—Minor Modification Application: DCP requested removal of COMB-1 as the backup control device during VRU annual downtime. VRU downtime was decreased from 5.0% to 1.0%, and COMB-1 downtime was decreased from 3.0% to 2.25%. Other minor updates to the underlying GLYCaIc properties for D2 were also requested. There were no overall changes in VOC emissions from D2 requested as part of this application, as increases due to the above changes in control were balanced out by reductions in control device downtime. DCP is withdrawing the January 26, 2018 minor modification application at this time, to be replaced by the changes requested in this significant modification application. DCP wishes to retain the changes requested in the July 26, 2016 minor modification. although some of these previous requested changes will be superseded by the changes in this application. Please see following summary of requested changes for details. Summary of Changes • D-2 Triethylene Glycol Dehydration Unit(AIRS 068) o Remove the listed condenser as a primary control device for this AIRS point. Retain the enclosed combustor COMB-1 used for still vent emission control from this source as the primary control device. The condenser itself will not be removed from the facility,but DCP will no longer claim any emission control from the condenser for still vent emissions from unit D-2'. I, o Cancel the AIRS point (AIRS 074) associated with COMB-12 and combine the combustion emissions from COMB-I under AIRS 068. • Decrease permitted downtime for COMB-1 from 3.0% annually to 1.0% annually. Still vent emissions from D-2 will continue to vent to atmosphere during periods of COMB-1 downtime. • Retain 5.0%annual downtime for the VRU recycling flash tank emissions from this unit. Emissions during VRU downtime will continue to vent to the backup control device COMB-1. • Revise the emission calculations from COMB-1 to include assist gas as well as pilot gas. o Update the GLYCaIc parameters, including the inlet extended gas analysis, used to estimated emissions for this source.These parameters have been evaluated and updated to more closely capture the actual operating parameters for this source. o Update the monitoring and recordkeeping requirements in Operating Permit 95OPWE020 to reflect removal of the condenser as a primary control device. o Update the CAM plan for unit D-2 to reflect removal of the condenser as a primary control device. • Facility Insignificant Activities o DCP is including an updated list of insignificant activities at this facility as part of this application. Insignificant emissions have been estimated, where applicable. Please see the list included in Attachment D for more details. ' The removal of this condenser as a primary control device,along with the associated monitoring and recordkeeping requirements from Operating Permit 95OPWE103,constitutes a significant change in existing monitoring permit conditions for unit D-2 and this Title V modification meets the definition of"significant"as a result.DCP has included Colorado Title V operating permit forms detailing the specific changes requested in this modification application,along with an updated Compliance Assurance Monitoring(CAM)plan for unit D-2. 2 A cancellation notice for AIRS 074 will be submitted after this application has been processed and approved. Please note that as indicated on APCD Form 2000-606 and the Responsible Official Certification for this application, D-2 is currently out of compliance with the requirement to vent all flash emissions to the enclosed combustor during periods of VRU downtime. Currently, the condenser located between the flash tank and enclosed combustor is suffering periodic freezing issues during colder winter months. These freezing issues prevent flow from the flash tank to the enclosed combustor during overlapping VRU downtime, causing flash emissions to vent to atmosphere. DCP has proposed a date of June 30.2019 to replace this condenser and correct this issue. Federal Regulatory Applicability • NSPS Subpart HH National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities o Unit D-2 at this facility is subject to the area source provisions of MACT Subpart HH, and this facility is not located within any Urban Area+Offset or Urban Cluster. There are no changes in the applicable requirements under this subpart for unit D-2 based on the changes proposed in this Title V modification application. Colorado Regulatory Applicability • Regulation 7, Section XII. Volatile Organic Compound Emissions from Oil and Gas Operations o D-2 is subject to the emission reduction requirements, control device operation requirements, and associated monitoring. recordkeeping, and reporting requirements under Colorado Regulation 7, Section XII. DCP will continue to meet all applicable requirements under this section. • Regulation 7, Section XVII. (State Only, except Section XbII.E.3.a. which was submitted as part of the Regional Haze SIP)Statewide Controls for Oil and Gas Operations and Natural Gas-Fired Reciprocating Internal Combustion Engines o D-2 is subject to the state-specific emission reduction and control requirements under Colorado Regulation 7, Section XVII. Specifically,the emission reduction requirements under Reg 7, Section XVII.D require at least a 95%reduction in actual emissions of hydrocarbons. The attached calculations in Attachment D of this application show that DCP will continue to meet this requirement without the additional control provided by the condenser. PSD/NNSR Applicability Enterprise Compressor Station is located in Weld County. Weld County is currently attainment or unclassifiable for all criteria pollutants with the exception of the 2008 8-hour ozone standard. A major source in an ozone nonattainment area is a source with a PTE of 100 tpy or more of NOx or VOC. Enterprise Compressor Station has potential emissions of both NOc and VOC above these thresholds and is considered an existing major stationary source.NNSR is required for major modifications at existing major stationary sources,which are modifications that cause a significant increase in a regulated NSR pollutant.As Table 1 below illustrates,the potential emission increases from all modified sources in this application are below the Significant Emission Rate (SER)thresholds. This project is not considered a major modification and no further requirements under the NNSR program apply at this time. Table 1 —Project Potential Emissions Potential Emissions AIRS ID Equipment Description NO (tpy) VOC(tpy) CO(tpy) PM(tpy) 123/0277/068 D-2 110 MMscfd TEG Dehy 1.43 24.96 6.51 - 123/0277/074 COMB-1 (Cancelled) -0.64 0.00 -3.49 - TBD Produced Water Storage - 1.60 - - N/A Insignificant Activities 1.40 8.78 1.18 - Total Project Potential Emissions 2.19 35.34 4.19 0.00 Ambient Air Impact Analysis Thresholds 40 — 100 5 New Source Review Thresholds 40 40 100 10 Trigger New Source Review? NO NO NO NO Trigger Modeling? NO — NO NO Highest Individual HAP 14.6 tpy Total HAP 35.5 tpy Enterprise Compressor Station is a synthetic minor source of criteria pollutants (NOx, S02, VOC, CO, PM, PM to, PM2.$) with respect to PSD permitting(i.e., emissions <250 tpy) and will remain a synthetic minor source after the emission increases described above. Therefore, Enterprise is not subject to PSD review at this time. This Title V Operating Permit modification application includes the following attachments: A. APEN Fees B. APEN Forms (D-2) C. Emission Calculations and Supporting Documentation D. Facilitywide Emission Summary- Form APCD-102 E. Updated O&M Plan (D-2) F. Facility Process Flow Diagram and Plot Plan G. Updated Compliance Assurance Monitoring (CAM) Plan H. Colorado Title V Operating Permit Forms 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'dl)CPMidstream.com. Sincerely, DCP Operating Company, LP Roshini Shankaran Senior Environmental Engineer Enclosures Natural Gas Dehydration Enterprise Compressor Station DCP Operating Company,LP Source ID 0-2. • Stripping Gas? N Y/N Description 110 MM0/;Ft7[.30.61 What is Stripping Gas? Manufacturer FOrt.fn: Stripping Gas Flow Rate 0/0 scam Model Custom Condenser? N'Y/N Serial# (Custom Condenser Temperature deg F Operation Date 11;)/2001 Condenser Pressure psia GLYCaic Model Date Oct.lb Combustor? B Y/N Operation 8760 hr/yr Combustor Ambient Air Temp i•••,0 deg F Wet Gas Temperature 105 deq F - Combustor Excess Oxygen (i% Wet Gas Pressure 920 psiq Combustor Destruction Efficiency 95.00%% Wet Gas Water Content Saturated IbH2O/MMscf Combustor Downtime 1.00%Uncontrolled Dry Gas Flow Rate 110 MMscfd Dry Gas Water Content 7,0 IbH2O/MM5cf Lean Glycol Water Content 1.0 wt%H2O `Condenser used for removing water from regen overhead stream ONLY,no emissions control claimed,Please Lean Glycol Flow Rate 20 gpm see footnote#12 below for details. Cold Separator? N Y/N Cold Separator Temperature N/A deg F Cold Separator Pressure N/A psig Glycol Pump Make&Model Rotor Tech GS2212 Glycol Pump Type Etectnc Elec.or Gas Glycol Pump Gas Flow Rate N/A acfm/gpm Flash Tank? V YIN Flash Tank Temperature 140 deg F • Flash Tank Pressure 35 psiq Flash Tank Control 100.00%Recycled to Inlet VRU Downtime 5.00%Routed to ECD Total Emissions from GRI-GLYCaIc 4.0 Uncontrolled Controlled CAS Emissions Emissions Pollutant Number (lb/hr) (Ib/yr) (tpy) .10%(tpy) (lb/hr) (Ib/yr) (tpy) +10%(tpy) VOC 137.6 1205456 602.73 663.00 5.2 45374 22.69 24.96 n-hexane 110-54-3 2.93 25624 12.81 14.09 0.09 828 0.41 0.46 Benzene 71-43-2 15,85 _ 138844 69.42 76.36 0.91 7999 4.00 4.40 Toluene 108-88-3 26.03 228054 114.03 125.43 1,52 13281 6.64 7.30 Ethylbenzene 100-41-4 0.85 7456 3.73 4.10 0.05 438 0.22 0.24 Xylene 1330-20-7 6.23 54542 27.27 30.00 0.37 3217 1.61 1.77 2,2,4-Temethylpentane 540-84-1 0.00 19 0.01 0.01 0.00 1 0.00 0.0003 Total HAP 51.89 454538 227.27 250.00 2.94 25763 12.88 14.17 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-1). Uncontrolled Emissions CAS Flash Emissions' Still Vent Emissions Total Dehy Emissions' Emission Factors Pollutant Number (tpy) (ipy} (tpy) (lb/yr) (Ib/MMscf) VOC 231.15 371.58 • V502.73 33.03 n-Hexane 110-54-3 6.11 6 70 12.81 25624 0.70 , Benzene 71.43-2 2.30 07.12 69,42 138844 3.80 Toluene • T108-88-3 2.53 11150 114.03 228054 6.25 Ethylbenzene 100-41-4 0.05 3.68 3.73 74e6 0.20 Xylene 1330-20-7 0.25 27.02 27.27 54542 1.49 2.2,4-Trimethyipentane 540-84.1 0.00 0.01 0.01 19 0.001 Total HAP 11.24 216.03 227.27 12.45 1.Flash emissions and regen emissions(uncontrolled potential to emit)obtained from GlyCalc report dated 1012018 2,Total dehy emissions calculated as a sum of Flash and Still Vent emissions. Flash Tank Emissions Flash Tank VRU Total Flash Tank Emissions' CAS Uptime Emissions l Flash Tank VRU Downtime Emissions° Pollutant Number (tpy) (tpy) (tpy) VOC 0.00 0.678 0.678 n-Hexane 110-54-3 0.00 0.015 0.015 Benzene 71-43-2 0.00 0.006 0.006 Toluene 108-88.3 0.00 0,006 0.006 Ethylbenzene 100-41-4 0.00 0.00012 0.00012 Xylene 1330-20-7 0.00 0.0006 0.0006 2,2.4-Trimethylpentane 540-84-1 0.00 0.0000 0.0000 Total HAP 0.00 0.028 0.03 3.No emissions dunng VRU uptime,100%recycled to process. 4.VRU downtime emissions refer to emissions during a maximum of 5%VRU downtime for maintenance and malfunctions.These emissions are normally routed to the enclosed combustor ECD.No overlap of VRU and ECD downtimes was assumed for this calculation. 5.Total flash tank emissions is the sum of flash tank VRU uptime and downtime emissions. Still Vent Emissions Still Vent ECD Total Still Vent Emissions s CAS Uptime Emissions' Still Vent ECD Downtime Emissions 3 Pollutant Number (tpy) (tpy) (tpy) VOC 18.393 3.716 22.11 n-Hexane 110-54-3 0.332 0.067 0.40 Benzene 71-43-2 3.322 0.671 3.99 Toluene 108-88-3 5.519 1.115 6.63 Ethylbenzene 100-41-4 0.182 0.037 0,22 Xylene 1330-20-7 1.337 0.270 1.61 2,2,4-Tsmethylpentane 540-84-1 0.000 0.000 0.00 Total HAP 10.693 2.160 12.85 6.ECD control emissions refer to regen emissions controlled by the enclosed combustor(during 99%annual uptime). 7.ECD downtime emissions refer to emissions during a maximum of 1%enclosed combustor downtime for maintenance and malfunctions. 8.Total still vent emissions is a sum of still vent ECU control and ECD downtime emissions. Total Controlled Emissions{PTE) CAS Dehy Emissions' Dehy Emissions+10%Buffet Overall System Control" Pollutant Number (tpy) (tpy) VOC 22.69 24.96 n-Hexane 110-54-3 0.41 0.46 . Benzene 71-43-2 4.00 4.40 Toluene 108-88-3 6.64 — 7.30 _--.—..— 96.,,, Ethylbenzene 10041-4 0.22 0.24 Xylene 1330-20-7 1.61 1.77 2,2,4-Trimethylpentane 540-84-1 0.00 0.00 Total HAP 12.88 14,17 9.Total controlled dehydrator emissions calculated as a sum of controlled still vent emissions,combined with emissions dunng control device downtime 10.DCP is adding a 10%buffer to controlled emissions for variability 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] Natural Gas Dehydration Flash Tank Off Gas Stream Detail from GRI•GLYCaIc 4.0 Description Flash Tank Off Gas Stream Vent Flow Rate 1510 0 scf/hr Hours of operation 8780 hr/yr Annual Flow Rate 13.228 MMscf/yr Pure Component Pure ' Component Component Fraction Component Component Fraction Component Vol% Mol Fraction Mol Weight Mol Weight Mass Fraction Heat Value Heat Value (Ib/lb-mol) (lb/lb-mot) (Btu/scf) (Btu/scf)' Water 0.53 0.00527 18.02 0.09 0.0030 0 0.0 Carbon Dioxide 12.70 0.127 44.01 5.59 0.1746 0 0,0 Nitrogen 0.59 0.00989 28 0.28 • 0.0087 0 0.0 Methane 41.900 0.4190 16.04 6.72 0.2100 1010.0 423.2 Ethane 20,100 0.2010 30.07 6.04 0.1888 1769.6 355.7 • Propane 11.700 0.1170 44.10 5.16 0.1612 2516.1 294.4 i-Butane 1990 0.0199 58.12 1.16 - 0.0361 3251.9 64.7 n-Butane 0.290 0.0529 58.12 3.07 0.0961 , 3262.3 172.6 i-Pentane 1 210 0.0121 7215 0.87 0.0273 4000.9 48.4 n-Pentane 1.540 0.0154 72.15 1.11 0.0347 4008.9 61.7 Cyclopentane 0,117 0.0012 70.13 0.08 0.0026 3763.6 4.4 n-Hexane 0.407 0.0041 86.18 0.35 0.0110 4755.9 19.4 • Cyclohexane 0.180 0,0018 84.16 0.15 •0.0047 4481.5 8.1 Other Hexanes 0.558 0,0056 86.18 0.48 O.0150 4755.9 26,5 Heptanes 0.321 0.0032 100.20 0.32 0.0101 5502.5 17.7 Methylcyclohexane 0120 0.0012 98.19 0.12 0.0037 5215.7 6.3 2,2,4-Trimethylpentane 0.000 0.0000 114.23 0.00 0.0000 6231.7 0.0 Benzene U.1159 0.0017 78.11 0.13 0.0041 3741.8 6.3 Toluene 0,,157 0.0016 92.14 0,14 0.0045 4475.0 7.0 Ethyibenzene 0,0000 106.17 0.00 0,0001 5222.2 0.1 • Xytenes , 0.0001 318.50 0.04 _ 0.0014 5208.8 0.7 Octanes s ).'OoO 0.0007 114.23 0.08 0,0024 6248,9 4.1 • 100.06 1.0006 32.00 1.00 1521 Condenser Vent Stream Detail from GRI-GLYCatc 4.0'2 Description C.Crtdeirser Vent Steam Vent Flow Rate 738.00 scf/hr Hours of operation 6760,hr/yr Annual Flow Rate 6.465 MMscf/yr Pure Component Pure Component Component Fraction Component Component Fraction Component Vol 39 Mol Fraction Mot Weight Mal Weight Mass Fraction Heat Value Heat Value (Ib/Ib-mol) (Ib/lb-mol) (Btu/scf) (Btu/scf) Water _ .3960 0.396 18.02 7.14 0,1414 0 0.0 Carbon Dioxide 9.17 0.0917 44.01 4.04 0.0799 0 0.0 Hydrogen Sulfide 0.00 0 34.1 0.00 0.0000 0 0.0 Nitrogen 0,06 0.000638 28 0.02 0.0004 0 0,0 Methane 2.70 0,0279 16.04 0.45 0.0089 1010,0 28,2 Ethane 4 53 0.0453 30.07 1.36 0.0270 1769.6 80.2 Propane 5.61 0.0561 44.10 2.47 0,0490 2516.1 141.2 i-Butane 1.40. 0.0140 58.12 0.81 0.0161 3251.9 45.5 n-Butane 4.6'2 0.0482 58.12 2,80 0.0555 3262.3 157.2 i-Pentane 1.23 0.0123 _ 72.15 0.89 0.0176 4000.9 49.2 n-Pentane 1.90 0.0190 72.15 1.37 0.0272 4008.9 76,2 Cyclopentane 0 56. 0,0056 70.13 0.39 0.0078 3763.9 21.1 n-Hexane 0,88 0.0086 86.18 0.74 0.0148 4755,9 41.1 Cydohexane 1.47 0.0147 84.16 1.24 0.0245 4481.5 65,9 Other Hexanes 0 52 0.0092 86.18 0.79 0.0156 4755.9 43.5 Heptanes 1,25 0.0126 100,20 126 0.0250 5502.5 69.3 Methylcyclohexane 1'119 0.0116 98.19 1.14 0.0226 5215.7 60.5 2,2.4-Trimethyipentane 0 000 0.0000 114.23 0.00 0.0000 6231.7 0.0 Benzene 910 0.0919 78.11 7,18 0.1422 3741,8 343.9 Toluene 11.40 0.1140 92.14 10.50 0,2081 4475.0 510.2 Ethylbenzene 0.240 0.0024 106.17 0,25 0.0050 5222.2 12.5 Xytenes 1.71 0.0171 318.50 5.45 0.1079 5208.8 89.1 - Octanes+ 0,160 0.0016 114.23 0.18 0.0036 6248.9 10.0 100.04 1.0004 50,48 1.00 1845 12.An additional GLYCalc run was performed including the condenser used as a secondary control device on unit D-2,to determine the waste gas flowrate and heat content going to the enclosed combustor,The primary GLYCatc run for this unit omits the condenser,to ensure that no condenser control is claimed in the overall emission calculations.Both the primary GLYCaic run,and an abridged version of the additional GLYCaIc run,have been included in Attachment C of this application. D-2 Glycol Dehy Calculations Uncontrolled Emissions Uncontrolled Emissions are taken directly from GLYCaIc. Emission Factor lb =Uncontrolled Emissions tons *2,000 lb * day * 1 year MMscf year ton Dehy Throughput MMscf 365 days Flash Tank Emissions Flash Tank VRU Uptime Emissions tons = Uncontrolled Flash Tank Emissions tons *(1-Flash Tank Control Efficiency) year year Flash Tank is controlled with VRU that recycles 100%of flash tank emissions to inlet,while online Flash Tank VRU Downtime Emissions tons = Uncontrolled Flash Tank Emissions tons *(VRU Downtime Percentage)*(1-ECD Control Efficiency) year year Flash Tank emissions are routed to enclosed combustor(ECD)during VRU downtime(5%annually),with a control efficiency of 95% Total Flash Tank Emissions=VRU uptime emissions+VRU downtime emissions Regen/Still Vent Emissions ECD Uptime Emissions tons = Uncontrolled Regen Emissions tons *(1-ECD downtime percentage)*(1-ECD Control Efficiency) year year Regen/Still Vent is controlled with ECD that has a control efficiency of 95%.ECD has a 1%annual downtime associated with maintenance and repairs,during which emissions for the still vent,vent to atmosphere. ECD Downtime Emissions tons = Uncontrolled Regen Emissions tons *(ECD Downtime Percentage) year year Still Vent emissions are vented to atmosphere during 1%annual ECD downtime. Total Regen Emissions=ECD uptime emissions+ECD downtime emissions Total Dehy Emissions Total Dehy Emissions=Total Flash Tank Emissions+Total Regen Emissions Overall Control Efficiency=1-Total Dehy VOC Emissions Uncontrolled V0C Emissions D-2 Inputs (No Condenser).txt GRI-GLYCalc VERSION 4.0 - SUMMARY OF INPUT VALUES Case Name: Enterprise TEG Dehydration Unit D2 File Name: \\dennas00\Data\Environmental\Air\Colorado\Enterprise\TV Renewal\2018-09 - TV Sig Mod - TEG Corrections, Engine Fuel Limit Increase\02. Emissions\GLYCalc\D2 GLYCalc (3rd QTR 2017 EGA).ddf Date: October 29, 2018 DESCRIPTION: Description: 110 MMscfd 20 gpm Glycol circ rate Inlet Gas Temp: 105 F Inlet Gas Pressure: 920 psig 3rd QTR 2017 EGA Annual Hours of Operation: 8760.0 hours/yr WET GAS: Temperature: 105.00 deg. F Pressure: 920.00 psig Wet Gas Water Content: Saturated Component Conc. (vol %) Carbon Dioxide 2.4100 Nitrogen 1.4608 Methane 72.4397 Ethane 13.2963 Propane 5.9729 Isobutane 0.8741 n-Butane 1.9407 Isopentane 0.4951 n-Pentane 0.5382 Cyclopentane 0.0197 n-Hexane 0.1259 Cyclohexane 0.0307 Other Hexanes 0.1926 Heptanes 0.0905 Methylcyclohexane 0.0245 Page 1 D-2 Inputs (No Condenser).txt 2,2,4-Trimethylpentane 0.0001 Benzene 0.0197 Toluene 0.0213 Ethylbenzene 0.0005 Xylenes 0.0027 C8+ Heavies 0.0456 DRY GAS: Flow Rate: 110.0 MMSCF/day Water Content: 7.0 lbs. H2O/MMSCF LEAN GLYCOL: Glycol Type: TEG Water Content: 1.0 wt% H2O Flow Rate: 20.0 gpm PUMP: Glycol Pump Type: Electric/Pneumatic FLASH TANK: Flash Control: Recycle/recompression Temperature: 140.0 deg. F Pressure: 35.0 psig Page 2 D-2 Agg (No Condenser).txt GRI-GLYCalc VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name: Enterprise TEG Dehydration Unit D2 File Name: \\dennas00\Data\Environmental\Air\Colorado\Enterprise\TV Renewal\2018-09 - TV Sig Mod - TEG Corrections, Engine Fuel Limit Increase\02. Emissions\GLYCalc\D2 GLYCalc (3rd QTR 2017 EGA).ddf Date: October 29, 2018 DESCRIPTION: Description: 110 MMscfd 20 gpm Glycol circ rate Inlet Gas Temp: 105 F Inlet Gas Pressure: 920 psig 3rd QTR 2017 EGA Annual Hours of Operation: 8760.0 hours/yr EMISSIONS REPORTS: UNCONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.8716 20.919 3.8176 Ethane 2.6523 63.655 11.6170 Propane 4.8305 115.932 21.1577 Isobutane 1.5956 38.294 6.9887 n-Butane 5.4995 131.989 24.0879 Isopentane 1.7672 42.414 7.7405 n-Pentane 2.7513 66.030 12.0505 Cyclopentane 0.7944 19.067 3.4797 n-Hexane 1.5303 36.726 6.7026 Cyclohexane 2.6037 62.489 11.4042 Other Hexanes 1.6025 38.460 7.0190 Heptanes 2.7998 67.195 12.2631 Methylcyclohexane 2.5408 60.980 11.1289 2,2,4-Trimethylpentane 0.0012 0.028 0.0051 Benzene 15.3239 367.773 67.1186 Page 1 D-2 Agg (No Condenser).txt Toluene 25.4570 610.968 111.5017 Ethylbenzene 0.8399 20.158 3.6788 Xylenes 6.1688 148.052 27.0194 C8+ Heavies 8.7297 209.513 38.2361 Total Emissions 88.3601 2120.642 387.0172 Total Hydrocarbon Emissions 88.3601 2120.642 387.0172 Total VOC Emissions 84.8362 2036.069 371.5826 Total HAP Emissions 49.3211 1183.705 216.0262 Total BTEX Emissions 47.7896 1146.951 209.3186 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 26.7194 641.264 117.0308 Ethane 24.0490 577.176 105.3346 Propane 20.4587 491.008 89.6090 Isobutane 4.5958 110.299 20.1296 n-Butane 12.2198 293.275 53.5227 Isopentane 3.4811 83.547 15.2473 n-Pentane 4.4122 105.892 19.3253 Cyclopentane 0.3255 7.812 1.4257 n-Hexane 1.3948 33.476 6.1093 Cyclohexane 0.6043 14.502 2.6467 Other Hexanes 1.9125 45.901 8.3769 Heptanes 1.2812 30.750 5.6118 Methylcyclohexane 0.4679 11.231 2.0496 2,2,4-Trimethylpentane 0.0010 0.025 0.0045 Benzene 0.5259 12.622 2.3035 Toluene 0.5765 13.836 2.5251 Ethylbenzene 0.0112 0.269 0.0491 Xylenes 0.0574 1.378 0.2515 C8+ Heavies 0.4470 10.728 1.9579 Page 2 D-2 Agg (No Condenser).txt Total Emissions 103.5413 2484.991 453.5108 Total Hydrocarbon Emissions 103.5413 2484.991 453.5108 Total VOC Emissions 52.7729 1266.551 231.1455 Total HAP Emissions 2.5669 61.606 11.2430 Total BTEX Emissions 1.1711 28.105 5.1292 EQUIPMENT REPORTS: ABSORBER NOTE: Because the Calculated Absorber Stages was below the minimum allowed, GRI-GLYCalc has set the number of Absorber Stages to 1.25 and has calculated a revised Dry Gas Dew Point. Calculated Absorber Stages: 1.25 Calculated Dry Gas Dew Point: 3.79 lbs. H20/MMSCF Temperature: 105.0 deg. F Pressure: 920.0 psig Dry Gas Flow Rate: 110.0000 MMSCF/day Glycol Losses with Dry Gas: 3.5545 lb/hr Wet Gas Water Content: Saturated Calculated Wet Gas Water Content: 72.42 lbs. H20/MMSCF Calculated Lean Glycol Recirc. Ratio: 3.81 gal/lb H2O Remaining Absorbed Component in Dry Gas in Glycol Water 5.23% 94.77% Carbon Dioxide 99.77% 0.23% Nitrogen 99.98% 0.02% Methane 99.98% 0.02% Ethane 99.94% 0.06% Propane 99.92% 0.08% Isobutane 99.90% 0.10% n-Butane 99.87% 0.13% Isopentane 99.88% 0.12% Page 3 D-2 Agg (No Condenser).txt n-Pentane 99.85% 0.15% Cyclopentane 99.33% 0.67% n-Hexane 99.78% 0.22% Cyclohexane 98.97% 1.03% Other Hexanes 99.82% 0.18% Heptanes 99.63% 0.37% Methylcyclohexane 98.97% 1.03% 2,2,4-Trimethylpentane 99.84% 0.16% Benzene 91.48% 8.52% Toluene 89.02% 10.98% Ethylbenzene 86.73% 13.27% Xylenes 82.02% 17.98% C8+ Heavies 99.02% 0.98% FLASH TANK Flash Control: Recycle/recompression Flash Temperature: 140.0 deg. F Flash Pressure: 35.0 psig Left in Removed in Component Glycol Flash Gas Water 99.91% 0.09% Carbon Dioxide 26.13% 73.87% Nitrogen 3.06% 96.94% Methane 3.16% 96.84% Ethane 9.93% 90.07% Propane 19.10% 80.90% Isobutane 25.77% 74.23% n-Butane 31.04% 68.96% Isopentane 34.00% 66.00% n-Pentane 38.71% 61.29% Cyclopentane 71.08% 28.92% n-Hexane 52.55% 47.45% Cyclohexane 81.77% 18.23% Other Hexanes 46.13% 53.87% Heptanes 68.76% 31.24% Methylcyclohexane 85.07% 14.93% Page 4 D-2 Agg (No Condenser).txt 2,2,4-Trimethylpentane 53.45% 46.55% Benzene 96.85% 3.15% Toluene 97.96% 2.04% Ethylbenzene 98.82% 1.18% Xylenes 99.20% 0.80% C8+ Heavies 95.72% 4.28% REGENERATOR No Stripping Gas used in regenerator. Remaining Distilled Component in Glycol Overhead Water 26.35% 73.65% Carbon Dioxide 0.00% 100.00% Nitrogen 0.00% 100.00% Methane 0.00% 100.00% Ethane 0.00% 100.00% Propane 0.00% 100.00% Isobutane 0.00% 100.00% n-Butane 0.00% 100.00% Isopentane 1.47% 98.53% n-Pentane 1.29% 98.71% Cyclopentane 0.70% 99.30% n-Hexane 0.95% 99.05% Cyclohexane 3.91% 96.09% Other Hexanes 2.17% 97.83% Heptanes 0.73% 99.27% Methylcyclohexane 4.70% 95.30% 2,2,4-Trimethylpentane 2.81% 97.19% Benzene 5.16% 94.84% Toluene 8.07% 91.93% Ethylbenzene 10.54% 89.46% Xylenes 13.04% 86.96% C8+ Heavies 12.57% 87.43% Page 5 D-2 Agg (No Condenser).txt STREAM REPORTS: WET GAS STREAM Temperature: 105.00 deg. F Pressure: 934.70 psia Flow Rate: 4.59e+006 scfh Component Conc. Loading (vol%) (lb/hr) Water 1.53e-001 3.33e+002 Carbon Dioxide 2.41e+000 1.28e+004 Nitrogen 1.46e+000 4.94e+003 Methane 7.23e+001 1.40e+005 Ethane 1.33e+001 4.83e+004 Propane 5.96e+000 3.18e+004 Isobutane 8.73e-001 6.14e+003 n-Butane 1.94e+000 1.36e+004 Isopentane 4.94e-001 4.32e+003 n-Pentane 5.37e-001 4.69e+003 Cyclopentane 1.97e-002 1.67e+002 n-Hexane 1.26e-001 1.31e+003 Cyclohexane 3.07e-002 3.12e+002 Other Hexanes 1.92e-001 2.01e+003 Heptanes 9.04e-002 1.10e+003 Methylcyclohexane 2.45e-002 2.91e+002 2,2,4-Trimethylpentane 9.98e-005 1.38e+000 Benzene 1.97e-002 1.86e+002 Toluene 2.13e-002 2.37e+002 Ethylbenzene 4.99e-004 6.41e+000 Xylenes 2.70e-003 3.46e+001 C8+ Heavies 4.55e-002 9.39e+002 Total Components 100.00 2.74e+005 DRY GAS STREAM Temperature: 105.00 deg. F Page 6 D-2 Agg (No Condenser).txt Pressure: 934.70 psia Flow Rate: 4.58e+006 scfh Component Conc. Loading (vol%) (lb/hr) Water 7.99e-003 1.74e+001 Carbon Dioxide 2.41e+000 1.28e+004 Nitrogen 1.46e+000 4.94e+003 Methane 7.25e+001 1.40e+005 Ethane 1.33e+001 4.83e+004 Propane 5.97e+000 3.18e+004 Isobutane 8.74e-001 6.13e+003 n-Butane 1.94e+000 1.36e+004 Isopentane 4.95e-001 4.31e+003 n-Pentane 5.38e-001 4.69e+003 Cyclopentane 1.96e-002 1.66e+002 n-Hexane 1.26e-001 1.31e+003 Cyclohexane 3.04e-002 3.09e+002 Other Hexanes 1.92e-001 2.00e+003 Heptanes 9.02e-002 1.09e+003 Methylcyclohexane 2.43e-002 2.88e+002 2,2,4-Trimethylpentane 9.99e-005 1.38e+000 Benzene 1.80e-002 1.70e+002 Toluene 1.90e-002 2.11e+002 Ethylbenzene 4.34e-004 5.56e+000 Xylenes 2.22e-003 2.84e+001 C8+ Heavies 4.52e-002 9.29e+002 Total Components 100.00 2.73e+005 LEAN GLYCOL STREAM Temperature: 105.00 deg. F Flow Rate: 2.00e+001 gpm Component Conc. Loading (wt%) (lb/hr) TEG 9.89e+001 1.11e+004 Water 1.00e+000 1.13e+002 Carbon Dioxide 2.68e-011 3.01e-009 Page 7 D-2 Agg (No Condenser).txt Nitrogen 1.01e-012 1.14e-010 Methane 8.23e-018 9.27e-016 Ethane 1.12e-007 1.26e-005 Propane 9.14e-009 1.03e-006 Isobutane 1.65e-009 1.86e-007 n-Butane 3.90e-009 4.39e-007 Isopentane 2.34e-004 2.64e-002 n-Pentane 3.20e-004 3.60e-002 Cyclopentane 5.00e-005 5.63e-003 n-Hexane 1.31e-004 1.47e-002 Cyclohexane 9.42e-004 1.06e-001 Other Hexanes 3.15e-004 3.55e-002 Heptanes 1.82e-004 2.05e-002 Methylcyclohexane 1.11e-003 1.25e-001 2,2,4-Trimethylpentane 2.96e-007 3.33e-005 Benzene 7.41e-003 8.34e-001 Toluene 1.98e-002 2.23e+000 Ethylbenzene 8.79e-004 9.89e-002 Xylenes 8.22e-003 9.25e-001 C8+ Heavies 1.12e-002 1.26e+000 Total Components 100.00 1.13e+004 RICH GLYCOL STREAM Temperature: 105.00 deg. F Pressure: 934.70 psia Flow Rate: 2.11e+001 gpm NOTE: Stream has more than one phase. Component Conc. Loading (wt%) (lb/hr) TEG 9.44e+001 1.11e+004 Water 3.63e+000 4.28e+002 Carbon Dioxide 2.55e-001 3.01e+001 Nitrogen 9.64e-003 1.14e+000 Methane 2.34e-001 2.76e+001 Ethane 2.26e-001 2.67e+001 Propane 2.14e-001 2.53e+001 Isobutane 5.25e-002 6.19e+000 Page 8 D-2 Agg (No Condenser).txt n-Butane 1.50e-001 1.77e+001 Isopentane 4.47e-002 5.27e+000 n-Pentane 6.11e-002 7.20e+000 Cyclopentane 9.55e-003 1.13e+000 n-Hexane 2.49e-002 2.94e+000 Cyclohexane 2.81e-002 3.31e+000 Other Hexanes 3.01e-002 3.55e+000 Heptanes 3.48e-002 4.10e+000 Methylcyclohexane 2.66e-002 3.13e+000 2,2,4-Trimethylpentane 1.89e-005 2.22e-003 Benzene 1.41e-001 1.67e+001 Toluene 2.40e-001 2.83e+001 Ethylbenzene 8.06e-003 9.50e-001 Xylenes 6.06e-002 7.15e+000 C8+ Heavies 8.85e-002 1.04e+001 Total Components 100.00 1.18e+004 FLASH TANK OFF GAS STREAM Temperature: 140.00 deg. F Pressure: 49.70 psia Flow Rate: 1.51e+003 scfh Component Conc. Loading (vol%) (lb/hr) Water 5.27e-001 3.77e-001 Carbon Dioxide 1.27e+001 2.22e+001 Nitrogen 9.89e-001 1.10e+000 Methane 4.19e+001 2.67e+001 Ethane 2.01e+001 2.40e+001 Propane 1.17e+001 2.05e+001 Isobutane 1.99e+000 4.60e+000 n-Butane 5.29e+000 1.22e+001 Isopentane 1.21e+000 3.48e+000 n-Pentane 1.54e+000 4.41e+000 Cyclopentane 1.17e-001 3.26e-001 n-Hexane 4.07e-001 1.39e+000 Cyclohexane 1.80e-001 6.04e-001 Other Hexanes 5.58e-001 1.91e+000 Page 9 D-2 Agg (No Condenser).txt Heptanes 3.21e-001 1.28e+000 Methylcyclohexane 1.20e-001 4.68e-001 2,2,4-Trimethylpentane 2.28e-004 1.03e-003 Benzene 1.69e-001 5.26e-001 Toluene 1.57e-001 5.77e-001 Ethylbenzene 2.65e-003 1.12e-002 Xylenes 1.36e-002 5.74e-002 C8+ Heavies 6.60e-002 4.47e-001 Total Components 100.00 1.27e+002 FLASH TANK GLYCOL STREAM Temperature: 140.00 deg. F Flow Rate: 2.08e+001 gpm Component Conc. Loading (wt%) (lbfhr) TEG 9.55e+001 1.11e+004 Water 3.66e+000 4.27e+002 Carbon Dioxide 6.75e-002 7.87e+000 Nitrogen 2.98e-004 3.47e-002 Methane 7.47e-003 8.72e-001 Ethane 2.27e-002 2.65e+000 Propane 4.14e-002 4.83e+000 Isobutane 1.37e-002 1.60e+000 n-Butane 4.71e-002 5.50e+000 Isopentane 1.54e-002 1.79e+000 n-Pentane 2.39e-002 2.79e+000 Cyclopentane 6.86e-003 8.00e-001 n-Hexane 1.32e-002 1.54e+000 Cyclohexane 2.32e-002 2.71e+000 Other Hexanes 1.40e-002 1.64e+000 Heptanes 2.42e-002 2.82e+000 Methylcyclohexane 2.29e-002 2.67e+000 2,2,4-Trimethylpentane 1.02e-005 1.19e-003 Benzene 1.39e-001 1.62e+001 Toluene 2.37e-001 2.77e+001 Ethylbenzene 8.05e-003 9.39e-001 Page 10 D-2 Agg (No Condenser) .txt Xylenes 6.08e-002 7.09e+000 C8+ Heavies 8.56e-002 9.99e+000 Total Components 100.001.17e+004 FLASH GAS EMISSIONS Control Method: Recycle/recompression Control Efficiency: 100.00 Note: Flash Gas Emissions are zero with the Recycle/recompression control option. REGENERATOR OVERHEADS STREAM Temperature: 212.00 deg. F Pressure: 14.70 psia Flow Rate: 7.14e+003 scfh Component Conc. Loading (vol%) (lb/hr) Water 9.29e+001 3.15e+002 Carbon Dioxide 9.50e-001 7.87e+000 Nitrogen 6.59e-003 3.47e-002 Methane 2.89e-001 8.72e-001 Ethane 4.69e-001 2.65e+000 Propane 5.82e-001 4.83e+000 Isobutane 1.46e-001 1.60e+000 n-Butane 5.03e-001 5.50e+000 Isopentane 1.30e-001 1.77e+000 n-Pentane 2.03e-001 2.75e+000 Cyclopentane 6.02e-002 7.94e-001 n-Hexane 9.44e-002 1.53e+000 Cyclohexane 1.64e-001 2.60e+000 Other Hexanes 9.88e-002 1.60e+000 Heptanes 1.48e-001 2.80e+000 Methylcyclohexane 1.38e-001 2.54e+000 2,2,4-Trimethylpentane 5.37e-005 1.15e-003 Benzene 1.04e+000 1.53e+001 Toluene 1.47e+000 2.55e+001 Page 11 D-2 Agg (No Condenser).txt Ethylbenzene 4.20e-002 8.40e-001 Xylenes 3.09e-001 6.17e+000 C8+ Heavies 2.72e-001 8.73e+000 Total Components 100.00 4.11e+002 Page 12 D-2 Inputs (Condenser).txt GRI-GLYCalc VERSION 4.0 - SUMMARY OF INPUT VALUES Case Name: Enterprise TEG Dehydration Unit D2 File Name: \\dennas00\Data\Environmental\Air\Colorado\Enterprise\TV Renewal\2018-09 - TV Sig Mod - TEG Corrections, Engine Fuel Limit Increase\02. Emissions\GLYCalc\D2 GLYCalc (3rd QTR 2017 EGA) + Condenser.ddf Date: October 29, 2018 DESCRIPTION: Description: 110 MMscfd 20 gpm Glycol circ rate Inlet Gas Temp: 105 F Inlet Gas Pressure: 920 psig Condenser added for Still Vent Btu content ONLY Annual Hours of Operation: 8760.0 hours/yr WET GAS: Temperature: 105.00 deg. F Pressure: 920.00 psig Wet Gas Water Content: Saturated Component Conc. (vol %) Carbon Dioxide 2.4100 Nitrogen 1.4608 Methane 72.4397 Ethane 13.2963 Propane 5.9729 Isobutane 0.8741 n-Butane 1.9407 Isopentane 0.4951 n-Pentane 0.5382 Cyclopentane 0.0197 n-Hexane 0.1259 Cyclohexane 0.0307 Other Hexanes 0.1926 Heptanes 0.0905 Methylcyclohexane 0.0245 Page 1 D-2 Inputs (Condenser).txt 2,2,4-Trimethylpentane 0.0001 Benzene 0.0197 Toluene 0.0213 Ethylbenzene 0.0005 Xylenes 0.0027 C8+ Heavies 0.0456 DRY GAS: Flow Rate: 110.0 MMSCF/day Water Content: 7.0 lbs. H2O/MMSCF LEAN GLYCOL: Glycol Type: TEG Water Content: 1.0 wt% H2O Flow Rate: 20.0 gpm PUMP: Glycol Pump Type: Electric/Pneumatic FLASH TANK: Flash Control: Recycle/recompression Temperature: 140.0 deg. F Pressure: 35.0 psig REGENERATOR OVERHEADS CONTROL DEVICE: Control Device: Condenser Page 2 D-2 Inputs (Condenser).txt Temperature: 160.0 deg. F Pressure: 12.0 psia II Page 3 D-2 Agg (Condenser).txt GRI-GLYCalc VERSION 4.0 - AGGREGATE CALCULATIONS REPORT Case Name: Enterprise TEG Dehydration Unit D2 File Name: \\dennas00\Data\Environmental\Air\Colorado\Enterprise\TV Renewal\2018-09 - TV Sig Mod - TEG Corrections, Engine Fuel Limit Increase\02. Emissions\GLYCalc\D2 GLYCalc (3rd QTR 2017 EGA) + Condenser.ddf Date: October 29, 2018 DESCRIPTION: Description: 110 MMscfd 20 gpm Glycol circ rate Inlet Gas Temp: 105 F Inlet Gas Pressure: 920 psig Condenser added for Still Vent Btu content ONLY Annual Hours of Operation: 8760.0 hours/yr EMISSIONS REPORTS: CONTROLLED REGENERATOR EMISSIONS Component lbs/hr lbs/day tons/yr Methane 0.8714 20.913 3.8166 Ethane 2.6494 63.586 11.6045 Propane 4.8091 115.419 21.0639 Isobutane 1.5832 37.996 6.9342 n-Butane 5.4439 130.654 23.8444 Isopentane 1.7206 41.295 7.5364 n-Pentane 2.6663 63.990 11.6782 Cyclopentane 0.7650 18.359 3.3505 n-Hexane 1.4486 34.766 6.3448 Cyclohexane 2.4064 57.755 10.5402 Other Hexanes 1.5336 36.807 6.7174 Heptanes 2.4656 59.174 10.7993 Methylcyclohexane 2.2131 53.113 9.6932 2,2,4-Trimethylpentane 0.0010 0.024 0.0044 Benzene 13.9627 335.104 61.1565 Page 1 D-2 Agg (Condenser).txt REGENERATOR OVERHEADS STREAM Temperature: 212.00 deg. F Pressure: 14.70 psia Flow Rate: 7.14e+003 scfh Component Conc. Loading (vol%) (lb/hr) Water 9.29e+001 3.15e+002 Carbon Dioxide 9.50e-001 7.87e+000 Nitrogen 6.59e-003 3.47e-002 Methane 2.89e-001 8.72e-001 Ethane 4.69e-001 2.65e+000 Propane 5.82e-001 4.83e+000 Isobutane 1.46e-001 1.60e+000 n-Butane 5.03e-001 5.50e+000 Isopentane 1.30e-001 1.77e+000 n-Pentane 2.03e-001 2.75e+000 Cyclopentane 6.02e-002 7.94e-001 n-Hexane 9.44e-002 1.53e+000 Cyclohexane 1.64e-001 2.60e+000 Other Hexanes 9.88e-002 1.60e+000 Heptanes 1.48e-001 2.80e+000 Methylcyclohexane 1.38e-001 2.54e+000 2,2,4-Trimethylpentane 5.37e-005 1.15e-003 Benzene 1.04e+000 1.53e+001 Toluene 1.47e+000 2.55e+001 Ethylbenzene 4.20e-002 8.40e-001 Xylenes 3.09e-001 6.17e+000 C8+ Heavies 2.72e-001 8.73e+000 Total Components 100.00 4.11e+002 CONDENSER VENT GAS STREAM Temperature: 160.00 deg. F Pressure: 12.00 psia Flow Rate: 7.38e+602 scfh Component Conc. Loading Page 13 D-2 Agg (Condenser).txt (vol%) (lb/hr) Water 3.96e+001 1.39e+001 Carbon Dioxide 9.17e+000 7.85e+000 Nitrogen 6.38e-002 3.47e-002 Methane 2.79e+000 8.71e-001 Ethane 4.53e+000 2.65e+000 Propane 5.61e+000 4.81e+000 Isobutane 1.40e+000 1.58e+000 n-Butane 4.82e+000 5.44e+000 Isopentane 1.23e+000 1.72e+000 n-Pentane 1.90e+000 2.67e+000 Cyclopentane 5.61e-001 7.65e-001 n-Hexane 8.64e-001 1.45e+000 Cyclohexane1.47e+000'2.41e+000 Other Hexanes 9.15e-001 1.53e+000 Heptanes 1.26e+000 2.47e+000 Methylcyclohexane;1.16e+000 2.21e+000 2,2,4-Trimethylpentane 4.54e-004 1.01e-003 Benzene 9.19e+000 1.40e+001 Toluene 1.14e+001 2.04e+001 Ethylbenzene 2.40e-001 4.95e-001 Xylenes`1.71e+000 3.52e+000 C8+ Heavies 1.60e-001 5.32e-001 Total Components 100.00 9.12e+001 CONDENSER PRODUCED WATER STREAM Temperature: 160.00 deg. F Flow Rate: 6.02e-001 gpm Component Conc. Loading (wt%) (lb/hr) (ppm) Water 9.99e+001 3.01e+002 999284. Carbon Dioxide 4.73e-003 1.42e-002 47. Nitrogen 7.11e-007 2.14e-006 0. Methane 3.13e-005 9.43e-005 0. Ethane 1.02e-004 3.06e-004 1. Propane 2.33e-004 7.02e-004 2. Page 14 EMPACT EXTENDED NATURAL GAS ANALYSIS(*DHA1 GLYCALC INFORMATION PROJECT NO. : 201709092 ANALYSIS NO.: 05 COMPANY NAME: DCP MIDSTREAM ANALYSIS DATE: SEPTEMBER 26,2017 14:14 ACCOUNT NO. : SAMPLE DATE : SEPTEMBER 22,2017 11:45 PRODUCER CYLINDER NO. : 1751 LEASE NO. : SAMPLED BY : MATHEW PICKETT NAME/DESCRIP: ENTERPRISE BOOSTER PRE TEG "`FIELD DATA*** SAMPLE TEMP.: SAMPLE PRES. : 920 AMBIENT TEMP.: COMMENTS : SPOT MOISTURE OBSERVED IN SAMPLE Componet Mole% Wt% Helium 0.00 0.00 Hydrogen 1.23 0.11 Carbon Dioxide 2.41 4.76 Nitrogen 0.23 0.29 Methane 72.43970 52.10160 Ethane 13.2963 17.9248 Propane 5.9729 11.8083 Isobutane 0.8741 2.2778 n-Butane 1.9407 5.0572 Isopentane 0.4951 1.6015 n-Pentane 0.5382 1.7409 Cyclopentane 0.0197 0.0620 n-Hexane 0.1251 0.4833 Cyclohexane 0.0307 0.1159 Other Hexanes 0,1926 0.7407 Heptanes 0.0905 0.4050 Methycyclohexane 0.0245 0.1079 2,2,4 Trimethylpentane 0.0001 0.0005 Benzene 0.0197 0.0690 Toluene 0.0205 0.0847 Ethylbenzene 0.0005 0.0024 Xylenes 0.0027 0.0128 C8+Heavies 0.0456 0.2416 Subtotal 99.99920 99.99790 Oxygen/Argon 0.00 0.00 Alcohols 0.0008 0.0021 Total 100.00000 100.00000 EMPACT Analytical Systems Inc. 365 S Main St Brighton,CO 80601 303-637-0150 Enclosed Combustor COMB-1 Emissions Enterprise Compressor Station DCP Operating Company, LP Enclosed Combustor Fuel Usage 50 scf/hr Pilot Gas 3200 scf/hr Assist Gas 1,020 BTU/SCF Fuel Heating Value 8,760 hr/yr Hours per Year 28.47 MMscf/yr Fuel Use 3.32 MMBtu/hr Fuel Use 29,039 MMBtu/yr Fuel Use Enclosed Combustor Waste Gas Flow Usage 1845 Btu/scf Still Vent Gas Heat Value 6.46 MMscf/yr Worst-case Still Vent Gas Flowrate 11926 MMBtu/yr Still Vent To Combustor 1521 Btu/scf Flash Tank Gas Heat Value 0.66 MMscf/yr Worst-case Flash Tank Gas Flowrate 1006 MMBtu/yr Flash Tank To Combustor 29,039 MMBtu/yr Fuel Heat 12,932 MMBtu/yr D2 Overheads 41,972 MMBTU/yr Combustion Emissions at COMB-1 EF Emissions lb/MMBtu ton/yr NOx 0.068 1.43 CO 0.31 6.51 AP-42 Table 13.5-1, 13.5-2 ;Reve 1 of 3 Project No.: 11 ;Revision: D a Item/Tag � � f :Date: 13 October 2014 Project: BY 15 Enviromental Control Equipment P.O.No.: ,Checked: SG Data Sheet RFQ No.: 'Approved: MS Client: Ref.P&ID: - Site: Supplier: LEED FABRICATION • Unit/Lease: Remarks: I Model No.: L30-0018.00 GENERAL 5 Design Code: NDE: LEED Fabrication Standards 2 Service: Customer Specs: ❑ Yes 3 Description: Standard Single Stage 36 High Efficiency Combustor ❑ No PROCESS DATA Process Conditions: Gas Composition: mol% Variable Value Units 4 Methane Flow Rate Up to 99 Mscfd s Ethane Pressure Up to 12 oz/in2 6 Propane Temperature °F 7 I-Butane Molecular Weight a n-Butane Process/Waste Stream 0 Gas ❑ Liquid 9 I-Pentane Detailed Process Description/Process Notes: to n-Pentane 1.Turndown 10:1.Based on an expected normal operating rate indicated above. is n-Hexane 2.DRE:98% operating at design conditions 12 CO2 3.Burner Pressure Drop:Min.0.10 oz/in2 13 N2 14 Helium is H2O 16 C7 17 C8 18 C9 19 C10 20 C11+ 21 TOTAL Other Components: PPMV Available Utilities: 22 H2S Fuel/Pilot Gas Min.30psig Natural Gas/Propane 40-50 SCFH 23 Benzene Instrument Air NA za Toluene Power 120 V/60 Hz or Solar Power zs E-Benzene Steam NA 26 Xylene Purge Gas DESIGN DATA 27 Ambient Temperatures: Noise Performance Requirements: Under 85 d8A za Low,°F -20 Structural Design Code: 29 High,°F 120 Wind Design Code: ASCE 30 Design Conditions: Pressure/Temperature 31 Max.Relative Humidity,% 90 Pressure/Speed 32 Elevation(ASL),ft Category 33 Area Classification: Class I Div 2 Seismic Design Code: 34 Electrical Design Code: NEC Location EQUIPMENT SPECIFICATION 35 Type: ❑ Elevated 0 Enclosed Equipment Design: 36 ❑ Above Ground Component Material/Size/Rating/Other , 37 ✓❑ Stack ❑ Multiple Stack Burner 38 ❑ Portable/Trailer Burner Tip/Assist Gas Burner 304 SS 39 Burner Body Carbon Steel ao Smokeless By: O Steam ❑ Assist Air Pilot Si ❑ Gas Assist Q Staging Pilot Tip 304 SS , 42 Pilot Line(s) Carbon Steel 43 Stack: Q Self Supporting Firebox/Stack 44 Flare Burner: ❑ Non-Smokeless❑ Smokeless ❑ Gas Assist Shell Carbon Steel 45 pilot: Q Intermittent ❑ Continuous Piping Carbon Steel 46 Pilot Air lnspirator: 0 Local ❑ Remote Nozzles Carbon Steel 47 Pilot Flame Control: ❑ No 0 Yes(Thermocouple) Flanges Carbon Steel 48 Insulation Blanket 49 Pilot Ignition: ❑ Flamefront Generator p] Inspirating Ignitor Insulation Pins 304 55 so ❑ Electronic 0 Automatic ❑ Manual Refractory NA 51 ❑ With Pilot Flame Control Refractory Anchors NA 52 ❑ With Auto Pilot Re-Ignition Ladders and Platforms NA 53 Stack Sample Connections Per EPA requirements 54 Pilot Ignition Backup: ❑ Manual Specify: i.e Piezo-Electric Sight Glass 2 55 [I Battery Pack Other Enterprise Insignificant Emissions DCP Operating Company,LP NOx CO VOC Benzene n-Hexane Insignificant Acitivities (tpy) (tpy) - (tpy) J (Ib/yr) , (Iblyr) — Emission Estimation Method Insignificant Per Facilitywide Fugitive Emissions 0.96 5.32 37.25 Protocol for Equipment Leak Emission Estimates" — — — — _ EPA Publication No.4531R-95-017,Table 2-8 Regulation No.3,Part C.Section 8.9.3.a PIGGING-16"Marla Reciever — — _ — 0.45 5.75 44.70 Engineering Estimate Regulation No.3,Part C.Section II.E.3.0 PIGGING-20"Inlet Reciever — — — — 0.20 3.40 26.40 Engineenng Estimate Regulation No.3,Part C,Section II.E.3.a PIGGING-12"Inlet Reciever — — — — 0.10 4.11 31.94 Engineenng Estimate Regulation No,3.Part C.Section 11.9.3.0 PIGGING-20"Launcher — — — — 0.93 4.24 31.04 Engineenng Estimate Regulation No.3.Part C.Section II.E.3.a PIGGING-16"Launcher — — — —, 0.65 3.83 28.04 Engineenng Estimate Regulation No.3.Part C,Section ILE.3.a PIGGING-16"Roggen Launcher — — — — 0.79 1.43 10.51 Engineering Estimate Regulation No.3,Part C,Section II.E.3.a Engine C-238/P003 Blowdowns — — — — 0.94 5.21 36.47 Engineenng Estimate Regulation No.3,Part C,Section II.E.3.a Engine C-2351P-005 Slowdowns — — — — 0.94 5.21 36.47 Engineering Estimate Regulation No.3,Part C,Section ti.E.3.a Engine C-236/P-006 Blowdowns — — — — O94 5.11 36.47 Engineenng Estimate Regulation No.3.Part C,Section II.E.3.a Engine C-234/P-018 Slowdowns — — — — 0.94 5.21 36.47 Engineering Estimate Regulation No.3,Pan C,Section II.E.3.a Engine C-237 Blowdowns — — — — 0,89 4.92 34.45 Engineenng Estimate Regulation No.3,Part C,Section II.E.3.a D-2.2,5 MMEttu/hr Dehy Reboiler Bumer 2.5 MMBtulhr 1,07 0.90 0.06 0.05 38.65 AP-42 Regulation No,3,Part C,Section II.E.3.k 0.75 MMBtulhr NG Fired Separator 0.75 MMBtulhr 0,32 0.27 0.02 0.01 11.59 AP-42 Regulation No.3.Pan C,Section II.E,3,k 212950 meter shed heater 0.006 MMBtuhr 0.006 MMBtu/h 0.00 0.00 0.00 0.00 0.09 AP-42 Regulation No.3.Pan C,Section II.E.3,k 214551 meter shed heater 0.006 MMBtufir 0.004 MMBtulh 0.00 0,00 0.00 _ 0.00 0.09 AP-42 • Regulation No.3.Part C,Section II.E.3.k PO14A Pressunzed Bullet Tank 30,000 ga — — -- — — N/A-Not a source of emissions Regulation No.3,Pan C,Section II.E.3.a P0148 Pressurized Bullet Tank 30,000 ga — — — — -- N/A-Not a source o1 emissions Regulation No.3,Part C,Section II.E,3,o Lube Oil Tank 210 bb — — neg. neg. neg. Regulation No.3.Pan C,Section II.E.3.aaa Produced Water Tank 100 bb Produced Water Sump 1 80 bb — — 1.60 86 269 APCD Emission Factors Regulation No.3.Part C.Section ILE.3.uu Produced Water Sump 2 80 bb • Sump Tank 3 80 bb — — neg. neg. neg. Regulation No.3.Part C,Section II.E.3.a Used Oil Tank 68 bb — — neg. neg. neg. Regulation No.3.Part C.Section II,E.3.aaa Sump 4 475 9a — — neg. neg. neg. Regulation Nu.3,Part C,Section II.E.3.a • Sump 5 80 bb — — neg, neg. neq. Regulation No.3,Pan C,Section II.E.3.a Sump 6 TEG/Cond 80 bb — — neg. neg. neg. Regulation No.3.Part C.Section II.E.3.a Sump 7 TEG Stormwater collection 80 bb — — neg. neg. neg. Regulation No.3,Part C.Section lI.E.3.a Used Oil Tank 1 475 9a — — neg. neg. neg. Regulation No.3.Part C.Section II.E.3.aaa Used Oil Tank 2 475 9s — — neg. nag. neg. Regulation No.3,Part C,Section II.E.3.aaa Slop Oil Sump 8 80 bb — — neg. neg. neg. Regulation No.3,Part C,Section II.E.3.aaa Luba Oil Day Tank 300 ga — — neg. neg. neg, Regulation No.3,Part C.Section II.E.3.aaa Lube Oil Day Tank 300 ga — — neg. neg. neg. Regulation No.3.Part C.Section II.E.3.aaa Remedialion Skimmer/bubbler 1 10 ac m — — neg. neg. neg. Regulation No.3,Part C,Section It.E.3,a Remediation Skimmerlbubbler 2 10 at m — — neg. neg. neg. Regulation No.3,Part C,Section II.E.3.a Total Insignificant Emissions: 1,40 1.18 8.78 53.87 440.66 NOTES: 1 Fugitive emissions based on 9/22/2017 gas analysis and August 2016 component count(with 15%buffer) 2 PIGGING emissions based on 9/22/2017 gas analysis(for recievers)and 9,2019 GLYCaic results(launchers)and estimated PIG sizes(from DCP Compliance) 3 Cat 63612 engine blowdown vent emission based on 25 V/ES events per year and 25 PM/UPM events per year with 9/22/2017 gas analysis. 4 Cat G3616 engine blowdown vent emission based on 12 L1/ES events per year and 12 PM/UPM events per year with 9/2212017 gas analysis, 5 Heater emissions based on 8,760 hours of operation and 1,020 BTU/SCF heat value gas. 6 Pressurized bullet tanks have no atmospheric emissions.These serve as process vessels leading to a condensate stabilizer. No loadout emissions. 7 The sumps are mostly water that drains off skid could possibly contain small amounts of hydrocarbon or TEG. 8 The remediation skimmers are small units that continually circulate a small amount of air dovmhole to facilitate remedialion of ground water. DCP Operating Company,LP 11/19/2018 Attachment D Facilitywide Emissions Summary—Form APCD-102 Enterprise Compressor Station Attachment E Updated O&M Plan D-2 Enterprise Compressor Station A CDPHE COLORADO Form APCD-302 ., Air Pollution Control Division CO f),1 ut r.rirrurr Air Pollution Control Division Operating and Maintenance Plan Template for Glycol Dehydration Systems Ver. January 1, 2018 The Air Pollution Control Division (Division)developed this Operating and Maintenance Plan (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 OEM Plan shall be submitted with the permit application when required. One OEM Plan may be used for multiple dehydrators at one facility if each are controlled and monitored in the same manner. If the OEM Plan template is completed correctly, the Division will approve the OEM Plan and a construction permit will be issued with the requirement to follow the OEM Plan as submitted. If the template is not completed correctly, the Division will work with the operator to make corrections. Once a construction permit is issued, the facility operator must comply with the requirements of the O&M Plan upon commencement of operation. An existing approved OEM Plan may be modified without a permit modification or permit reissuance, but the operator must adhere to the requirements of the existing approved OEM Plan until an approval letter is issued for the new OEM Plan. The operator is required to use the Division-developed OEM 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 OEM 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: November 2018 Section 1 - Source Identification For new permits, some of this information (i.e., Facility AIRS ID, Permit Number, and AIRS Point ID) may not be known at the time of application. Please only fill in the fields that are known and leave the others blank. Company Name: DCP Operating Company, LP Facility Location: Weld County Enterprise Compressor Facility Name: Station Facility AIRS ID(for existing facilities) 123 - 0277 Emission Units Covered by this OEM Form Facility Equipment ID D-2 Permit Number(if known) 95OPWE103 AIRS Point ID (if known) 068 Glycol Type Used a TEG Equipped with Flash Tank? (Y/N) Y a Glycol types are Ethylene Glycol (EG), Diethylene Glycol (DEG), or Triethylene Glycol (TEG). APCD Internal Use Only Page 1 of 5 Approved? ❑ Initial Date CDPHE , COLORADO Co i Air Pollution Control Division (,.irtrrrn ci(i'tiE Itc F(e.;tllt t, 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 welt 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 O&M Plan for a period of five (5) years. If applicable state requirements or any Federal NSPS, NESHAP, or MACT require a longer record retention period, the operator must comply with the longest record retention requirement. Section 4 - Monitoring Requirements • Control Equipment Information Table 1 below details the monitoring parameters and frequency for control equipment depending on the type of control equipment and the requested permitted emissions at the facility. Indicate the emissions control type(s) by checking the appropriate boxes. In addition, check the appropriate box for "Monitoring Frequency"based on the facility-wide permitted VOC emissions. Table 1 Emissions Control or Recycling Method Monitoring Frequency Parameter Flash ® Permitted n Permitted Still Tank Facility Emissions Facility Emissions Vent (if present) ≥ 80 tpy VOC < 80 tpy VOC Condenser b * Condenser Outlet Weekly Monthly Temperature Pilot Light and Auto- Daily Weekly Enclosed Flare or igniter Monitoring Combustor ® Visible Emissions Observation e Daily Weekly Pilot Light and Auto- Daily Weekly Elevated Open igniter Monitoring Flare C Visible Emissions Observation e Daily Weekly Combustion Chamber Daily Weekly Thermal Oxidizer Temperature Visible Emissions Observation e Daily Weekly * -Condenser is present, but acts as a secondary control device for unit D-2. CDPHE COLORADO i=ce cO Air Pollution Control Division e I' p,irtPt r'i'='r Table 1 Emissions Control or Recycling Method Monitoring Frequency Parameter Flash ® Permitted Permitted Still Tank Facility Emissions Facility Emissions Vent (if present) ≥ 80 tpy VOC < 80 tpy VOC Vapor Recovery Monitoring requirements, including parameters and frequency, Unit(VRU) or ® to be determined by the operator and listed below, and Recycled or Closed approved by the Division Loop System g pp Routed to Reboiler Monitoring requirements, including parameters and frequency, Burner as Fuel h to be determined by the operator and listed below, and approved by the Division Monitoring requirements including specific parameters and Other ❑ 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 shall be: Table 2: Condenser Maximum Outlet Temperature ❑ 160 °F A maximum temperature greater than 160 °F requires approval from the Division. °F 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 Page 3 of 5 CDPHE : COLORADO CO Air Pollution Control Division ner ,,t ent,,t 'iiz t_.:rlt„s,F'=`:'.r 'nEr=r,t combustion device for the presence or absence of smoke (e.g., visible emissions). If smoke is observed during the visible emissions inspection, the operator has the option to either (1) immediately shut-in the equipment to investigate the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed; or (2) conduct a formal Method 22 observation to determine whether visible emissions (as defined per Regulation No. 7, Section XVII.A.16.)are present. If a Method 22 is conducted, the record of the observations shall be maintained as required in Section 3 of this OEtM 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 n 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 OEtM Plan. g Vapor Recovery Unit (VRU) or Recycled or Closed Loop System In the space provided below, please provide a description of the emission control system, including an explanation of parameters monitored, monitoring frequency, and how the system design ensures that emissions are being routed to the appropriate system at all times, or during all permitted runtime. Also, provide a description of how downtime is tracked and recorded. Attach additional pages if necessary. The VRU wilt route flash tank vapors back to the process. If the VRU is down (5%annually), the flash tank emissions will be routed to the enclosed combustor (COMB-1)with a DRE of 95%. DCP will record the hours of VRU downtime. VRU downtime is defined as periods where the flash tank emissions are routed to COMB-1 instead of recycled to the inlet. Page 4 of 5 CDPHE COLORADO co e Air Pollution Control Division 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 OBtM Activities Please use this section to describe any additional notes or operation and maintenance activities, or if additional space is needed from a previous section. Attach additional pages if necessary. The enclosed combustor (COMB-1) used for still vent control has a 1.0%annual downtime for maintenance and malfunctions, during which times still vent emissions will be directed to the atmosphere. COMB-1 Runtime status will be tracked on at least a daily basis to determine COMB-1 downtime. COMB-1 downtime is defined as periods when emissions from the still vent are routed to the atmosphere instead of to COMB-1. If unit D-2 is down in addition to either the VRU or COMB-1, this does not constitute downtime as no emissions are being produced. Page 5 of 5 Attachment F Facility Process Flow Diagram and Plot Plan Enterprise Compressor Station Enterprise Compressor Station Process Flow Diagram DCP Operating Company, LP 0 Combustor A 8—300bb1 Stabilized Condensate Tanks > Truck Loading A Condensate Gas Stabilizer 0 COMB-1 v A A VRU < A West Pressurized Bullet < Gas Return A BTEX c to Inlet 2 Condenser Condensate Condensate A u_ Slug Catcher East Inlet Gas V Gas PressurizedInlet Bullet Gas > Compression > Dehydration —› Outlet Gas —> Slug Catcher Attachment G Updated Compliance Assurance Monitoring(CAM) Plan p_2 Enterprise Compressor Station Compliance Assurance Monitoring Plan - Dehydrators Background a. Emission Unit Description: Natural Gas Dehydration System using triethylene glycol(D-2); b. Applicable Regulation,Emission Limit, Monitoring Requirements: D-2: Regulations: Operating Permit Condition 3.1 Emission Limitations: VOC 24.96 tons/yr Individual HAP 8 tons/yr Total HAP 20 tons/yr c. Control Technology: Enclosed Combustor(Still Vent, Flash Tank during VRU downtime) II. Monitoring Approach Indicator No. l I. Indicator Enclosed Combustor Measurement Approach 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. II. Indicator Range Any absence of a flame will trigger an investigation to determine the problem and to perform corrective action,record keeping relating to the problem,and reporting of the problem when necessary. III. Performance Criteria a. Data Representativeness Device sensing heat will determine the presence or absence of the flame. b. Verification of The observation of the presence of a flame will Operational Status indicate that the device is operational. c. QA/QC Proper operation of this thermocouple shall be Practices/Criteria verified annually,and it shall be replaced if necessary. d. Monitoring Frequency Continuous e. Data Collection Excursions and any adjustments or repairs made Procedures to the enclosed combustor following an excursion shall be recorded in a log. f. Averaging Time Heat sensor will operate continuously and averaging will not be necessary. III. Justification a. Background: The pollutant specific emission unit is one individual dehydration unit, which functions to remove water vapor from the gas stream. Flash emissions from the inlet dehydrator flash tank is routed to the plant inlet using a vapor recovery unit(VRU) with 100%efficiency and the still vent emissions are routed to an enclosed combustor. b. Rationale for Selection of Performance Indicators and Indicator Ranges: The destruction of VOC is dependent upon combustion. The presence of a flame indicates the ECD is operational. In order to ensure the ECD is operating at all times that emissions are vented to it, it is continuously monitored for the presence of heat/a flame. Ili Attachment H Colorado Title V Operating Permit Forms Enterprise Compressor Station Operating Permit Application FACILITY IDENTIFICATION FORM 2000-100 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE t. Facility name and Name Enterprise Compressor Station mailing address Street or Route 370 17th Street,Suite 2500 City,State,Zip Code Denver,Colorado 80202 2. Facility location Street Address SWSW Section 30,T3N,R63V6' (No P.O.Box) City,County,Zip Between Keenesburg and Roggen,Weld County,Colorado Code 3. Parent corporation Name DCP Operating Company,LP Street or Route 370 17th Street,Suite 2500 City,State,Zip Code Denver,Colorado 80202 Country(if not U.S.) 4. Responsible Name David M.Jost official Title Vice President of Northern Operations Telephone 970-378-6345 5. Permit contact person Name Roshini Shankaran Title Senior Environmental Engineer (If Different than 4) Telephone 303-605-2039 6. Facility SIC code: 4922 7. Facility identification code: CO 123-0277 8. Federal Tax I.D.Number: 841041166 9. Primary activity of the operating establishment:Natural Gas Liquids Processing and Compression 10. Type of operating permit New X Modified Renewal 11. Is the facility located in a"nonattainment"area: X Yes No If"Yes",check the designated"non-attainment"pollutant(s): Carbon Monoxide X Ozone PM 10 Other(specify) 12. List all(Federal and State)air pollution permits(including grandfathered units),plan approvals and exemptions issued to this facility.List the number,date and what unit/process is covered by each permit. For a Modified Operating Permit,do not complete this item. 1 Operating Permit Application FACILITY PLOT PLAN FORM 2000-101 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division Facility Name:Enterprise Compressor Station Facility identification Code:CO 123-0277 The operating permit must be prepared and submitted on forms supplied by the Division. Use of this form is required for all operating permit applications. The Division will not consider or act upon your application unless each form used has been entirely completed. Completion of the information in the shaded area of this form is optional. Use"NA"where necessary to identify an information request that does not apply and is not in the optional shaded area. In order for a comprehensive air quality analysis to be accomplished, a facility plot plan MUST be included with the permit application. Drawings provided must fit on generic paper sizes of 8 1/2"X 11", 8 1/2"X 14"or 11"X 15", as appropriate to display the information being provided. Include the facility name and facility identification code on all sheets. For facilities with large areas, sketches of individual buildings, on separate drawings, may be needed to allow easy identification of stacks or vents. Insignificant activities do not need to be shown. Please see the updated Facility Plot Plan,included as Attachment H to this application. 1.A plant layout(plan view)including all buildings occupied by or located on the site of the facility and any outdoor process layout.. 2. The maximum height of each building (excluding stack height). 3.The location and coded designation of each stack. Please ensure these designations correspond to the appropriate stacks listed on the other permit forms in this application. The drawings need not be to scale if pertinent dimensions are annotated, including positional distances of structures, outdoor processes and free standing stacks to each other and the property boundaries. 4. The location of property boundary lines. 5. Identify direction"North"on all submittals. Are there any outdoor storage piles on the facility site with air pollution emissions that need to be reported? Yes X No If"Yes",what is the material in the storage pile(s)? Are there any unpaved roads or unpaved parking lots on the facility site?x Yes No List the name(s) of any neighboring state(s)within a 50 mile radius of your facility: N/A 2 Operating Permit Application SOURCE AND SITE DESCRIPTIONS FORM 2000-102 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division Facility Name: Enterprise Compressor Station Facility Identification Code:CO 123-0277 • The operating permit must be prepared and submitted on forms supplied by the Division. Use of this form is required for all operating permit applications. The Division will not consider or act upon your application unless each form used has been entirely completed. Completion of the information in the shaded area of this form is optional. Use"NA"where necessary to identify an information request that does not apply and is not in the optional shaded area. 1.Briefly describe the existing Unit(s)to be permitted. Attach copies of Form 2000-700 as needed to provide the information. Process flowsheets or line diagrams showing major features and locations of air pollution control equipment can be most effective in showing the location and relationships of the units. Providing mass flowrates/balances at critical points on the diagrams is very helpful when developing an understanding of the processes involved. Enterprise is classified as a natural gas compressor station as set forth under Standard Industrial Classification Code 4922.The facility uses five (5) gas-fired internal combustion engines to drive compressors boosting the inlet gas pressure from about 80 PSIG to 1,050 PSIG to facilitate movement of the gas in the pipeline. The station also includes a triethylene glycol (TEG) dehydrator unit which contacts "lean"triethylene glycol with the inlet natural gas stream to remove moisture.The"rich" glycol mixture is regenerated in a still for reuse in the process. The still vent exhaust stream is sent to an enclosed combustor where it is combusted. This enclosed combustor has an annual uptime of 99%, with downtime emissions releasing to atmosphere. The TEG dehydration system operates with a flash tank. The flash tank emissions are routed back to the process through the use of a Vapor Recovery Unit (VRU),with an annual uptime of 95%. Emissions during downtime events are routed to the enclosed combustor.A condensate product is generated when the inlet gas is routed through the inlet scrubber and transferred to eight(8) 300 barrel atmospheric storage tanks. A loading system is provided for moving the liquid condensate material from the tanks into a truck for transport offsite. The condensate tanks and loadout are controlled by an enclosed combustor.The facility has a natural gas throughput of 110 MMSCFD and a maximum stabilized condensate production rate of 153,884.4 bbl/yr. 2.Site Location and Description (Include instructions needed to drive to remote sites not identified by street addresses) Site location: SWSW Section 30,T3N,R63W The facility is located one (1) mile north of US Highway 76 on the Gutterson Road between the towns of Keenesburg and Roggen, Weld County, Colorado. 3. Safety Equipment Identify safety equipment required for performing an inspection of the facility: Protection x Other, specify Fire retardant clothing x Hard Hat x Safety shoes x Hearing Protection Gloves 3 Operating Permit Application SOURCE DESCRIPTION-APENS FORM 2000-102A Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division Facility Name:Enterprise Compressor Station Facility identification Code:CO 123-0277 NOTE: Each new or updated Air Pollutant Emission Notice (APEN) submitted must be accompanied by payment of$191.13 per APEN. 1.For each emission unit enclose a copy of the most current complete Air Pollutant Emission Notice(APEN)on file with the Division. If the most current APEN was not completely and correctly filled out, a revised APEN is required. List an APEN number, date, and a brief description of the unit/process covered by the APEN. (No filing fees are needed for these copies) Source AIRS ID Description APEN Date ID P-013 063 8-300bb1 Atmospheric Vertical Stabilized Condensate Storage Tanks 11/29/2016 Controlled with a Combustor P-016 066 153,884.4 bbl/yr Stabilized Condensate Truck Loading 11/29/2016 COMB-1 074 Enclosed Combustor used for Flash Tank and Still Vent control on unit D-2. 7/26/2016 This individual AIRS point is being cancelled and combined with AIRS 068(D-2)as part of this application. PW TBD APEN Only, Permit Exempt Produced Water Storage Tanks 8/02/2018 C-238 053 3,550 hp, Caterpillar G3612SI, Natural Gas Fired, Reciprocating Internal Submitted with Combustion Engine,4-cycle, Standard Lean Burn wl Oxidation Catalyst Minor C-235 055 3,550 hp, Caterpillar G3612SI, Natural Gas Fired, Reciprocating Internal Modification Combustion Engine, 4-cycle,Standard Lean Burn w/Oxidation Catalyst Application- C-236 056 3,550 hp, Caterpillar G3612SI, Natural Gas Fired, Reciprocating Internal Combustion Engine,4-cycle, Standard Lean Burn w/Oxidation Catalyst C-234 070 3,550 hp, Caterpillar G3612SI, Natural Gas Fired, Reciprocating Internal Combustion Engine,4-cycle, Standard Lean Burn w/Oxidation Catalyst C-237 071 4,735 hp, Caterpillar G3616, Natural Gas Fired, Reciprocating Internal Combustion Engine, 4-cycle, Standard Lean Burn w/Oxidation Catalyst 2.No APEN exists for an emission unit. List the new APEN and the appropriate descriptive information here. Submit the APEN with a construction permit application. New APEN and permit application submitted Yes x No Filing Fee Enclosed 3. A revised APEN was prepared and enclosed for an emission unit. List the APEN and the appropriate descriptive information here. A revised APEN is needed where a significant increase in emissions has occurred, or is planned; or a major modification of the unit has occurred or is planned; or the existing information needs correction or completion. A construction permit application may need to be submitted. Revised APEN submitted as part of this application: x Yes No x Filing Fee Enclosed New permit application enclosed: Yes x No Permit modification application enclosed: x Yes No Attachment B contains copies of the following APEN: D-2 068 110 MMSCFD, Forum Tri-ethylene Glycol(TEG) Dehydration Unit, 20 gpm Submitted with TEG Recirculation Rate, Flash Tank Routed to Reboiler, Equipped with an this application enclosed combustor 4 Operating Permit Application SOURCE DESCRIPTION-INSIGNIFICANT ACTIVITIES FORM 2000-102B Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division Facility Name:Enterprise Compressor Station Facility Identification Code:CO 123-0277 NOTE:The operating permit must be prepared and submitted on forms supplied by the Division This is a supplemental form for use only when necessary to provide complete information in the operating permit application.The Division will not consider or act upon your application unless each form used has been entirely completed. Please see included Supplemental Form 700 for complete list of Insignificant Activities Certain categories of sources and activities are considered to be insignificant contributors to air pollution and are listed below. A source solely comprised of one or more of these activities is not required to obtain an operating permit pursuant to Regulation 3, unless the source's emissions trigger the major source threshold as defined in Part A, Section I.B.58 of Regulation 3. For the facility, mark all insignificant existing or proposed air pollution emission units, operations, and activities listed below. (a) noncommercial(in-house)experimental and analytical laboratory equipment which is bench scale in nature including quality control/quality assurance laboratories, process support laboratories, environmental laboratories supporting a manufacturing or industrial facility, and research and development laboratories. (b) research and development activities which are of a small pilot scale and which process less than 10,000 pounds of test material per year. (c) small pilot scale research and development projects less than six months in duration with controlled actual emissions less than 500 pounds of any criteria pollutant or 10 pounds of any non-criteria reportable pollutant. Disturbance of surface areas for purposes of land development,which do not exceed 25 contiguous acres and which do not exceed six months in duration. (This does not include mining operations or disturbance of contaminated soil). x Each individual piece of fuel burning equipment,other than smokehouse generators and internal combustion engines,which uses gaseous fuel,and which has a design rate less than or equal to 5 million Btu per hour.(See definition of fuel burning equipment,Common Provisions Regulation). Petroleum industry flares, not associated with refineries, combusting natural gas containing no H2S except in trace(less than 500 ppmw)amounts, approved by the Colorado Oil and Gas Conservation Commission and having uncontrolled emissions of any pollutant of less than five tons per year. Chemical storage tanks or containers that hold less than 500 gallons, and which have a daily throughput less than 25 gallons. Landscaping and site housekeeping devices equal to or less than 10 H.P. in size(lawnmowers,trimmers, snow blowers, etc.). Crude oil or condensate loading truck equipment at crude oil production sites where the loading rate does not exceed 10,000 gallons per day averaged over any 30 day period. Chemical storage areas where chemicals are stored in closed containers, and where total storage capacity does not exceed 5000 gallons. This exemption applies solely to storage of such chemicals. This exemption does not apply to transfer of chemicals from,to, or between such containers. x Oil production wastewater(produced water tanks),containing less than 1% by volume crude oil,except for commercial facilities which accept oil production wastewater for processing. Storage of butane, propane, or liquified petroleum gas in a vessel with a capacity of less than 60,000 gallons, provided the requirements of Regulation No. 7,Section IV are met,where applicable. x Storage tanks of capacity<40,000 gallons of lubricating oils. Venting of compressed natural gas, butane or propane gas cylinders,with a capacity of 1 gallon or less. Fuel storage and dispensing equipment in ozone attainment areas operated solely for company-owned vehicles where the daily fuel throughput is no more than 400 gallons per day, averaged over a 30 day period. s x Crude oil or condensate storage tanks with a capacity of 40,000 gallons or less. Storage tanks meeting all of the following criteria: (i) annual throughput is less than 400,000 gallons; and (ii)the liquid stored is one of the following: (A) diesel fuels 1-D, 2-D, or 4-D; (B) fuel oils#1 through#6; (C) gas turbine fuels 1-GT through 4-GT; (D) an oil/water mixture with a vapor pressure lower than that of diesel fuel(Reid vapor pressure of.025 PSIA). x Each individual piece of fuel burning equipment which uses gaseous fuel,and which has a design rate less than or equal to 10 million Btu per hour,and which is used solely for heating buildings for personal comfort. Stationary Internal Combustion Engines which: (i) power portable drilling rigs; or (ii) are emergency power generators which operate no more than 250 hours per year; or (iii)have actual emissions less than five tons per year or rated horsepower of less than 50. Surface mining activities which mine 70,000 tons or fewer of product material per year. A fugitive dust control plan is required for such sources. Crushers,screens and other processing equipment activities are not included in this exemption. x Air pollution emission units,operations or activities with emissions less than the appropriate de minimis reporting level. NOTE: Material Data Safety Sheets(MSDS)do not have to be submitted for any insignificant activities. USE FORM 2000-700 TO PROVIDE AN ITEMIZED LIST OF THE SOURCES OR ACTIVITIES BEING IDENTIFIED AS INSIGNIFICANT ACTIVITIES. DO NOT ITEMIZE INDIVIDUAL PIECES OF LANDSCAPING EQUIPMENT. THE LIST IS NEEDED TO ACCURATELY ACCOUNT FOR ALL ACTIVITIES AT THE FACILITY 6 Operating Permit Application SUPPLEMENTAL INFORMATION FORM 2000-700 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Enterprise Compressor 2. Facility identification code:CO 123-0277 Station 3. This form supplements Form 2000-102B for Emission Unit Insignificant Sources Source Description Insignificant Per Facilitywide Fugitive Emissions Regulation No.3,Part C,Section II.E.3.a PIGGING-Marla Reciever Regulation No.3,Part C,Section II.E.3.a PIGGING-16" PIG Launcher Regulation No.3,Part C,Section II.E.3.a PIGGING-Roggen Launcher Regulation No.3,Part C,Section II.E.3.a PIGGING-20" PIG Launcher Regulation No.3,Part C,Section II.E.3.a PIGGING-20" Inlet Reciever Regulation No.3,Part C,Section 1LE.3.a PIGGING- 12" Inlet Reciever Regulation No.3,Part C,Section II.E.3.a Engine C-238/P003 Blowdowns Regulation No.3,Part C,Section II.E.3.a Engine C-235/P-005 Blowdowns Regulation No.3,Part C,Section 11.E.3.a Engine C-236/P-006 Blowdowns Regulation No.3,Part C,Section II.E.3.a Engine C-234/P-018 Blowdowns Regulation No.3,Part C,Section II.E.3.a Engine C-237 Blowdowns Regulation No.3,Part C,Section II.E.3.a D-2:2.5 MMBtu/hr Dehy Reboiler Burner Regulation No.3,Part C,Section II.E.3.k 0.75 MMBtu/hr NG Fired Separator Regulation No.3,Part C,Section II.E.3.k 212950 meter shed heater 0.006 MMBtu/hr Regulation No.3,Part C,Section II.E.3.k 214551 meter shed heater 0.006 MMBtu/hr Regulation No.3,Part C,Section II.E.3.k P014A Pressurized Bullet Tank Regulation No.3,Part C,Section ILE.3.a P014B Pressurized Bullet Tank Regulation No.3,Part C,Section II.E.3.a Lube Oil Tank Regulation No.3,Part C,Section Il.E.3.aaa 100 bbl Produced Water Tank Regulation No.3,Part C,Section II.E.3.uu Produced Water Sump 1 Regulation No.3,Part C,Section II.E.3.uu Produced Water Sump 2 Regulation No.3,Part C,Section II.E.3.uu Sump Tank 3 Regulation No.3,Part C,Section II.E.3.a Used Oil Tank Regulation No.3,Part C,Section II.E.3.aaa Sump 4 Regulation No.3,Part C,Section 11.E.3.a Sump 5 Regulation No.3,Part C,Section II.E.3.a Sump 6 TEG/fond Regulation No.3,Part C,Section 11.E.3.a Sump 7 TEG Stormwater collection Regulation No.3,Part C,Section II.E.3.a Used Oil Tank 1 Regulation No.3,Part C,Section II.E.3.aaa Used Oil Tank 2 Regulation No.3,Part C,Section II.E.3.aaa 1 Slop Oil Sump 8 Regulation No.3,Part C,Section II.E.3.aaa Lube Oil Day Tank Regulation No.3,Part C,Section II.E.3.aaa Lube Oil Day Tank Regulation No.3,Part C,Section II.E.3.aaa Remediation Skimmer/bubbler I Regulation No.3,Part C,Section II.E.3.a Remediation Skimmer/bubbler 2 Regulation No.3,Part C,Section II.E.3.a 2 Operating Permit Application STACK IDENTIFICATION FORM 2000-200 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Enterprise Compressor Station 2. Facility identification code:CO 123-0277 3. Stack identification code:COMB-1 3a.Construction Permit Number:97WE0553 4.Exhausting Unit(s),use Unit identification code from appropriate Form(s)2000-300,301,302,303,304,305,306,307 2000-300 2000-301 2000-302 2000-303 2000-304 2000-305 2000-306 2000-307 D-2 5. Stack identified on the plot plan required on Form 2000-101 X No Change in Equipment Location 6. Indicate by checking: X This stack has an actual exhaust point.The parameters are entered in Items 7-13. This stack serves to identify fugitive emissions. Skip items 7-13. Go to next form. When stack height Good Engineering Practice(GEP)exceeds 65 meters(Colorado Air Quality Reg 3.A.VIII.D)data entry is required for Item 7. 7. Discharge height above ground level: 25 (feet) 8. Inside dimensions at outlet(check one and complete): X Circular 3.0 (feet) Rectangular length(feet)_width(feet) 9. Exhaust flow rate: Normal (ACFM) Maximum (ACFM) Velocity (FPS) Calculated Stack Test 10. Exhaust gas temperature(normal): (°F) 11. Does process modify ambient air moisture content? X Yes No If"Yes",exhaust gas moisture content: Normal percent Maximum percent 12. Exhaust gas discharge direction: X Up Down Horizontal 13. Is this stack equipped with a rainhat or any obstruction to the free flow of the exhaust gases from the stack? Yes X No *****Complete the appropriate Air Permit Application Forms(s)2000-300,301,302,303,304,***** 305,306,or 307 for each Unit exhausting through this stack. Operating Permit Application GLYCOL DEHYDRATION UNIT FORM 2000-307 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Enterprise Compressor Station 2. Facility identification code:CO 123-0277 3. Stack identification code:COMB-I 4. Dehydrator(Unit)code:D-2 5. Unit description:Natural gas dehydration system using triethylene glycol(TEG)for water removal.Includes VRU for capturing flash tank emissions and an enclosed combustor for still vent emissions.The VRU has an annual downtime of 5%for maintenance and malfunctions.The enclosed combustor has an annual downtime of 1%for maintenance and malfunctions.VRU downtime emissions are routed to the enclosed combustor,and combustor downtime emissions are uncontrolled,and released to atmosphere. 6. Indicate the dehydrator control technology status. Uncontrolled X Controlled If the dehydrator is controlled,enter the control device number(s)from the appropriate forms: 2000-400 COMB-I 2000-403 7. Manufacturer:Forum 9. Regenerator heater design rate or maximum continuous rating (mmBTU!hr):2.5 8. Model&serial number:Custom 10. Date first placed in service: 1/11/2001 Date of last modification:July 2016 11. Flash Tank:X Yes No Flash tank vented to: atmosphere X process or control device(enclosed combustor) 12. Glycol Circulation rate: 20 gallons per minute(maximum) gallon per pound of H2O OR 13. Pipeline Capacity: (mmscf/day): 110.0 14. Glycol Type: X Triethylene Glycol Ethylene Glycol Other(specify) 15. Glycol Make-up Rate(gallons/year): 16. Computer model input&output printout attached X Glycalc 4.0 results 17. Gas Pressure(psi):920 18. Gas Temperature(°F): 105 19. Gas composition test results VOC • BTEX HEXANE Test date:9/22/2017 value units value units value units 10.3948 mol% 0.0434 mol% 0.1251 mol% *****For this emissions unit,identify the method of compliance demonstration by completing Form 2000-500,***** DESCRIPTION OF METHODS USED FOR DETERMINING COMPLIANCE. Attach Form 2000-500 and its attachment(s)to this form. ***** Please complete the Air Pollution Control Permit Application Forms 2000-600 and 2000-601 for this Unit. ***** NOTE: THE SPECIALIZED APEN FOR A GLYCOL DEHYDRATION UNIT MUST BE COMPLETED AND SUBMITTED IF THE STILL VENT EMISSIONS HAVE NOT BEEN REPORTED BEFORE Operating Permit Application CONTROL EQUIPMENT-MISCELLANEOUS FORM 2000-400 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Enterprise Compressor 2.Facility identification code:CO 123-0277 Station 3. Stack identification code:COMB-1 4.Unit identification code: D-2 5. Control device code:COMB-1 6. Manufacturer and model number: LEED L30-0018-00 7. Date placed in service: 4/11/2016 Date of last modification:July 2016 8. Describe the device being used. Attach a diagram of the system. • VRU(closed loop)to control flash tank emissions.This control device has an annual uptime of 95%,with the enclosed combustor COMB-1 acting as a back-up control device for the remaining 5%. • Enclosed Combustor COMB-1 to control still vent(control efficiency shown below for this device).This control device has an annual uptime of 99%,with uncontrolled emissions during any periods of downtime. 9. List the pollutants to be controlled by this equipment and the expected control efficiency for each pollutant on the table below. Documentation attached EITHER the outlet pollutant concentration OR the control efficiency must be provided. Pollutant Inlet pollutant Emissio Outlet pollutant Control concentration n concentration Efficiency capture (%) efficien cy(%) gr/acf ppmv gr/acf ppmv VOC 95% HAPs 95% 10. Discuss how the collected material will be handled for reuse or disposal. 11. Prepare a malfunction prevention and abatement plan for this pollution control system.The plan does not have to be submitted with the application. It is suggested the plan include,but not be limited to the following: a. Identification of the individual(s),by title,responsible for inspecting,maintaining and repairing this device. b. Operation variables such as temperature that will be monitored in order to detect a malfunction or breakthrough,the correct operating range of these variables,and a detailed description of monitoring or surveillance procedures that will be used to show compliance. c. What type of monitoring equipment will be provided(temperature sensors,pressure sensors, CEMs). d. An inspection schedule and items or conditions that will be inspected. f. Where is this plan available for review? NOTE: COMPLETION OF INFORMATION IN SHADED AREA OF THIS FORM IS OPTIONAL Operating Permit Application COMPLIANCE CERTIFICATION-MONITORING AND REPORTING FORM 2000-500 Colorado Department of DESCRIPTION OF METHODS USED Rev 06-95 Public Health and Environment FOR DETERMINING COMPLIANCE Air Pollution Control Division All applicants are required to certify compliance with all applicable air pollution permit requirements by including a statement within the permit application of the methods used for determining compliance. This statement must include a description of the monitoring,recordkeeping,and reporting requirements and test methods. In addition, the application must include a schedule for compliance certification submittals during the permit term. These submittals must be no less frequent than annually,and may need to be more frequent if specified by the underlying applicable requirement or by the Division. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name Enterprise Compressor 2. Facility identification code:CO 123-0277 Station 3. Stack identification code:COMB-1 4. Unit identification code:D-2 5.For this Unit the following method(s)for determining compliance with the requirements of the permit will be used(check all that apply and attach the appropriate form(s)to this form). Continuous Emission Monitoring(CEM)-Form 2000-501 Pollutant(s): Periodic Emission Monitoring Using Portable Monitors-Form 2000-502 Pollutant(s) X Monitoring Control System Parameters or Operating Parameters of a Process-Form 2000-503 Pollutant(s): VOCs,HAPs Monitoring Maintenance Procedures-Form 2000-504 Pollutant(s): Stack Testing-Form 2000-505 Pollutant(s): Fuel Sampling and Analysis(FSA)-Form 2000-506 Pollutant(s): X Recordkeeping-Form 2000-507 Pollutant(s): VOC,HAPs X Other(please describe)-Form 2000-508 Pollutant(s):VOC,HAPs 6. Compliance certification reports will be submitted to the Division according to the following schedule: Start date: February 1,of the year following the Operating Permit renewal. and every 12 months thereafter. (12 month maximum interval) Compliance monitoring reports will be submitted to the Division according to the following schedule: Start date: August 1,of the year following the Operating Permit renewal. and every 6 months thereafter. (6 month maximum interval) NOTE: EACH APPLICABLE REQUIREMENT ON FORM 2000-604 NEEDS TO BE SPECIFICALLY ADDRESSED IN ITEM 5. Operating Permit Application COMPLIANCE DEMONSTRATION BY FORM 2000-503 Colorado Department of MONITORING CONTROL SYSTEM PARAMETERS OR Rev 06-95 Public Health and Environment OPERATING PARAMETERS OF A PROCESS Air Pollution Control Division The monitoring of a control system parameter or a process may be acceptable as a compliance demonstration method provided that a correlation between the parameter value and the emission rate of a particular pollutant is established in the form of a curve of emission rate versus parameter values. Ideally stack test data that bracket the emission limit,if possible,could be used to define the emission curve. This correlation shall constitute the certification of the system. It should be attached for Division approval. If it is not attached,please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Enterprise Compressor Station 2. Facility identification code:CO 123-0277 3. Stack identification code:COMB-1 4.Unit identification code:D-2 5. Pollutant(s)being monitored:VOC,HAPs 6. Name of manufacturer:Leed 7. Model number:L30-0018-00 8. Is this an existing system? X Yes No 9. Reserved for future use 10. Describe the method of monitoring: Presence of a flame in Enclosed Combustor: Presence of a flame is continuously monitored with thermocouple or equivalent temperature sensing device.Device senses heat and when there is an absence of a flame,then an alarm is sent to the control room. The observation of the presence of a flame will indicate that the device is operational. 11. Backup system:Daily Visual Inspections 12. Quality Assurance/Quality Control: -Any monitoring system used with the record keeping shall be subject to appropriate performance specifications, calibration requirements and quality assurance procedures. -A quality assurance/quality control plan for the monitoring system is attached for Division review. The plan is not attached,but will be submitted to the Division by - X The presence of a pilot flame in the enclosed combustor is monitored continuously using a thermocouple,or equivalent device.Backup monitoring is provided by visual inspection if pilot light status cannot be verified.Daily logs of both continuous monitoring results,as well as any backup visual inspection results,are kept. QA/QC checked by periodic review of logs by Supervisory personnel. 13. The applicant shall propose an appropriate averaging period,(i.e.,a particular number of continuous hours)for the purpose of defining excess emissions. The Division may approve the proposed averaging period,or other period which the Division determines to be appropriate. Provide the proposed averaging period(s)below. Parameter Averaging Period Operating Pennit Application COMPLIANCE DEMONSTRATION FORM 2000-507 Colorado Department of BY RECORDKEEPING Rev 06-95 Public Health and Environment Air Pollution Control Division Recordkeeping may be acceptable as a compliance demonstration method provided that a correlation between the parameter value recorded and the emission rate of a particular pollutant is established in the form of a curve or chart of emission rate versus parameter values. This correlation may constitute the certification of the system. For an existing program,the correlation demonstration must be attached for Division consideration for approval. If the correlation information has not yet been developed,please submit it within 60 days of the startup of the system. SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Enterprise Compressor Station 2. Facility identification code:CO 123-0277 3. Stack identification code:COMB-1 4. Unit identification code:D-2 5. Pollutant(s)being monitored: 6. Material or parameter being monitored and recorded: VOC,HAPs Flash tank temperature and pressure,inlet gas temperature and pressure,TEG circulation rate,hours and days of operation,natural gas throughput,control device downtime,actual emissions of VOCs and HAPs 7. Method of monitoring and recording(see information on back of this page): The following parameters are monitored according to the indicated schedule,and all data recorded in facility 12-rolls workbook. Flash tank temperature and pressure:monitored weekly Inlet gas temperature and pressure: monitored weekly TEG Circulation Rate: monitored daily Hours/Days of operation: monitored monthly,used with monthly throughput to determine average daily throughput Natural Gas Throughput: monitored monthly using existing flow meter,used with hours of operation to determine average daily throughput Control Device Downtime:monitored according to active O&M plan for this unit Actual emissions of VOCs and HAPs:Calculated monthly using GLYCaIc and the above monitored parameters 8. List any EPA methods used:None 9. Is this an existing method of demonstrating 10. Start date: May 1999 compliance? No X Yes 11. Backup system:Assume maximum values for recordkeeping analysis in case of missing values 12 a. Data collection frequency: X Daily X Weekly X Monthly Batch(not to exceed monthly) Other-specify 12 b. Compliance shall be demonstrated: Daily Weekly X Monthly Batch(not to exceed monthly) X Other—12-month rolling 13. Quality Control/Quality Assurance: -The monitoring system shall be subject to appropriate performance specifications,calibration requirements,and quality assurance procedures. -A quality assurance/quality control plan for the recordkeeping system is attached for Division review. -The plan is not attached,but will be submitted to the Division by DCP currently conducts recordkeeping associated with this facility.DCP uses an internal data base to ensure the recordkeeping is being conducted on the proper frequency and that the correct information is being gathered. 14. A proposed format for the compliance certification report and excess emission report is attached. DCP currently submits compliance certification reports and excess emission reports to the Colorado Air Pollution Control Division as required.The format for these submittals can be found in the previous submittals from DCP. ***** The compliance records shall be available for Division inspection. ***** The source shall record any malfunction that causes or may cause an emission limit to be exceeded. ***** Malfunctions shall be reported to the Division the next business day. Hazardous air releases shall be reported to the Division immediately. Operating Permit Application COMPLIANCE DEMONSTRATION FORM 2000-508 Colorado Department of Public Health and Environment BY OTHER METHODS Rev 06-95 Air Pollution Control Division 1.Facility Name:Enterprise Compressor Station 2.Facility identification code:CO 123-0277 3.Stack identification code:COMB-1 4.Unit Identification code:D-2 5.Pollutant(s)or Parameter(s)being monitored:Inlet Wet Gas Sampling 6.Description of the method of monitoring: Extended samples of inlet gas shall be collected and analyzed.The wet gas composition from the most recent extended analysis will be used with other recorded parameters to calculate VOC and HAP emissions on a monthly basis,using GLYCaIc. 7.Compliance shall be demonstrated:(Specify the frequency with which compliance will be demonstrated) Inlet wet gas will be collected and sampled annually.If any concentrations of BTEX on the analysis exceed specified values, inlet sampling frequency will increase to quarterly. Operating Permit Application EMISSION UNIT HAZARDOUS AIR POLLUTANTS FORM 2000-600 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Enterprise Compressor Station 2. Facility identification code:CO 123-0277 3. Stack identification code:COMB-1 4. Unit identification code:D-2 5. Unit material description:Triethylene glycol(TEG)Dehydrator used for dehydration of inlet wet gas stream. 6. Complete the following summary of hazardous air emissions from this unit. Attach all calculations and emission factor references. Attached X Actual Emissions Data is for calendar year Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name Quantity Measurement Quantity Measurement Units Units Highest Individual HAP <S TPY Total HAP Emissions <20 TPY NOTE: If there is a permit for this unit,the permit limits are the same as the potential to emit. Operating Permit Application EMISSION UNIT CRITERIA AIR POLLUTANTS FORM 2000-601 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name:Enterprise Compressor Station 2. Facility identification code:CO 123-0277 3. Stack identification code:COMB-1 4. Unit identification code: D-2 5. Complete the following emissions summary for the following pollutants. Attach all calculations and emission factor references. Attached X Air pollutant Actual Potential to emit Maximum allowable Quantity U TPY U TPY Particulates(TSP) TPY PM-10 TPY Nitrogen oxides 1.43 TPY 0.068 2 1.43 Volatile organic compounds 24.96 TPY 1.24 7 24.96 Carbon monoxide 6.51 TPY 0.31 2 6.51 Lead TPY Sulfur dioxide TPY Total reduced sulfur TPY Reduced sulfur compounds TPY Hydrogen sulfide TPY Sulfuric Acid Mist TPY Fluorides TPY TPY TPY TPY TPY Units(U)should be entered as follows: =Ib/hr 2=lb/mmBTU 3=grains/dscf 4=lb/gallon 5=ppmdv 6=gram/HP-hour 7=lb/mmscf 8=other(specify) 9=other(specify) 10=other(specify) Operating Permit Application APPLICABLE REQUIREMENTS AND FORM 2000-604 Colorado Department of Public Health and Environment STATUS OF EMISSION UNIT Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1.Facility name:Enterprise Compressor Station 2.Facility identification code:CO 123-0277 3.Stack identification code:COMB-1 4.Unit identification code: D-2 5.Pollutant 6.Colorado Air Quality 7. 8.Limitation 9.Compliance Regulations State Status or Only IN OUT Construction Permit Number VOC 24.96 tpy X HAPs <8 tpy individual HAP X <20 tpy total HAPs NO. 1.43 tpy X CO 631 tpy X 10.Other requirements(e.g.,malfunction reporting,special operating conditions from an State Compliance Status existing permit such as material usage,hours of operation,etc.) Only IN OUT Extended Gas Analysis:Annually,or quarterly if results exceed specified values X Gas Throughput Limit:40,150 MMscf'yr,monthly recordkeeping X Gas Throughput Limit during ECD Downtime:401.50 MMscf,/yr,monthly recordkeeping Gas Throughput Limit during VRU Downtime:2,007.50 MMscf/yr,monthly recordkeeping Gas Throughput during VRU downtime:flash tank emissions routed to COMB-I X Gas Throughput during ECD downtime:still vent emissions routed to atmosphere X Hours of Operation:monthly recordkeeping X Enclosed Combustor Downtime:daily recordkeeping X Enclosed Combustor Requirements:pilot light monitoring,recordkeeping X Vapor Recovery Unit Downtime:daily recordkeeping X Compliance Assurance Monitoring:the permitee shall follow the CAM plan for control of X this TEG natural gas dehydrator Colorado Regulation 7 Section XII:"maintain overall control of emission from natural gas X dehydrator of at least 90%.Follow all applicable monitoring,recordkeeping,and reporting requirements. Colorado Regulation 7 Section XVII:maintain overall control of emissions from natural gas X X dehydrator of at least 95%.Follow all applicable monitoring,recordkeeping,and reporting requirements. Lean Glycol Recirculation Rate:20 gallons/minute,weekly recordkeeping X NESHAP Subpart HH Area Source requirements X NESHAP Subpart A General Provisions X **** USE FORM 2000-700 TO EXPLAIN HOW COMPLIANCE WAS DETERMINED FOR EACH APPLICABLE REQUIREMENT Operating Permit Application EMISSION UNIT COMPLIANCE PLAN FORM 2000-606 Colorado Department of Public Health and Environment COMMITMENTS AND SCHEDULE 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE I.Facility name: Enterprise 2.Facility identification code:CO 123-0277 Compressor Station 3.Stack identification code:COMB-1 4.Unit identification code:D-2 5. For Units that are presently in compliance with all applicable requirements,including any monitoring and compliance certification requirements of Colorado Air Quality Regulation 3,Part C that apply,complete the following. These commitments are part of the application for operating permits. ❑ We will continue to operate and maintain this Unit in compliance with all applicable requirements. ❑ Form 2000-604 includes new requirements that apply or will apply to this Unit during the term of the permit. We will meet such requirements on a timely basis. 6. For Units not presently fully in compliance,complete the following. This Unit is in compliance with all applicable requirements except for those indicated below. We will achieve compliance according to the following schedule(If more space is needed attach additional copies of Form 2000-700): Applicable Requirement Corrective Actions Deadline 1. June 30,2019 Replace the BTEX condenser to Flash emissions shall be routed prevent winter freeze ups,which to the enclosed combustor during periodically prevent flash gas all periods of VRU downtime routing to the ECD during VRU (5%annually) downtime 2. 3. ■_1-. Progress reports will be submitted: Start date: June 30,2019 Operating Permit Application SUPPLEMENTAL INFORMATION FORM 2000-700 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Enterprise Compressor Station 2. Facility identification code:CO 123-0277 3. This form supplements Form 2000- 604 for Emission Unit(e.g.B001,P001,etc.) D-2 Additional Information,Diagram Item Number Requirement Compliance Methods VOC Emissions Limit:24.96 tpy DCP calculates rolling 12-month totals,updated monthly.Records and calculations in Enterprise 12- NO„Emissions Limit: 1.43 tpy month rolling totals calculations workbook. CO Emissions Limit:6.51 tpy Emissions calculated using GLYCalc in conjunction with monitored operating parameters. Extended Gas Analysis:Annually,or quarterly if results exceed specified Records,calculations,and annual extended gas values analyses in DCP compliance files Gas Throughput Limit:40,150 MMscflyr,monthly recordkeeping DCP calculates rolling 12-month totals,updated Gas Throughput Limit during ECD Downtime:401.50 MMscf/yr,monthly monthly.Records and calculations in Enterprise 12- recordkeeping month rolling totals calculations workbook. Gas Throughput Limit during VRU Downtime: 2,007.50 MMscfiyr,monthly Processed gas is continuous monitored via flow recordkeeping meter. Gas Throughput during VRU downtime: flash tank emissions routed to COMB-1 Design specifications.Recordkeeping Gas Throughput during ECD downtime:still vent emissions routed to atmosphere Design specifications,Recordkeeping Hours of Operation:monthly recordkeeping Records and calculations in Enterprise 12-month rolling totals calculations workbook. Enclosed Combustor Downtime:daily recordkeeping Records and calculations in Enterprise 12 month rolling totals calculations workbook. Enclosed Combustor Requirements:pilot light monitoring,recordkeeping Records and calculations in Enterprise 12 month rolling totals calculations workbook. Vapor Recovery Unit Downtime:daily recordkeeping Records and calculations in Enterprise 12-month rolling totals calculations workbook. Compliance Assurance Monitoring:the permitee shall follow the CAM plan The approved CAM plan will be followed and for control of this TEG natural gas dehydrator records kept in DCP compliance files Colorado Regulation 7 Section XIL: maintain overall control of emission from Design specifications,Records and calculations in natural gas dehydrator of at least 90%. Follow all applicable monitoring, DCP compliance files recordkeeping,and reporting requirements. Colorado Regulation 7 Section XVII: maintain overall control of emissions from natural gas dehydrator of at least 95%.Follow all applicable monitoring, Design specifications,Records and calculations in recordkeeping,and reporting requirements. DCP compliance files Lean Glycol Recirculation Rate: 20 gallons minute,monthly recordkeeping Records and calculations in Enterprise 12-month rolling totals calculations workbook. NESHAP Subpart 1111 Area Source requirements Design specifications,Records and calculations in DCP compliance files NESHAP Subpart A General Provisions Design specifications,Records and calculations in DCP compliance files Recordkeeping and Reporting Requirements Records and calculations in DCP compliance files Operating Permit Application PLANT-WIDE HAZARDOUS AIR POLLUTANTS FORM 2000-602 Colorado Department of Public Health and Environment Rev 06-95 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE 1. Facility name: Enterprise Compressor Station 2. Facility identification code:CO 123-0277 3. Complete the following emissions summary for all hazardous air emissions at this facility.Calculations attached. Attach a copy of all calculations to this form. Attached X Pollutant CAS Common or Generic Actual emissions Allowable OR Potential to emit Pollutant Name Quantity Units Quantity Units Highest Individual HAP 14.6 TPY (Formaldehyde) Total Facility-wide HAPs 35.5 TPY NOTE: If there is a permit for this unit, the permit limits are the same as the potential to emit. Operating Permit Application PLANT-WIDE CRITERIA AIR POLLUTANTS FORM 2000-603 Colorado Department of Public Health and Environment 09-94 Air Pollution Control Division SEE INSTRUCTIONS ON REVERSE SIDE I.Facility name:Enterprise Compressor 2.Facility identification code: Station CO 123-0277 • 3. Complete the following emissions summary for the listed emissions at this facility. Air pollutant Actual Potential to Maximum allowable emit TPY TPY TPY Particulates(TSP) 5.7 5.7 PM-10 5.7 5.7 Nitrogen oxides 130.8 130.8 Volatile organic compounds 165.3 165.3 Carbon monoxide 154.0 154.0 Lead Sulfur dioxide 0.3 0.3 Total reduced sulfur Reduced sulfur compounds Hydrogen sulfide Sulfuric acid mist Fluorides Operating Permit Application TABULATION OF PERMIT APPLICATION FORMS FORM 2000-800 Colorado Department of Health 09-94 Air Pollution Control Division Facility Name: Enterprise Compressor Station Facility Identification Code:CO 123-0277 ADMINISTRATION This application contains the following forms: X Form 2000-100,Facility Identification X Form 2000-101,Facility Plot Plan X Forms 2000-102,-102A,and-102B,Source and Site Descriptions II. EMISSIONS SOURCE Total Number DESCRIPTION of This Form This application contains the following forms X Form 2000-200,Stack Identification 1 (one form for each facility boiler.printing Form 2000-300,Boiler or Furnace Operation Form 2000-301,Storage Tanks Form 2000-302,Internal Combustion Engine Form 2000-303,Incineration Form 2000-304,Printing Operations Form 2000-305,Painting and Coating Operations Form 2000-306,Miscellaneous Processes X Form 2000-307,Glycol Dehydration Unit 1 111. AIR POLLUTION CONTROL Total Number SYSTEM of This Form This application contains the following forms: X Form 2000-400.Miscellaneous 1 Form 2000-401,Condensers Form 2000-402,Adsorbers Form 2000-403,Catalytic or Thermal Oxidation Form 2000-404,Cyclones/Settling Chambers Forum 2000-405,Electrostatic Precipitators • Form 2000-406,Wet Collection Systems Form 2000-407,Baghouses/Fabric Filters IV. COMPLIANCE Total Number DEMONSTRATION of This Form This application contains the following forms X Form 2000-500,Compliance Certification-Monitoring and 1 (one for each facility boiler,printing operation, Reporting Form 2000-501,Continuous Emission Monitoring Form 2000-502,Periodic Emission Monitoring Using Portable Monitors X Form 2000-503,Control System Parameters or Operation 1 Parameters of a Process Form 2000-504,Monitoring Maintenance Procedures Form 2000-505,Stack Testing Form 2000-506,Fuel Sampling and Analysis X Form 2000-507,Recordkeeping 1 X Form 2000-508,Other Methods 1 1 V. EMISSION SUMMARY AND Total Number COMPLIANCE CERTIFICATION of This Form This application contains the following forms X Form 2000-600,Emission Unit Hazardous Air Pollutants 1 quantifying emissions,certifying compliance with applicable requirements,and developing a compliance plan X Form 2000-601,Emission Unit Criteria Air Pollutants 1 X Form 2000-602.Facility Hazardous Air Pollutants 1 X Form 2000-603,Facility Criteria Air Pollutants 1 X Form 2000-604,Applicable Requirements and Status of 1 Emission Unit Form 2000-605.Permit Shield Protection Identification X Form 2000-606,Emission Unit Compliance Plan- 1 Commitments and Schedule Form 2000-607,Plant-Wide Applicable Requirements Form 2000-608,Plant-Wide Compliance Plan- Commitments and Schedule VI. SIGNATURE OF RESPONSIBLE OFFICIAL - FEDERAL/STATE CONDITIONS A. STATEMENT OF COMPLETENESS I have reviewed this application in its entirety and,based on information and belief formed after reasonable inquiry,I certify that the statements and information contained in this application are true,accurate and complete. B. CERTIFICATION OF FACILITY COMPLIANCE STATUS-FEDERAL/STATE CONDITIONS(check one box only) I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. X 1 certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements,except for the following emissions unit(s): D-2 (list all non-complying units) • WARNING: Any person who knowingly,as defined in§ 18-1-501(6),C.R.S.,makes any false material statement, representation,or certification in,or omits material information from this application is guilty of a misdemeanor and may be punished in accordance with the provisions of§25-7 122.1,C.R.S. Printed or Typed Name Title David M.Jost Vice President of Northern Operations Signature Date Signed 2 Operating Permit Application CERTIFICATION FOR STATE-ONLY CONDITIONS FORM 2000-800 Colorado Department of Health 09-94 Air Pollution Control Division Facility Name: Enterprise Compressor Station Facility Identification Code:CO 123-0277 VI. SIGNATURE OF RESPONSIBLE OFFICIAL- STATE ONLY CONDITIONS A. STATEMENT OF COMPLETENESS I have reviewed this application in its entirety and,based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this application are true,accurate and complete. B. CERTIFICATION OF FACILITY COMPLIANCE STATUS FOR STATE-ONLY CONDITIONS(check one box only) I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. X I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements,except for the following emissions unit(s): D-2 (list all non-complying units) WARNING: Any person who knowingly,as defined in§ 18-1-501(6),C.R.S.,makes any false material statement, representation,or certification in,or omits material information from this application is guilty of a misdemeanor and may be punished in accordance with the provisions of§25-7 122.1,C.R.S. Printed or Typed Name Title David M.Jost Vice President of Northern Operations Siure Date Signed e / / SEND ALL MATERIALS TO: COLORADO DEPARTMENT OF HEALTH APCD-SS-B 1 4300 CHERRY CREEK DRIVE SOUTH DENVER,CO 80246-1530 3 BERM. `. N 60'SLUG GTCHER / I (OUT OF SERVICE) I MCC / / VMl0E1T05 BUILDING W E • /SLUG .. t- NGL TRANSFORMER _�C (OWNED BY ViUTY) a V-0101 INLET SLUGLCA/ NORTH BULLET CHER METHANOL UNDERGROUND SEPARATOR DRIP / ! l_..... .BERM. ' 1120'RECEIVER �; i % DAY TANK VAULT A� .__ ..-._.__. FUEL GAS '-r -SUMP,USED OIL DAY TANK 25 USED OIL..- C ENSATE SCRUBBER METER RUN yy BERN P LURE OIL SUMP 2 1 FGE-- ' FlL1ER U 7 GY TANK 24 BERM 0 rE/LUKE OIL 000��///rrr//// y__.__ PIPE RACK.__ .. O-...-- 1.I, RECEVER -' x FENCE FUEL GAS I DRUM to'RECEIVER SURGE TANK�� STORAGE _ ------ SURFACE WATER DRAINAGE DIRECTION 0 '' VOL TANK FILTER�IN� M -_ �� 1 a m m) SECONDARY CONTAINMENT BERM LOP OIL GL g M M M �.�.. . 'PIG TRAP G--- �BUIIDING ABOVE/BELOW GROUND PIPING F❑11}I AIR COMPRESSORS BLDG O! 1 ' 1 METER CONDENSATE SUMP-6 BERM 0 0 0 0 c 1110RMWATER m.: ao /\ COMPRESSOR SCRUBBERS ^ P WOATEN� ❑ AST-6 USED OLL PbxxxNmv C_!SS-1WIND FENCE _ BERMD SPILL La _ g�, BERM F s55��T0000mppprrru�a,�L6 I SUMP-2 � ,a NORKOOL -7 AUK WATER N NGI.e 1 - OSUMP-1 --a..._VRU. AST-11 w TEC AST- DISCHARGE COOLERS COOIEfl --.-_. n SI m 4ERW10L AST-10 o • M-5 TEG O EMPTY A. .SHED O FILTER VENT BERM E7 EKCHANCER.i� r2 STABILIZER LUKE Oil GLYCOL P w I. .... r.,...__,..11.#2 CONTACTOR BERM C_ i __OEATER O REBOILER : lAADOUT -....._.._._.._ I FILTER P'' DENY ftEGEN V65ELS eq p7�.DENY SNR) TANK k SURGE TANK • •• DISCHARGE�Q L' SEPARATOR 1'_"T CONDENNSER • SHED D PERMANENTLY CLOSED Ot��tST K/0 VESSEL CONDENSATE PRE-COOLER ��. - R4CA-y2/ND K/0 VESSEL 1 SUMP-3 '`\.O SUMP-7 TEG/CONDENSATE 1 6 FURS WITH. \ / BERM '1 ) �,,,_,__I FUEL GAS pa KNOGKOVi O \�� SUMP-6 TEG CONDENSATE BERM L METER DISCHARGE ""'7 VESSEL / NOTE: q AST-230 OAST( METER SKID IBMS PANEL-a- J BERM N T.OIL CONTAINING PIPES ARE DETAILED ON THE - - BTU to CONDENSER AST-220 OAST-y- Qom_.su4P_s P&ID DRAWINGS T O THE SITE AT THE ROGGEN PLANT O 0A$T,2 BERuIM NOLe AND THE GREELEY OFFICE. ROT 21 TRASH 0 2.THERE WERE APPROKIMATLY(5)FIVE 55 GALLON DRUMS ii __ __.. MONTH H. • AST-24 sc �a/2'RECEIVER O'�'� j WMP5TER OBSERVED ON—SITE AT THE TIME Of THE SITE VISIT, BERM B ' '' 12 LAUNCHER ,ity SHED) BUT THE NUMBER MAY VARY FROM TO MONTH. -...1 \� �_ pMETER ._ 1 BONE (8)300 BBL n S 1U L YARD ONDE SAT li y. W' E III��KR CONDENSATE is 3 HOUg STORAGE TANKS FLARE � KNOCKOUT I POT I ` 16'.. ' / \ FLARE J LAUNCHER J NOT OR SCALE ld sketch ad depicts the Otion dronin9 n nd an to obad on o ibaacn Al containing container,equipment.and piping(as required by 40 Main ENTRANCE ACCESS RD fCFR or sym.P:)).Prevention dram a a should only be used SW CORNER Plan(SPCC)purposes.As drawing is not to scale,actual fSEC 30 containers.equipment.a piping may wry M size and TJN.R63W N BA 20'23'E 1424.83' VOMITER from those represented here. SPCC PLOT PLAN REV DATE REVISION BY CART ENGR. - REV DATE REVISION BY CARD ENGR.w - ENTERPRISE COMPRESSOR STATION 0 12-12-03 DRAWN FROM DEES DARNING AND FIELD NOTES P.N.W. P.R. 5 7-16-13 REVISIONS PER:MARK-UP J.R.E. D.N.B. WELD COUNTY GATHERING SYSTEM-ROGGEN I 12-2B-07 REVISIONS PER WPM.FIELD SKETCH J.R.E. R.P.M. 6 7-16-14 REVISIONS PER:MARK-UP J.R.E. D.N.B. dj/� S/p9 Weld County 2 B-4-09 REASONS PER:R.P.N.FIELD SKETCH AR.E R.P.M. 7 3-9-17 REVISIONS PER:MARK-UP Midstream_ COLORADO 3 7-6-12 REASONS PER:M.C.F. JA.E. M.C.F. 4 1-2-12 REVISIONS PER:D.N.B.MARK-UP IRE D.N.B. \data\EnsDrawings\Mapping\Colorado\Weld\Enterprise_SPCC Colorado Department of Public Health and Environment Form APCD-102 Air Pollution Control Division C D P H E z .,.' Facility Wide Emissions Inventory Form Vet April,2017 ('ompanl Name:I1CP(lperatmg Company.LP ' Source Name:L:uterprlse Compressor Station *-'a Soarer Ants ID:123,[1277 1 00011rullyd Pote2ON to Emil(PIE) 1000911rd Yutenlial to Emil IPTl:1 l'rhrri+ll PS1 i 3101011177(7002,40,,.lrest I IIAPa llbnlyrl 4010 10 Ey0400510eseripti0n TSP 1?110 1021.5 9O2 005 VOC CO l 10110 0001 km. H(. Td 10 431 n-Hea Mexb 224.1'01 001 Po110 P111.5 101 NO, 3'01 CO I 0100 51501 cr0 B1 1'01 EH Sy, u-nea 01214 114-T011 053 Coc,r,C.Rx I., 105 105 lice 2400 1100_ 857:I I75) 915 SO - 526 -. 1OS I05 24.9 ±7.42 I , , -- 263 - ., Ins 14 u1 aX, x7. 43 '055 Ill01Ga5 I05 105 105 0 06 x400 11082 8570 1 17124 boil 925 0 4 _ __ 570 _ IOS 1 O 1 05 o 00 2.101 1100 27 42 1 5,421 S79 49 19 .. lot En{;inef±l6 1U 10. to_ 004 2100 21082 IS lb I 07.424 1,757 I,101 075 10 9 14 - 5_0 _ I16 IOS 100 1113 _01 7400 712 5 495 X17 1.10 o I9 - 203 - 11U3 I'4I3 Sb/rd oed('901.0591 ant, .. _ _ _ .. + S4 _ I -. _ r. 154 _ _ .. ._ _ _ _ .. _ I2x _. .. - - I. In ±WA 1 uvl J.nr4 P. Sob' ,drond T1uc31.970 1 .. _ - ... .. 2. I - .. _ . .. _. _. .. _ _ _ 011 _ - - 4 5 XI5 02 0004 ' I. 5.9 0. 112 Ili 01,0302 134 301, - - - 141 1 I - .. 101 59990 78,18o - _ 21 I 41 24 96 6.51 -- 11798 1,1,00,, 4_(09 (' 1i5 911 - 1 ,50 -201,018O.105 105 O d, 1 5 ,r 1 IIXI v .6- 5 _ 105 14 2 5185 f . 41 19 - -• 971 ,I:00C237 ,_ ISS 155 009 3101_281 Iv 125341 16.68 2,,I IW Ilas 127 14 ± _ 770 - 1-+ I 15I 77 1W 1201 12 01 +t 52 797 .3 tl 79 - 388 - e,411.LI ell 108111-1-1"ASCELLED _ errmimd.S'our5.0.626ul• 5.5 575 5/5 0.14 11941 461+31 4..011 1461, 9,62.1 .,917 156.149 1(1,734 2,400 61.015 OM+ 1.8+e 11 5+5 5.75 .5.,i ON 119.43 104.94 ISI.+6 10105 100 1,950 11..966 94,945 515 3,730 1.185. 1.430 I APED Only-Permit Laenipt Source, rat! ISOJ,n5d N'ale.5u.a;c _ _ _ .. _ 16 - I - - X6 _ _ _ -ol _ _ .. _ _ _ _ I: _ _ _ _ $6 _ _ _ _6v _ _ Ii______ 1 ,_API .1 Only 1u010,01- 0.0 0.0 0.0 0.0 0.0 1,6 11.011.00 0 0 16 0 0 0 219 0 U 0.11 O.0 00 0.0 O.0 L6 0.0 0 0 U 86 0 0 0 160 0 0 APES Eaempl'ImiBn.11000 sonrec7 1..110.0.0110 .- _ _ _ _ _ _ _. 54 - - .. - - InsiFnifscael Subtotal, 0.2 0,11 00 0.0 1.4 11.8 1.2 0 0 0 14 0 0 0 NI 0 0 0.0 0,0 0.0 00 1.4 81 ' 1.1 0 0 n .4 0 0 0 a 441 6 0 1'o 00,011000rces=i 57 I 6.7 I 5.7 I 0! I 130.9 I 1627.7 1416.2: 146,274 I 9.624 I 5.917 i 158628 125!.734 18,4119 161915 133.077 I 2.678 I 20 15.7 I 5.7 I 5.7 10.3 1110.11 460.3 I 154.0 I 19157 I 4111 I 2,950 1 II.so5 1189x51 515 13.7201 1,895 I 1.430 1 1 Uncontrolled I(3Pa Ssmsrmrl ITevtl 73.1 I 4.9 I 3.0 I 79.3 I 069 14.2 131.6 I I7.2 I 1.4 I 0.0 ' Cnna601ed IIAPs Summary I2P(I{14.2 I 24 I 1.5 I 7.8 1 1.0 103 I I.9 I 0.9 I 0.1 I 00 2Oconlrolled lotu1,A1111APslrPvl-1 3409 I Controlled luta,..11l ILO',('1Pv14 40.0 FOO1OO2OO1O I 'this form should he completed to include troth rooting 40410es and all'unposed new u1 ntodrtiCatons 10 eslshnp Oolt000lrs 5nurces 2 II the emissions source is new then enter'proposed"under the Pcrmil No and AIRS ID data coluotn9 3 HAP nhhrcvrutio0.s Include R/.=Heniene 224-151'- ''.4-1 rinlethvlpentenc 1'01=I oluene Aeetal-Acetaldehyde E1(-f.tbylhenzene .torn-Acrolem Nyl--Nylene 0-Iles-n-11242134 21(:11(2=Ionnaldeh3de Meth-Methanol 4 APFN l'.xerniall tslgollrcenl Sources should he included when warranted CCP Oparaung Company.LP 11119)2018 Page 1 of 1 CDPHE Glycol Dehydration Unit APEN aoy 014ie ' ►' Form APCD-202 /, CO tic>t;a5 • Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. This APEN is to be used for glycol dehydration (dehy)units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source(e.g. amine sweetening unit, hydrocarbon liquid loading,condensate storage tanks, 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.govicdphelapcd. 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: 95OPWE103 AIRS ID Number: 123 / 0277 /068 hd5 alre nSL ! LLL. Lor Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location: Site Location SWSW Section 30, T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 E-Mail Address2: rshankaran@dcpmidstream.com a Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. 390468 ' COLORADO _1 . _ _ L,Pt' oo l;rli s-. . 7 1431.3wttt w.. ... Permit Number: 95OPWE103 AIRS ID Number: 123/02n/068 I_E'd'✓ r� i1K ll[ _>AF CD h4... Section 2 - Requested Action O NEW permit OR newly-reported emission source -OR- ❑✓ MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment O Change company name3 O Add point to existing permit ❑ Change permit limit O Transfer of ownership' ❑ Other(describe below) -OR- ❑ APEN submittal for update only(Note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- El Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info&Notes: Cancel individual AIRS for COMB-1, combine combustion emissions under D-2 Reduce COMB-1 downtime from 3.0%to 1.0%, update various GLYCaIc parameters 3 For company name change,a completed Company Name Change Certification Form(Form APCD-106)must be submitted. 4 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 Company equipment Identification No. (optional): D-2 For existing sources, operation began on: 1/11/2001 For new or reconstructed sources, the projected start-up date is: O Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source hours/day days/week weeks/year Operation: Will this equipment be operated in any NAAQSEl Yes ❑ No nonattainment area? Is this unit located at a stationary source that is considered ❑ Yes ❑ No a Major Source of(HAP) Emissions? !COLORADO Do C ycc! Dehyd-3tion Unit APEN Reisi n 7'2, 1 2 I �� N.,;,,Fv ' .., Permit Number: 95OPWE103 AIRS ID Number: 123/0277/068 r >c_ h.., Section 4 - Dehydration Unit Equipment Information Manufacturer: Forum Model Number: Custom Unit Dehydrator Serial Number: Custom Unit Reboiler Rating: 2.5 MMBTU/hr Glycol Used: O Ethylene Glycol (EG) O DiEthylene Glycol (DEG) ❑✓ TriEthylene Glycol(TEG) Glycol Pump Drive: 0 Electric O Gas If Gas, injection pump ratio: / Acfm/gpm Pump Make and Model: Rotor Tech GS2212 #of pumps: Glycol Recirculation rate(gal/min): Max: 20.0 Requested: 20.0 Lean Glycol Water Content: 1.0 Wt.% Design Capacity: 110 MMSCF/day Dehydrator Gas Throughput: s 40,150 29,829 Requested :MMSCF/year Actual: MMSCF/year Inlet Gas: Pressure: 920 psig Temperature: 1 05 °F Water Content: Wet Gas: lb/MMSCF 0 Saturated Dry gas: 7.0 lb/MMSCF Flash Tank: Pressure: 35 psig Temperature: 140 'F ❑ NA Cold Separator: Pressure: psig Temperature: 'F 0 NA Stripping Gas: (check one) 0 None O Flash Gas O Dry Gas O Nitrogen Flow Rate: scfm Additional Required Information: 0 Attach a Process Flow Diagram O Attach GRI-GLYCalc 4.0 Input Report&Aggregate Report(or equivalent simulation report/test results) O Attach the extended gas analysis(including BTEX Et n-Hexane, temperature, and pressure) 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. r _ 3 I AV COLORADO -ijr�Iti�ltl U+'il�'1Pcta i E _,;;�, _ . Permit Number: 95OPWE103 AIRS ID Number: 123/0277/068 Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 /-104.4877 Discharge Height Operator Temp. Flow Rate Velocity Above Ground Level Stack ID No. CF) (ACFM) (ft/sec) (feet) COMB-1 25 Indicate the direction of the stack outlet: (check one) El Upward ❑Downward O Upward with obstructing raincap ❑Horizontal 0 Other(describe): Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter(inches): 36 0 Square/rectangle Interior stack width(inches): Interior stack depth(inches): ❑Other(describe): Section 6 - Control Device Information 0 Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Used for control of: ❑ Condenser: Type: Make/Model: Maximum Temp: `F Average Temp: 'F Requested Control Efficiency: Used for control of: Flash Tank vent stream ❑✓ VRU: Size: Make/Model: Requested Control Efficiency: 100 VRU Downtime or Bypassed: 5 Used for control of: all Vent stream Rating: MMBtu/hr Type: Enclosed Combustor Make/Model:Leed / L30-0018-00 rn Combustion LI-JDevice: •' Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: 'F Waste Gas Heat Content: Btu/scf Constant Pilot Light: ❑� Yes 0 No Pilot Burner Rating: 0.05 MMBtu/hr Closed Used for control of: 0 Loop Description: System: System Downtime: Used for control of: Flash Tank during 5%annual VRU downtime 0 Other: Description: Vent to ECD(COMB-1) Requested Control Efficiency: 95 % T.. r,a.. 232 la,!C?', i. F� 7 4 I �� COLORADO ICI)combustion device(COMB-1) used for still vent control has a 1.0%annual downtime for maintenance and repairs Still vent emissions will vent to atmosphere during periods of COMB-1 downtime. Permit Number: 95OPWE103 AIRS ID Number: 123/0277/068 ,,,... tl,, ,?Cr_.: s c . _ _ . _ a _ : Section 7- Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall(or combined)control efficiency(%reduction): Overall Requested Pollutant Description of Control Method(s) Control Efficiency (%reduction in emissions) PM SOX NO. CO VOC Enclosed Combustor(COMB-1) 95% HAPs Enclosed Combustor(COMB-1) 95% Other: From what year is the following reported actual annual emissions data? 201 7 Criteria Pollutant Emissions Inventory Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Pollutant Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis Units (AP-42, Emissions Emissions6 Emissions Emissions Mfg.,etc.) (tons/year) (tons/year) (tons/year) (tons/year) PM SOx NO. 0.068 Ib/MMBtu AP-42 0.15 0.15 1.43 1.43 CO 0.31 ib/MMBtu AP-42 0.80 0.80 6.51 6.51 VOC 33.03 Ib/MMscf GLYCaic 292.27 3.22 663.00 24.96 Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions6 Number Basis Mfg.,etc.) (pounds/year) (pounds/year) Benzene 71432 5.96 Ib/MMscf GLYCaic 81,307 1,394 Toluene 108883 7.13 lb/MMscf GLYCaic 117,432 1,016 Ethylbenzene 100414 0.19 Ib/MMscf GLYCaic 3,496 12 Xylene 1330207 2.39 Ib/MMscf GLYCaic 53,563 162 n-Hexane 110543 0.87 Ib/MMscf GLYCaic 13,144 176 2,2,4- 540841 Trimethylpentane Other: 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. Avir COIORaDO :v _'J_ G31/Lei D hydra iiw Unii r' i.' . 7 201 5 I h`[� " , Permit Number: 95OPWE103 AIRS ID Number: 123/0277/068 Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. ViCtkoti Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Senior Environmental Engineer Name(print) Title Check the appropriate box to request a copy of the: ✓0 Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692-3175 or(303)692-3148 APCD-SS-B 1 4300 Cherry Creek Drive South APCD Main Phone Number Denver, CO 80246-1530 (303)692-3150 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https:f/www.colorado.gov/cdphe/apcd ®� 7O 7O r ?CD <0? w ;col Dehydration U APEN nit R_ 7 :!? 6 . INFO TO SUPPORT 11/20/2018 Modification �x; � COLORADO Department of Public Health&Environment November 23, 2020 Roshini Shankaran Senior Environmental Engineer DCP Operating Company, LP 370 17th Street, Suite 2500 Denver, CO 80202 REF: DCP Operating Company, LP - Enterprise Compressor Station, OP #95OPWE103, FID# 123-0277 SUBJECT: Administrative Completeness Determination for Significant Modification Dear Ms. Shankaran: The application for the revision to the operating permit for the Enterprise Compressor Station (received November 20, 2018) to modify the TEG dehydration unit D-2 has been determined to constitute a significant modification as defined in Regulation No. 3, Part C, Section I.A.7. As stated in that section, significant modifications will be processed using the procedures set forth in Part C of Regulation No. 3, for combined Construction/Operating Permit issuance. Regulation No. 3, Part C, Section III.B.7 requires that facilities submit an application for a combined construction permit and operating permit on a standard application form supplied by the Division. Since the Division currently has no forms for this procedure, your November 20, 2018 letter and attachments (APEN, flow diagram and emission calculation methodology) fulfill this requirement. Fees Colorado Regulation No. 3, Part A Section VI.A.1 requires the division to charge fees to "...recover the direct and indirect costs incurred by the Division in processing permit applications, issuing • permits, and in conducting a compliance monitoring and enforcement program. Such fees shall apply without regards to whether a permit is issued, denied, withdrawn, or revoked." With respect to processing applications and issuing permits, fees will be charged for time spent reviewing the application and drafting the permit and associated basis document, including researching regulatory and technical issues related to the application and permit draft as applicable. Chargeable time also includes peer and supervisor review of drafts, as well as time spent by permit engineers and division management in meetings, phone calls, and responding to emails. The hourly permit processing fee is $108.12 beginning on July 1, 2020. Please see https://www.colorado.gov/pacific/cdphe/emissions- and-permitting-fees for additional information about fees. %Fc� t ,Ac Y. 4300 Cherry Creek Drive S., Denver,Co 80246-1530 P 303-692-2000 www.colorado.gov/cdphe 4 G Jared Polls, Governor I Jill Hunsaker Ryan,MPH, Executive Director , *!. Please note that the Division utilizes a quarterly billing system for all operating permits. The bills you receive will reflect chargeable time for the previous quarter. The Colorado Legislature has directed the Division to inform sources if the time spent processing an application will exceed 30 hours. The Division has determined that the time required to process your application for renewal of the operating permit will exceed 30 hours. Based on our experience in processing operating permits, we estimate that the total time required to process your application will be between 25 and 100 hours. This letter fulfills the Division's obligation to inform you that the processing time for your operating permit renewal will exceed 30 hours and to provide you with an estimate of the processing time. Timeline Significant modifications are processed under the same time lines and procedures as new operating permits, including Public Comment and EPA review. Within sixty (60) days of receiving an application for a significant modification the Division must determine if the application is administratively complete. Under the provisions of Regulation No. 3, Part C, Section IV.C, the Division has 18 months from the receipt of a complete application in order to approve or disapprove the application. The 18 month clock starts on the date a complete application is submitted. Please note that you cannot institute the proposed modifications to your facility until the revised operating permit has been issued. Required Additional Information The Division has determined that the November 20, 2018 application is administratively complete. If during the technical review of your application, the Division determines that additional information is necessary to evaluate or take final action on this application, a request will be made in writing for the information and a reasonable deadline for response set. If you fail to provide the requested information or do not meet the deadline, the Division will be unable to continue with the processing and issuance of the modified permit (Regulation No. 3, Part C, Section IV.D). Please do not hesitate to contact me if you have any questions at 303-692-6332 or elie.chavez@state.co.us. Sincerely, cat) Elie Chavez, P.E. Engineer, Operating Permit Unit Stationary Sources Program Air Pollution Control Division 11/23/2020 State.co.us Executive Branch Mail-Completeness Letter for 11-20-2018 Significant Modification COLO ADo Chavez-CDPHE, Elie<elie.chavez@state.Co.us> Completeness Letter for 11-20-2018 Significant Modification 1 message Chavez-CDPHE, Elie <elie.chavez@state.co.us> Mon, Nov 23, 2020 at 4:11 PM To: "Shankaran, Roshini" <RShankaran@dcpmidstream.com> Hi Roshini, I really apologize, but I let one of these completeness letters for Enterprise slip through the cracks-found it today as I was preparing for public notice. Please find attached the completeness letter for the significant modification application submitted on 11/20/2018 for the modification of downtime and addition of assist gas for TEG Dehydration Unit D-2(AIRS 068). Please let me know if you have any questions or need anything else!Again, I apologize for the tardiness! Thanks so much, Elie Chavez Permit Engineer Title V Operating Permit Unit Stationary Sources Program Air Pollution Control Division C _ ,y COLORADO ti" fir Air Pollution Control Division �� Department of Public Health 6 Environment P 303.692.6332 4300 Cherry Creek Drive South, Denver, CO 80246-1530 elie.chavez@state.co.us I www.colorado.gov/cdphe/aped Are you curious about ground-level ozone in Colorado?Visit our ozone webpage to learn more. 123-0277 Sig Mod Completeness Letter 11-20-2018.pdf 67K https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permthid=thread-a%3Ar9140966982572454242&simpl=msg-a%3Ar330274596... 1/1 6/1/2020 Modification Application DCP Midstream 370 17th Street,Suite 2500 / Denver,CO 80202 Midstream. 303-605-2030 May 29,2020 UPS Tracking Number 1Z F46 915 01 9414 8317 Air Pollution Control Division Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South,APCD-SS-B1 Denver,Colorado 80246-1530 RE: Produced Water Permit Application 123-0277,Enterprise Compressor Station SW1/4,SW1/4,Sec 30,T3N,R63W Weld County,Colorado Dear Sir/Madam: DCP Operating Company,LP("DCP") owns and operates the Enterprise Compressor Station located in the SW 1/4 SW 1/4 of Section 30,Township 3N,Range 63W,Weld County,Colorado. Enterprise is currently authorized under Colorado Department of Public Health and Environment(CDPHE)Air Pollution Control Division("Division")Permit No.95OPWE103,originally issued on May 1,1999. DCP is submitting a construction permit application package for the Enterprise Compressor Station. The Enterprise Compressor Station is an existing compressor station located in the 8-hour ozone nonattainment area. The produced water tank was a previously exempt source under the repealed exemption for produced water containing less than 1%crude oil (Regulation Number 3,Part B,Section II.D.1.m). As a result,DCP is submitting a complete permit application by June 1,2020 per the Division's "FAQ Volume 1 -Reg Rev Dec 2019"timeline. DCP is requesting to update the produced water tank at this facility with site specific emission factors. No other sources at this site are being updated with this submittal. Enclosed is a check for$191.13 to cover the APEN filing fee(1 x$191.13). Should you have any technical questions or need additional information feel free to contact me at (303) 605-2039 or RShankaranCZidcpmidstream.com. Sincerely, DCP OPERATING COMPANY,LP Roshini Shankaran Senior Environmental Engineer Attachments SPIRIT ENVIRONMENTAL Construction Permit Application Enterprise Compressor Station Weld County, Colorado May, 2020 PREPARED FOR: DCP Operating Company, LP Denver, CO SPIRIT PROJECT: 20329.OOA FOR SPIRIT ENVIRONMENTAL: ,gitirk, larei; Nicole Neyrey OFFICE: 720-500-3710 FAX:281-664-2491 1626 Wazee Street, Suite 2A Denver, CO 80202 spiritenv.com j CDPHE COLORADO Form APCD-100 CO Department of Public Health & Environment Oil & Gas Industry Construction Permit Application Completeness Checklist Ver.November 29,2012 Company Name: DCP Operating Company, LP Source Name: Enterprise Compressor Station Date: May 2020 Yes No Are you requesting a facility wide permit for multiple emissions points? ❑ Q In order to have a complete application, the following attachments must be provided, unless stated otherwise. If application is incomplete, it will be returned to sender and filing fees will not be refunded. Attachment Application Element Applicant APCD A APEN Filing Fees CI ❑ B Air Pollutant Emission Notice(s) (APENs)& ❑ ❑ Application(s) for Construction Permit(s)—APCD Form Series 200 C Emissions Calculations and Supporting Documentation Q ❑ D Company Contact Information- Form APCD-101 Q ❑ E Ambient Air Impact Analysis ❑ ❑ Check here if source emits only VOC(Attachment E not required) F Facility Emissions Inventory—Form APCD-102 El ❑ ❑ Check here if single emissions point source(Attachment F not required) G Process description, flow diagram and plot plan of emissions unit and/or ❑ ❑ facility DI Check here if single emissions point source(Attachment G not required) H Operating&Maintenance(O&M)Plan—APCD Form Series 300 El ❑ n Check here if true minor emissions source or application is for a general permit(Attachment H not required) 1 Regulatory Analysis E ❑ oCheck here to request APCD to complete regulatory analysis I (Attachment I not required) Colorado Oil and Gas Conservation Commission (COGCC) 805 Series Rule n ❑ Requirements—Form APCD-105 Check here if source is not subject to COGCC 805 Series requirements (Attachment J not required) Send Complete Application to: Colorado Department of Public Health& Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver,Colorado 80246-1530 Check box if facility is an existing Title V source: IXI Send an additional application copy Check box if refined modeling analysis included: [1 Send an additional application copy Check box if application is for major NA NSR or PSD permit: n Send eight(8)total application copies Page 1 of 1 FormAPCD-I00-AppCompleteChecklist-Ver I1-29-2012.docx Fixed Roof Tank Storage DCP Operating Company,LP Denver, CO _Fixed Roof Tank Routine Emissions Tank Identifier 123/0277/075 123/0277/075 Tank Name Sump 1 Sump 2 Product Name Produced Water Produced Water 'General Tank Information I AP-42 Reference] I Tank Type-Vertical or Horizontal Vertical Vertical Tank Type-Dome or Cone(Cone Default)(Only Vertical) Cone Cone Tank Type-Uninsulated,Shell Insulated,or Shell&Roof Insulated Uninsulated Uninsulated Height, Hs or Length, L(ft) 10.00 10.00 Diameter, D(ft) 8.00 8.00 Tank Capacity(bbl) 90 90 Liquid Height,HL(ft) 5.00 5.00 Maximum Liquid Height, Hex(ft) Eq. 7.1-37 footnote 9.00 9.00 Cone Roof Height, HR(ft) Eq.7.1-18 0.25 0.25 Cone Roof Outage, HBO(ft) Eq.7.1-17 0.08 0.08 Shell Color(White default) Gray-Light Gray-Light Shell Condition(Average default) Average Average Average Tank Shell Surface Solar Absorptance, as Tbl. 7.1-6 0.58 0.58 Roof Color(White default) Gray-Light Gray-Light Roof Condition (Average default) Average Average Average Tank Roof Surface Solar Absorptance,aR Tbl. 7.1-6 0.58 0.58 Vent Pressure Setting,PeP(psig) (0.03 psig default) 0.03 0.03 Vent Vacuum Setting, PBV(psig)(-0.03 psig default) -0.03 -0.03 Breather Vent Pressure Range,APB(psi) Eq. 7.1-10 0.06 0.06 Vent Setting Correction Factor, KB (dimensionless) Eq.7.1-40, 1-41 1.00 1.00 Vapor Space Outage, Hy()(ft) Eq.7.1-16 5.08 5.08 Vapor Space Volume,Vv(ft3) Eq.7.1-3 256 256 'Throughput I AP-42 Reference I Throughput(gal/yr) 279,273.75 279,273.75 Annual Liquid Level Increases, EH01(ft/yr) Eq.7.1-37 742.65 742.65 Turnovers, N(/year) Eq. 7.1-36 92.83 92.83 Turnover Factor, KN Eq. 7.1-35 footnote 1.000 1.000 Net Working Loss Throughput,VQ(ft3/yr) Eq.7,1-38 37,330 37,330 AP-42 Meteorological Data for: Denver, CO (Meteorological Data I AP-42 Reference Annual Average Solar Insolation Factor, I (Btu/ft2-d) Tb1.7.1-7 1,491 1,491 Annual Average Max Ambient Temp,TAx(°F) Tb1.7.1-7 88.0 88.0 Annual Average Min Ambient Temp,TAN(°F) Tb1.7.1-7 60.4 60.4 Annual Average Ambient Pressure, PA(psia) Tb1.7.1-7 12.1 12.1 Annual Average Daily Ambient Temp Change,ATA(°F/°R) Eq.7.1-11 27.60 27.60 Annual Average Daily Avg Ambient Temp,TAA(°R) Eq. 7.1-30 533.87 533.87 Annual Average Liquid Bulk Temp,TB(°R) Eq. 7.1-31 536.46 536.46 Annual Average Daily Temp Range,�Tv(°F/°R) Eq.7.1-6 or 1-8a 36.71 36.71 Annual Average Vapor Temp,Tv(°R) Eq.7.1-32 or 1-34b 541.24 541.24 Annual Average Daily Avg Liquid Surface Temp,T,A(°R) Eq. 7.1-27 or 1-29` 538.85 538.85 Annual Average Daily Max Liquid Surface Temp,TLx(°R) Fig.7.1-17 548.03 548.03 Annual Average Daily Min Liquid Surface Temp,TLN(°R) Fig.7.1-17 529.68 529.68 aUninsulated: Eq.7.1-6, Shell Insulated: Eq.7.1-8,Shell/Roof Insulated=Tex-TBN bUninsulated: Eq. 7.1-32,Shell Insulated: Eq. 7.1-34,Shell/Roof Insulated=TB °Uninsulated: Eq.7.1-27,Shell Insulated: Eq.7.1-29, Shell/Roof Insulated=TB (Product Data I AP-42 Reference I Product Stored Crude Oil RVP 5 Crude Oil RVP 5 Vapor Molecular Wt., My(lb/lb-mole) 50 50 Vapor Pressure at T,A, PVA(psia) 4.13 4.13 Vapor Pressure at T PFig 7.1-13b, 14b, P �x, Vx(psia) Eq.7.1-26 4.87 4.87 Vapor Pressure at TLN,PvN(Psia) 3.49 3.49 Daily Vapor Pressure Range,APv(psi) Eq. 7.1-9 1.39 1.39 Working Loss Product Factor, Kp Eq. 7.1-37a 0.75 0.75 Vented Vapor Sat. Factor, KS Eq.7.1-21 0.473 0.473 Vapor Density,Wv(Ib/ft3) Eq. 7.1-22 3.56E-02 3.56E-02 Vapor Space Expansion Factor, KE Eq. 7.1-5 0.2354 0.2354 'Emissions Rates (AP-42 Reference I Standing Loss, LS(Ib/yr) Eq.7.1-2 369.57 369.57 Working Loss,LW(Ib/yr) Eq. 7.1-35 996.33 996.33 Total Loss, LT(Ib/yr) Eq. 7.1-1 1,365.90 1,365.90 Total Loss(tpy) 0.68 0.68 Company Name: DCP Operating Company,LP Facility Name: Enterprise Produced Water Tank Emission Factor using Flash Liberation Sample and AP-42 VOC and HAPs emission factors Flash Emission Factors(Flash Liberation Sample) Flash Gas Properties 4.1 scf/bbl Gas to Water Ratio 7.30E-04 m3/L(for APEN) Molecular Weight 33.6 Ib/Ib-mol VOC 35.74% wt% n-Hexane 3.30% wt% Benzene 0.43% wt% Toluene 0.34% wt% Ethylbenzene 0.01% wt% Xylene 0,07% wt% 2,2,4-Trimethylpentane 0.00% wt% Emission Factor Calculation Methodology Compound emission factor(lb/bbl)=Flash GWR(scf/bbl)x MW of flash gas(lb/lb-mol)x[1/379.41(set/lb-mot)]x wt%of compound in flash gas(wt%) Emission Factors VOC 0.13 lb/bbl n-Hexane 0.01 lb/bbl Benzene 1.57E-03 lb/bbl Toluene 1.23E-03 lb/bbl Ethylbenzene 2.76E-05 lb/bbl Xylene 2.46E-04 lb/bbl 2,2,4-Trimethylpentane 3.18E-06 lb/bbl Working and Breathing Emission Factors(AP-42) Compound wt°t°of TOC Working Losses* Breathing Losses* Total W&B Losses Production W&B Emission [Ib/yr] [lb/yr] [Ib/yr] (bbls/year) Factor(lblbbl) TOC 1,992.66 739.14 2,731.80 VOC 53.51% 1,066.19 395.48 1,461.67 0.11 n-Hexane 4.95% 98.58 36.57 135.15 0.01 Benzene 0.65% 12.89 4.78 17.67 1.33E-03 Toluene 0.51% 10.07 3.74 13.81 13,299 1.04E-03 Ethylbenzene 0.01% 0.23 0.08 0.31 2.34E-05 Xylene 0.10% 2.02 0.75 2.77 2.08E-04 2,2,4-Trimethylpentane 0.00% 0.03 0.01 0.04 2.69E-06 Note:Gas composition for working and breathing losses based on gas composition from flash liberation sample *From AP-42 Breathing&Working Calculations Tank emission factors(AP-42+Flash Liberation Sample) Flash EF W&B EF Combined EF Compound (lb/bbl) (Iblbbl) (lb/bbl) VOC 0.13 0.11 0.24 n-Hexane 0.01 0.01 0.02 Benzene 1.57E-03 1.33E-03 2.90E-03 Toluene 1.23E-03 1.04E-03 2.26E-03 Ethylbenzene 2.76E-05 2.34E-05 5.10E-05 Xylene 2.46E-04 2.08E-04 4.54E-04 2,2,4-Trimethylpentane 3.18E-06 2.69E-06 5.86E-06 I Company Name: DCP Operating Company, LP , Facility Name: Enterprise Produced Water Storage Tank Emissions Calculations VOC and HAPs Actual Emissions Control Description: None Production for 2019 Actual Calculations: 9,718 Control Efficiency: 0% Annualized production based on average daily production Emission factors are based on PS Memo 09-02. Listed below are the appropriate emission factors. EF(lb/bbl) VOC Benzene n-Hexane Toluene EBenzene Xylene 2,2,4-TMP PS-Memo 09-02 0.262 0.007 0.022 — — — — 2019 Actual Calculations: Uncontrolled Emissions VOC Benzene n-Hexane Toluene EBenzene Xylene 2,2,4-TMP (ton/yr) (lb/yr) (Ib/yr) (Iblyr) (lb/yr) (lb/yr) (Ib/yr) 1.27 68.02 213.79 - - -- - tpy=> 0.03 0.11 — — — — Controlled Emissions VOC Benzene n-Hexane Toluene EBenzene Xylene 2,2,4-TMP (ton/yr) (lb/yr) (lb/yr) (Ib/yr) (Ib/yr) (lb/yr) (Ib/yr) 1.27 68.02 213.79 - - - -- tpy=> 0.03 0.11 — — — -- Example Calculations: Uncorrtroll ed Emissions (! )=annual Ummntroll ed Throughput(bbl l•Emission Factor(--M ) Jb ) 0* yr J l bbl J Controlled Emissions /b =Annual Controlled Thronghpn bbl •Emission Factor( lb 1•(1-Control E•Q'cienty) (3r) )r bbl, +Annual Cncontrolkd Throughput bbl .Emission Facto lb it bbl 1'OC Emissions taro -Emissions lb 1 ran Emissions( 3r J (}r (2.000/b� a.&B Gas(Willful rr ton} (2.000lb 2.000(b),( I ) (379:IISCFGns) ( I f Bin ) (12"lifr) Uncontrolled roc( J ll 1 ( J ) t Heat Confetti J �r ton Gas Ain. lb-mol i•OC°o SCF 106 Rot Company Name: DCP Operating Company,LP Facility Name: Enterprise Produced Water Storage Tank Emissions Calculations VOC and HAPs PTE Emissions Control Description: None Production for PTE Calculations: 13,299 Control Efficiency: 0% Annualized production based on average daily production Site-specific emission factors based on a flash emissions analysis have been used to calculate emissions. Listed below are the appropriate emission factors. Site Specific Emission Factors have been used to caculate Emissions based on Tanks 4.0.9 and Flash analysis EF(lb/bbl) VOC Benzene n-Hexane Toluene EBenzene Xylene 2,2,4-TMP Site Specific 0.240 0.003 0.022 0.002 5.100E-05 4.541E-04 5.865E-06 PTE Calculations: Uncontrolled Emissions VOC Benzene n-Hexane Toluene EBenzene Xylene 2,2,4-IMP Flash Gas (ton/yr) (lb/yr) (lb/yr) (lb/yr) (lb/yr) (lb/yr) (lb/yr) (MMBtu/yr) 1.59 38.53 294.79 30.11 0.68 6.04 0.08 133 PTE tpy=> 0.02 0.15 0.02 0.00 0.00 0.00 33.64 Gas MW' 0.357 Fraction VOC by Weight* Controlled Emissions 1,319.95 Gross Heating Value`(btu/scf) VOC Benzene n-Hexane Toluene EBenzene Xylene 2,2,4-TMP *From Flash Analysis (tontyr) (lb/yr) (lb/yr) (lb/yr) (lb/yr) (lb/yr) (lb/yr) 1.59 38.53 294.79 30.11 0.68 6.04 0.08 tpy=> 0.02 0.15 0.02 0.00 0.00 0.00 Example Calculations: (—)- (—)• j CboontroB er/Emission, i$)-Anton!G"rcmnd!ex/P ru. ym 1 bbl •Emission Fn,er{bb/ yr l• ( l Controlled Emdssiorn(16)•-Annual Controlled Thronghpu1 661} Emb,lon Focrorl !6 1.(i-Control Ef- n,r) . p.) p.J lbbd.!!! +Annual Uncornrolkd ThronRf'r h r bb! !b,EmAsion Faro,{( l 9 r, tbb1�y F4( Em llssiorit tp's 1-Eminions(M)( I ion ) 1 )r 111 lyr 2.000/6 W&B Gnsll•.VL/Bnr ,r ( I (3 79.4 ISCF Gos ( I Bin I.V3/Bnu LiroonaolPd m(1,1 (2,000,61- 1 I � I -Xeni Cowen 1 ran 11 l Gas AM' l !b-tool t FIX..e SCF I .iv Ens Alliance 5530 Marshall Street Arvada,Colorado 80002 Phone:303-420-5949 Fax:303-420-5920 SOURCE TESTING FLASH LIBERATION ANALYSIS OF SEPARATOR WATER SAMPLE DATA PROJECT NO OG-2020-0116 SAMPLE ID . Pressurized Water COMPANY NAME DCP Midstream ANALYSIS DATE 3/12/2020 SITE Enterprise SAMPLE DATE 3/6/2020 UNIT ID V0101 CYLINDER NO 37653 SAMPLED BY AJM LAB ANALYST CLB FIELD DATA SAMPLE PRESSURE 97.8 psig SAMPLE TEMP 48 F AMBIENT PRESSURE 12.3 psi AMBIENT TEMP 34 F COMMENTS: Flash Liberation of Pressurized Water Pressure Temperature Separator Produced Water 98 psig 48°F Stock Tank 12.3 psia 60°F Base Conditions 14.65 psi 60°F Flash Liberation Results Result Units Gas Water Ratio 4.1 SCF flashed gas/bbl stock tank liquid Gas Specific Gravity 1.1614 Air=1.00 Quality Assurance Result Duplicate GWR RSD(20%max.) 1.29% 5530 Marshall Street Al I I a AMY Arvada,Colorado 80002 Phone:303-420-5949 Fax:303-420-5920 SOURCE TESTING Flashed Gas Extended Analysis SAMPLE DATA PROJECT NO OG-2020-0116 SAMPLE ID Flashed Gas COMPANY NAME DCP Midstream ANALYSIS DATE 3/12/2020 SITE Enterprise SAMPLE DATE 3/6/2020 UNIT ID...... V0101 CYLINDER NO 37653 SAMPLED BY AJM LAB ANALYST CLB LAB CONDITIONS PRESSURE 12.2 psi TEMPERATURE 72 F COMMENTS LABORATORY DATA COMPONENT MOLE% WT% GPM HYDROGEN SULFIDE 0.0000 0.0000 0.0000 CARBON DIOXIDE . . . 24.1511 31.5995 4.1399 NITROGEN 1.9284 1.6061 0.2131 METHANE... - 44.3214 21.1389 7.5472 ETHANE 11.0931 9.9167 2.9799 PROPANE 6.1663 8.0839 1.7064 ISOBUTANE . 1.0970 1.8956 0.3606 N-BUTANE 2.8856 4.9863 0.9138 ISOPENTANE 1.3229 2.8377 0.4860 N-PENTANE 1.8662 4.0030 0.6795 CYCLOPENTANE 0.1475 0.3075 0.0439 N-HEXANE 1.2898 3.3045 0.5327 CYCLOHEXANE 0.2777 0.6948 0.0949 OTHER HEXANES 1.7149 4.3692 0.6858 HEPTANES 0.7737 2.3009 0.3550 METHYLCYCLOHEXANE 0.2524 0.7368 0.1019 2,2,4 TRIMETHYLPENTANE 0.0003 0.0009 0.0001 BENZENE 0.1860 0.4320 0.0522 TOLUENE 0.1232 0.3376 0.0414 ETHYLBENZENE 0.0024 0.0076 0.0009 XYLENES 0.0214 0.0677 0.0083 OCTANES 0.2422 0.8184 0.1210 NONANES 0.0517 0.1968 0.0290 DECANES PLUS 0.0846 0.3578 0.0521 SUBTOTAL 100.0000 100.0000 21.1455 OXYGEN/ARGON 0.0000 0.0000 0.0000 TOTAL 100 100 21.1455 BTU MOLECULAR WEIGHT... 33.6359 NET DRY REAL 1199.8179/scf RELATIVE DENSITY(AIR=1) 1.1614 COMPRESSIBILITY FACTOR 0.9930 GROSS DRY REAL 1319.9469/scf GROSS WET REAL 1296.6066/scf ANALYTICAL PROCEDURES TAKEN FROM GPA 2286-95 CDPHE COLORADO Form APCD-101 Department of Public Co Health & Environment Company Contact Information Form Ver.September 10,2008 Company Name: DCP Operating Company, LP Source Name: Enterprise Compressor Station Permit Roshini Shankaran Compliance Branden Hayes Contacts: Contact': y 370 17th Street, Suite 2500 3026 4th Avenue Address: Street Address: Street Denver CO 80202 Greeley CO 80631 City State Zip City State Zip Phone Number: (303) 605-2039 Phone Number: (970) 378-6389 Fax Number: (303)605-1957 Fax Number: (303)605-1957 E-mail: RShankaran@dcpmidstream.com E-mail: BSHayes@dcpmidstream.com Billing Contact: Bifiling lFees�t;-: Roshini Shankaran (PermitFees)j Roshini Shankaran Annual Fees)! 370 17th Street, Suite 2500 370 17th Street, Suite 2500 Address: Street Address: Street Denver CO 80202 Denver CO 80202 City State Zip City State Zip Phone Number: (303) 605-2039 Phone Number: (303) 605-2039 Fax Number: (303)605-1957 Fax Number: (303)605-1957 E-mail: RShankaran@dcpmidstream.com E-mail: RShankaran@dcpmidstream.com Check how would you like to receive your permit fee invoice? Mail: n E-mail: n Fax: ri Footnotes: The permit contact should be the point of contact for technical information contained in the permit application. This may be a company representative or a consultant. 2 The compliance contact should be the point of contact for discussing inspection and compliance at the permitted facility. 3 The billing contact(Permit fees)should be the point of contact that should receive the invoice for fees associated with processing the permit application&issuing the permit.(Reg. 3,Part A,Section VI.B) The billing contact(Annual fees)should be the point of contact that should receive the invoices issued on an annual basis for fees associated with actual emissions reported on APENs for the facility. (Reg. 3,Part A, Section V1.C) Page 1 of 1 AP_Form-APCD-tO 1-Company-Contact-Information(2)doe Colorado Department of Public Health and Environment • Form.4510-102 I Air Pollution Control Division CD ��//Pr HE Facility Wide Emissions Inventory Forml . Vcr.Apnl,2O15 CO Co.poo Name:lx'P Operating Company,I.P Ir •Of Source Name:I::nrolpli4e Compressor Station 544 Source AIRS ID:123/O277 4loewrv4461..4.61 to C.d.(Pik) 4.09.144 Pm.0061..times(100:1 .UKim 4005» J 4447.010.7401 1311 Vp .P 4014044 deal you J ue — .I.Me6.h.4 aln 1•.19.»..INeA4..4e rsnp Di sot NM SIX' en I IrmRb 12...1 i.e. Ire 1V CH—XIC 1024 -Mat . 75¢, 54Jz rn , nrnn -300.0 4 A,! 3404 444-1 am 05; 82774027 C-250 240q >4-1 - 524 - 0 45 11 I 05' . 2711 - _ _ 055 En,.4'-115 105 _ 24,00 210.2 45-0 1 _ 0• _ _ 105 2 1 - i ' _ _ 051 4,Loa 4246 105 III, 1962 46 4400 2 k5 70 1 27,42+ 2151 71.000 44 - 542 - 105 115 4.05 0.04 1400 7490 2^13 1 5,411 40. 5 - 462 44 5 17 - _41 - 13.01?So.4.4.055.54169504 < ee T.N. — — — — 005 1i 2 — _ — ell 1 1 141.1 0.491 — — — — — — 915 ..— — 41 152 10 112 > — — 060 091651.101uWan t' 0.m.lc T..:6 55.4.1.7 — — — _ 001 _ 4�1.151 44 41: — — — 175 215 0 t 1.275 — — — — — — 4J. 0.?+ U14 — — — 1 11 u - 61 — — ♦ u'F111;U 14211051114.1.1115.10.5 _'24 070 1,6, 1e.41 10.5 105 1.05 g1 210412 X5.'4! :'1.424 1751 6011415 .530._ — 105 1.05 1.0,5 0. 74. ?9.12 j 1.5 157.1 510 5 — — 011 Eng.1•-277 1,55 155 ISO 29 }2.01 2051. 125741 26374 2,5.4 I5,5 0.345 19 14 57 — 114 _ 115 151 15. 409 t091 W 1410 4654 , 9.'110 1;209 707 104 0a 1 5 — I00 — O'ASV11LLI1 151414-4.4':\0.11:0514 I 1 T6n 0Y0NP406 -5- 55 67 -J - _ - - ss nl 06 ie+ - 0 073 IT1145.545444JTE440405 - - - - 1.40 64+11 ' 6.12 I - - - 15420? 441,612 k777 45,500 ::4710 0450 - - _ _ IJv 21 VS 602 - - - 7.7, 11.251 AV 2125 016 s 075 4'rWwW W.tn S1.e.0< I fe - I - - _ _ .9 .4 I 4 30.5 - u 1 50 - - - - . i0 1 n .?5 _ 0 - P..m1n.•0.mn.44•...M 5, 0,7. 115 515 034 130-. ..04445 47141; 146374 9441 5,917 430,425 200,454 4400 40375 551» 4.140 47 575 4.75 0,70 644 120.57 1900 154.44 I 20375 4.112 1.070 40,140 44444 000 0.741 7.111 4,47 1 A7L15 04{-Pen.1....7*44. _ 1 _ I 1 I I- _ 1 I - _ _ _ APE 0.670.Nw.I- 1• 5.• •e 19 0.• 10 •.9 I. 9 . . . . . . . . . ... .. ... .. ... .. .. . . . . . . . . 0 a 0 .67174 6....1./1rIgo40u1.w.... 06 4m,594o Aanlee - - - _ - - 1 0 51 - 00 i - - 1 - _ I I 0 _ J 0.50.614156.9 4.YaN. 0.0 0.0 0.0 0.9 4,4 51 0.9 I e 0 4 _ 4< 0 • • 479 0 0 04 0.0 0,e' 4.4 4.0 _54 10 0 0 a 4 4 9 0 0 215 6 4 11444.1111.0.•41 57 I 7.' 1 5.7 I 424 I 00.4 110015 I 47.4; 144.174 I 9.424 I 5411 1440.470 1210,436J 6,421 140.1741 35.504 1 3,040 I O 1511 3,7 I 67 10.11 1104 I V.I 4544 : 11]05 I 4,144 I 1.050 140,491 142.4x1 404 12•x1 1 0.144 I 1.447 I I ' r.n..,S1d11.44'.O.Owr..41,1. 74.2 I 40 I JP I 61.7 I 1.27 I 4.2 I 441 1 47.4 I LS I 14 I c.....¢Ar.Wm.w9 rrn)4 44.2 I 2.4 I LS I Si I 4.1 I •3 I 4.7 I 14 I 0.. I 00 (•....o-.a.4T..,A44AP.(rrv5.I 1x.0 1 4....55114.11.....01 RAnCITY)4 44.5 I I '1'410 form should be completed to include both esls4ing sources and all proposed 5400 or nladilicatons to existing<m4140nna sources 2 If the enuss4uns source 4s new then enter"proposed'under the rem,No and AIRS ID dam 004,40, • 4 HAP uhbreviatione include HZ Benzene 424-TMP=2,2,4-(nnoelhylpenlane • Tel=Toluene Acetal=Acetaldehyde • EH-Why lbenzene Auto=Acroleu4 Xyl=Xylem n-Het=n-Ilezole • HCHO=f oonuldehydc Meth=Methanol 4 ANN I-_zempt/lmign.licunt Sources should he Included when 0artumcd CCP Opealoq Company,LP 5/1912020 Page 1 of 1 DCP Operating Company, LP Enterprise Compressor Station Attachment G Process Description, Flow Diagram and Plot Plan Attachment G: Process Description and Flow Diagram DCP Operating Company, LP Enterprise Compressor Station ATTACHMENT G Process Description and Flow Diagram The Enterprise Compressor Station takes natural gas from surrounding sources and compresses the gas to pipeline pressure. The incoming gas goes through an inlet slug catcher where liquids are removed and sent to two(2) pressurized bullet tanks. The gas is then compressed via five(5) natural gas fired compression engines (IDs C-238, C-238, C-236, C-234/P-018, C-237), dehydrated via one (1) TEG dehydration unit (ID D-3), and sent to a gas plant via pipeline for further processing. The overhead still vent emissions from the TEG dehydrator (ID D-3) are routed to an enclosed combustor ("ECD"). The ECD is estimated to be down one (1) percent of the time, during which the still vent emissions will be vented directly to the atmosphere. The TEG dehydrator flash gas emissions are routed back to the inlet of the facility via a vapor recovery unit ("VRU"). The VRU is estimated to be down five (5) percent of the time. During VRU downtime, emissions from the flash tank are routed to the ECD. The liquids are stored in a pressurized bullet tank. Condensate is stored in eight (8) 300 bbl atmospheric storage tanks (ID P-013) and hauled offsite via a truck loading rack (ID P-016). Produced water is stored in a two (2) 90 barrel (bbl) produced water sump tanks (ID SUMP-1, SUMP-2). Spirit Environmental, LLC May 2020 1 of 1 Enterprise Compressor Station Process Flow Diagram DCP Operating Company,LP 0 Combustor A 8—300bb1 Stabilized Condensate Tanks > Truck Loading A 1 Condensate 2-90bbl Water Gas Sump Tanks Back-up Stabilizer > , V >0 Enclosed Combustor A VRU < —T CWest Pressurized Bullet < Gas Return A s BTEX c to Inlet :3 Condenser t Condensate Condensate m U- Slug Catcher ( East Inlet Gas v Gas > Pressurized Inlet Bullet J Gas > Compression > Dehydration _> Outlet Gas —'> Slug Catcher \ O-3 Compressor Blowdowns to atm ( E BERM N -',10'SLUG CATCHER (OUT OF SERVICE) WC ,/,/SWO RCA TRANSFORMER -•'C BY UTIUTT)NORTH BIAL.51 (OWNED NEST La B ROLDRIP IMEf^�SL CATCHER j 2C IRCETER M ri O L� WARNER PAT TANK t jA _ NEL CAS SCRUBBER �—/'� °AWIMP � 2' USM OIL ED OMP Z CONDENSATE UNDERGROUND METER RUN RIRR B L1 1 1ru DtY r"OOR24 y BMA o LEGEND M —x— FENCE PPE RACK 10'RECENER 20RCE FM O1 --- ('j O'r 11 SURFACE WATER DRAINAGE DIRECTION IF 'IMMURES1LEA 1 / lHl%AI/lw-•Y//%//N/N%N//N%Hn�/ ( _ '•/// / / % I-i SECONDARY CONTAINMENT BERM �27OOp G /% /�// ELOW GROUND PIPING I PIG IMP BEi01g �� y, Nnmm -------- ABOVE/BELOW MR COMPRESSORS I BLDG iY�//�//��//l/ /. /I' '.�G.•._..'/�•f` M CONDENSATE 3 s 3'4 BEM a . . . . • COIPRESICR SOMMERS PROOUCED WATER rnND FENCE ARr-.USED out. " �� ss-1 BEAM 0 1, v�An ,--L BER4 F �pAVli,W __ SAP-2� �❑/MRa R (I�i NOPo(ODL//AS5$}fF--e7B ®Atp B'ATEA 13 MCI. -1 G'•^'�,J Si: 1110E ASf-1 COOlL110 R I--�p,cn, „ /' ART-11 iK-5 RC i1LlEl VENT t $3 EMPTY 1 ExCW10ER {2 STASUZER ua[G'VI GLYCOL 9I CMIRACTOR BM iGADdR i O � E K� ODfi R[OD1 • 9 YL45TDS R t,____:,,,,,,,,..0 astragal iv} IJ G SURGE TMOI 06CIMRGC SEPARATOR I _-.1 Cod C0SCO S'',1.. ❑ PERMWDOLY ,50 I(/O VESSEL SLED SUMP-3 PRE-COOLER '-'.41'21-- RIO VESSEL CONDENSATE (-f] O `• SUP-7 TEL/COIOENSATE BEM BERM A LJ Fu¢-. d NMocRa RARE"ir o • wMP-e TEc/CalIRNSAYS NOTE: AR_T3O O BERM L METER 1 M�� -'lSS��VESSEL 11 N I.OIL CONiNNINC PIPES ARE DETARED ON THE 222222 i "' b PkID DRAWINGS FOR THE SITE AT THE ROGGEN PLANT t A"11Ot O� ! — S AND THE GREELEY OFFICE AMf-4O F-Y I-7 n If RECDJER p 2.THERE WERE APPROX1MTLY FIVE 55 GALLON DRUMS OBSERVED ON-SITE AT THE TTIME OF THE SITE VISIT, ��B 1Y LAIRICNER 1 ® ` BUT 711E NUMBER MAY VARY FROM MONTH TO MONTH y}� METED SONS i CO 300 BBL. / `� 6l LW" CONDENSATETANKS 2 V I' HOUSE p3' STORAR TAMGE ES FLARE KNOCKOUT POT A \ FLARE J 1N I \ .Note M bw.lke and I.mMb el Non MN W and contains,.yymRt NM NOM,(a•rewind R7 NO MAN ENTRANCE ACCESS'RD RR 1127(3)). TAY*wing a-..d far SMI Prevention ol ma COMItIIIITIMMAID SW CORNER Plan(SPCC)pMPo.M A.dgpgMq ta way m IIola l3K N63lac la_ _ Nu and R BP 20'23'E 142403' P0RRYn Irma them I.P...N.d br.. SPCC PLOT PLAN REV BATE REVISION NV YRFD (NM,.T REV DATE REVISION BY awn ORR TZT ENTERPRISE COMPRESSOR STATION 0 12-12-03 DRAIN FROM RUN ORAISW NO FIELD NORM PYRE RA B 7-1S-13 REVISIONS PER MARK-UP IR.E ONE WELD COUNTY GATHERING SYSTEM-ROGGEN 1 12-12-28-07 REVISIONS PER RPM.NOD SKETCH ALLRP.M R 7-11-14 PENSIONS PER MAIN-UP ARE DNA, 2 0-4-01 PENNONS PER RF.M.FIELD SKETCH ARE R.P.M. 7 38-17 REMB016 PER WIN(-UP RAM., EM. P� Weld RADOl 3 7-1-12 PENSIONS PER M.C.F. E.C F. IRE F. Midstream. COLORADO ' 4 1-2-12 REVISIONS PER DAIL MARK-3P IRE DAR \OOth\Eh.OFORR1g5\Mtyying\COIS.Od0\WNd\ENtaryPIM_SPCC Attachment I. Regulatory Applicability Information DCP Operating Company, LP Enterprise Compressor Station ATTACHMENT I Regulatory Applicability Information This applicability analysis is for updated equipment and emission sources found at the Enterprise Compressor Station operated by DCP Operating Company, LP ("DCP") in Weld County, Colorado. DCP will continue to comply with the state and federal regulatory requirements per Permit 95OPWE103. This section addresses the state and federal regulatory applicability specific to the proposed modifications at the Enterprise Compressor Station. Regulation 3, Part A, Section II: The Air Pollution Emission Notice (APEN) forms for the equipment included in the proposed modification are provided in this application. • PW Tanks(123/0277/075): APEN Required & Permit Required Regulation 3, Part B: The facility is subject to this regulation and this application serves to apply for the required construction permit for the increase in emissions above the permitting threshold. Regulation 3, Part C: This facility is and will continue to be a major source with respect to the Title V Operating Permit Program. DCP will be required incorporate this update into the existing Title V Permit within 12 months of startup per Regulation 3, Part C, 11113.2 or the reclassification of the Denver Ozone Non-attainment area from moderate to serious. Regulation 3, Part D: This facility is a major source of NON, CO and VOC with respect to Nonattainment New Source Review. Emissions from the proposed modification do not exceed the Nonattainment New Source Review significant emission rates. The facility will continue to be a true minor stationary source(s)with respect to PSD and therefore not subject to this regulation. Regulation 7, Part D, Section I.: This facility is in the 8-hour Ozone Control Area and therefore subject to Section I. of this regulation. • This is a new/modified facility and will comply as required with Regulation 7, Part D, Section I. Regulation 7, Part D, Sections II. & Ill., and Part E, Section I.: Regulation 7 describes the statewide requirements for oil and gas operations. This section applies to atmospheric Spirit Environmental, LLC March 2020 l�J 1 of 2 Attachment I: Regulatory Applicability Information DCP Operating Company, LP Enterprise Compressor Station hydrocarbon liquids and produced water storage tanks, hydrocarbon liquids loading, pneumatic controllers,glycol natural gas dehydrators, and natural gas fired reciprocating internal combustion engines. Dehydrators and internal combustion engines that are subject to an emission control requirement in a federal maximum achievable control technology ("MACT") standard under 40 CFR Part 63, a Best Available Control Technology ("BACT") limit, or a New Source Performance Standard ("NSPS") under 40 CFR Part 60 are not subject to these sections. DCP will comply as required with Regulation 7, Part D, Sections II. & III., and Part E, Section I. Regulation 7, Part D, Section II.C.1.c: Sump 1 and Sump 2 do not emit VOCs greater than 2 tons per year on a rolling basis and no air pollution control device will be installed. Regulation 7, Part D, Section II.C.4.: Sump 1 and Sump 2 are not controlled storage tanks and are not applicable storage tank measurement system requirements for natural gas processing plants. Regulation 7,Part D,Section II.C.5.: Loadout operations from the produced water storage tanks are not applicable to this section; therefore, will not need to comply with the applicable control requirements for natural gas processing plants. Spirit Environmental, LLC March 2020 2 of 2 Produced Water Storage Tank(s) APEN X440 Form APCD-207 CDPHE 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. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for tanks that store produced water associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source(e.g. crude oil storage tanks,condensate storage tanks, hydrocarbon liquid loading, 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 and associated addendum forms can be found on the Air Pollution Control Division (APCD) website. 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: gt5op,, I 3 AIRS ID Number: 123 /0277 /075 [Leave thank uniess APCD has already assigned a permit r and AIRS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30, T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: (Include Zip Code) 370 17th St., Suite 2500 Denver, CO Contact Person: Roshini Shankaran Phone Number: (303) 605-2039 E-Mail Address2: RSankaran@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 the APCD via e-mail to the address provided. 431966 COLO!ADO �F S oia Ta: k si APEN R is n 1 14 1 OIr° tivaenw Permit Number: AIRS ID Number: 123 /0277/075 Section 2 - Requested Action O NEW permit OR newly-reported emission source 0 Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP05 O GP08 • If General Permit coverage is requested,the General Permit registration fee of$312.50 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit(check each box below that applies) ❑ Change in equipment ❑ Change company name3 ❑ Change permit limit ❑ Transfer of ownership' ❑ Other(describe below) -OR ▪ APEN submittal for update only(Note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ED APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info a Notes: Revising emissions to reflect a site-specific emission factor. Actual emissions below are based on PS-Memo 09-02 emission factors. 3 For company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted. 4 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: Produced Water Storage Company equipment Identification No. (optional): Sump-1 & Sump-2 For existing sources, operation began on: 2/04/2008 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Storage tank(s)located at: O Exploration&Production(MP)site 0 Midstream or Downstream (non E&P)site Will this equipment be operated in any NAAQS nonattainment area? 0 Yes O No Are Flash Emissions anticipated from these storage tanks? 0 Yes ❑ No Are these storage tanks located at a commercial facility that accepts oil production ❑ Yes J No wastewater for processing? Do these storage tanks contain less than 1%by volume crude oil on an annual average basis? ❑✓ Yes O No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission(COGCC) ❑ Yes 0 No 805 series rules?If so, submit Form APCD-105. Are you requesting≥6 ton/yr VOC emissions(per storage tank), or are uncontrolled actual ❑ Yes i No emissions≥6 ton/yr(per storage tank)? Y 1 sCOLORADO n 222 , ��:a�a _ k(s) APE1.1 - �? - _, 12 <"' 2 Ixr° w�.... Permit Number: AIRS ID Number: 123 /0277/075 Section 4 - Storage Tank(s) Information Actual Annual Amount Requested Annual Permit Limits (bbl/year) (bbl/year) Produced Water Throughput: 9,718 13,299 From what year is the actual annual amount? 2019 Tank design: ❑r Fixed roof O Internal floating roof ❑ External floating roof Storage #of Liquid Manifold Storage Total Volume of Installation Date of Most Date of First Tank ID Vessels in Storage Tank Storage Tank Recent Storage Vessel in Production (bbl) Storage Tank(month/year)' (month/year) Sump-1 1 90 02/2008 02/2008 Sump-2 1 90 02/2008 02/2008 Wells Serviced by this Storage Tank or Tank Battery6(E&P Sites Only) API Number Name of Well Newly Reported Well O O O O s Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider future process growth. Requested values are required on all APENs,including APEN updates. 6 The E&P Storage Tank APEN Addendum(Form APCD-212)should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 /-104.4877 0 Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack Discharge Height Above Temp. Flow Rate Velocity ID No. Ground Level(Feet) (°F) (ACFM) (ft/sec) Indicate the direction of the stack outlet: (check one) ❑Upward O Downward ❑Upward with obstructing raincap O Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) O Circular Interior stack diameter(inches): ❑Square/rectangle Interior stack width(inches): Interior stack depth(inches): ❑Other(describe): �ti�(d� el COLORADO dwe.m.aiwwr _, �.� �.. _�_ _.; T� rlflti[S) � ��,_ ' Y�� .�. i c <')�� 3 I exn�n...�...0 Permit Number: AIRS ID Number: 123 /0277/075 Section 6 - Control Device Information ❑✓ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Vapor Size: Make/Model: ❑ Recovery Unit(VRU): Requested Control Efficiency: % VRU Downtime or Bypassed(emissions vented): % Pollutants Controlled: Rating: MMBtu/hr Type: Make/Model: ❑ Combustion Requested Control Efficiency: % Device: Manufacturer Guaranteed Control Efficiency: Minimum Temperature: Waste Gas Heat Content: Btu/scf Constant Pilot Light: ❑ Yes ❑ No Pilot Burner Rating: MMBtu/hr Description of the closed loop system: ❑ Closed Loop System Pollutants Controlled: o Other: Description: Control Efficiency Requested: Section 7- Gas/Liquids Separation Technology Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig Describe the separation process between the well and the storage tanks: COLOR ADO +. -.:c .`:'.f 5 crra2,211,1,.(51 4�D"' r' 1 ) 2, :.? 4 � r, � Permit Number: AIRS ID Number: 123 /0277/075 ;.Cy_fn a -_ Section 8 - Criteria Pollutant Emissions Information Attach alt emissions calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? O Yes ❑r No If yes,describe the control equipment AND state the collection and control efficiencies(report the overall, or combined, values if multiple emission control methods were identified in Section 6): Collection Efficiency Control Efficiency Pollutant Control Equipment Description (%of total emissions captured (%reduction of captured by control equipment) emissions) VOC NO. CO HAPs Other: From what year is the following reported actual annual emissions data? 201 9 Use the following table to report the criteria pollutant emissions from source: Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Pollutant Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Units (AP-42, Emissions Emissions$ Emissions Emissions Basis Mfg.,etc.) (tons/year) (tons/year) (tons/year) (tons/year) VOC 0.240 Ib/bbl FbehL4.1OcmAnalyses 1.27 1.27 1.59 1.59 NO. CO 5 Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider future process growth. Requested values are required on all APENs,including APEN updates. 7 Attach produced water laboratory analysis,stack test results,and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 8 Annual emission fees will be based on actual controlled emissions reported.If source has not yet started operating,provide projected emissions. Section 9 - Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteriaO Yes 0 No pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 lbs/year? If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: Chemical Emission Factor Actual Annual Emissions Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions8 Number Basis Mfg.,etc.) (lbs/year)) (lbs/year) Benzene 71432 0.003 Ibrobl Flash 1.4.21.1km.. 38.53 38.53 Toluene 108883 0.002 LibolonAn** 30.11 30.11 Ethylbenzene 100414 5.1E-05 lb/bbl Ruh L.x.nwnAnalyse 0.68 0.68 Xylene 1330207 4.5E-04 Ib/t Rash Lnn.mnnnu,.. 6.04 6.04 n-Hexane 110543 0.022 !brob! Rasa Liberation Muy.. 294.79 294.79 2,2,4-Trimethylpentane 540841 5.9E-06 lb/bbl Rath LiDmaUonAmino 0.08 0.08 7 Attach produced water laboratory analysis,stack test results,and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. a Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide projected emissions. HAPs in table above reflect PTE values since APEN is requesting site specific emission factors. L. al COLORADO " '' .,,.__.. .1 'f� -.,i')I"��?T 3fi�!,�!�''tii - F' ,J i' c ��' 5 Permit Number: AIRS ID Number: 123 /0277/075 r ,f'C ,to, Section 10- 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 GP05 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. 5/2° ) 207O Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name(print) Title Check the appropriate box to request a copy of the: E✓ 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$191.13 and the General Permit For more information or assistance call: registration fee of$312.50, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 Air Pollution Control Division OR APCD-SS-B1 (303)692-3148 4300 Cherry Creek Drive South Denver,CO 80246-1530 APCD Main Phone Number (303)692-3150 Make check payable to: Colorado Department of Public Health and Environment aft„elC0LIR.AD0 Storage Tan',, i 6 I MOP N Produced Water Storage Tank(s) APE M��K �Y-.v Form APCD-207 ti CDPHE 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. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for tanks that store produced water associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source(e.g. crude oil storage tanks, condensate storage tanks, hydrocarbon liquid loading, 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 and associated addendum forms can be found on the Air Pollution Control Division (APCD) website. 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: g5OPt..1E-t03 AIRS ID Number: 123 /0277 /075 [Lea,: h .l.F.ur,i;s=APCD has already assigned a permit='and A PS ID Section 1 - Administrative Information Company Namei: DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30, T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: (Include Zip Code) 370 17th St., Suite 2500 Denver, CO Contact Person: Roshini Shankaran Phone Number: (303) 605-2039 E-Mail Address2: RSankaran@dcpmidstream.com i Use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. 43196G COLORADO CJ ''. _e1 ) . Io ,nl5jr�r'r;N 2iiiu 1 I ®.MOMi `r,.rmm..l Permit Number: AIRS ID Number: 123 /0277/075 I:, Section 2 - Requested Action ID NEW permit OR newly-reported emission source O Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP05 O GP08 • If General Permit coverage is requested,the General Permit registration fee of$312.50 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit(check each box below that applies) O Change in equipment O Change company name3 ❑ Change permit limit ❑ Transfer of ownership4 O Other(describe below) -OR ▪ APEN submittal for update only(Note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- ▪ APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info Ft Notes: Revising emissions to reflect a site-specific emission factor. Actual emissions below are based on PS-Memo 09-02 emission factors. 3 For company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted. 4 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: Produced Water Storage Company equipment Identification No. (optional): Sump-1 & Sump-2 For existing sources,operation began on: 2/04/2008 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Storage tank(s)located at: El Exploration Et Production(EEtP)site 0 Midstream or Downstream (non EEtP)site Will this equipment be operated in any NAAQS nonattainment area? 0 Yes O No Are Flash Emissions anticipated from these storage tanks? 0 Yes ❑ No Are these storage tanks located at a commercial facility that accepts oil production ❑ Yes r❑ No wastewater for processing? Do these storage tanks contain less than 1%by volume crude oil on an annual average basis? El Yes O No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission(COGCC) Yes No 805 series rules? If so, submit Form APCD-105. ❑ ❑ Are you requesting≥6 ton/yr VOC emissions(per storage tank),or are uncontrolled actual ❑ Yes 0 No emissions≥6 ton/yr(per storage tank)? ICOLONADO Permit Number: AIRS ID Number: 123 /0277/075 Section 4 - Storage Tank(s) Information Actual Annual Amount Requested Annual Permit Limits (bbl/year) (bbl/year) Produced Water Throughput: 9,718 13,299 From what year is the actual annual amount? 2019 Tank design: ❑r Fixed roof O Internal floating roof O External floating roof Storage #of Liquid Manifold Storage Total Volume of Installation Date of Most Date of First Tank ID Vessels in Storage Tank Storage Tank Recent Storage Vessel in Production (bbl) Storage Tank(month/year) (month/year) Sump-1 1 90 02/2008 02/2008 Sump-2 1 90 02/2008 02/2008 Wells Serviced by this Storage Tank or Tank Battery6(E&P Sites Only) API Number Name of Welt Newly Reported Welt O O O - ❑ O s Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider future process growth. Requested values are required on all APENs,including APEN updates. 6 The EEP Storage Tank APEN Addendum(Form APCD-212)should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191/-104.4877 0 Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack Discharge Height Above Temp. Flow Rate Velocity ID No. Ground Level(Feet) (°F) (ACFM) (ft/sec) Indicate the direction of the stack outlet: (check one) ❑Upward ❑Downward ❑Upward with obstructing raincap ❑Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) ❑Circular Interior stack diameter(inches): ❑Square/rectangle Interior stack width(inches): Interior stack depth(inches): ❑Other(describe): 3 1 COLORADO St3rage Talk!S} ri�� Re--s,:,�, 12 2D1" °.r.a.wrwar Permit Number: AIRS ID Number: 123 /0277/075 �Crra=ar_ �� iii',. Section 6 - Control Device Information ❑✓ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Vapor Size: Make/Model: ❑ Recovery Unit(VRU): Requested Control Efficiency: VRU Downtime or Bypassed(emissions vented): % Pollutants Controlled: Rating: MMBtu/hr Type: Make/Model: ❑ Combustion Requested Control Efficiency: Device: Manufacturer Guaranteed Control Efficiency: % Minimum Temperature: Waste Gas Heat Content: Btu/scf Constant Pilot Light: ❑ Yes O No Pilot Burner Rating: MMBtu/hr Description of the closed loop system: ❑ Closed Loop System Pollutants Controlled: ❑ Other: Description: Control Efficiency Requested: Section 7- Gas/Liquids Separation Technology Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig Describe the separation process between the well and the storage tanks: ®ICOIORADO '.,Ps .. �� to;-S1(0 Ta"tia LiSi O� 4 x irw.�ive `.w Permit Number: AIRS ID Number: 123 /0277/075 Section 8 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑Yes EJ No If yes, describe the control equipment AND state the collection and control efficiencies (report the overall, or combined, values if multiple emission control methods were identified in Section 6): Collection Efficiency Control Efficiency Pollutant Control Equipment Description (%of total emissions captured (%reduction of captured by control equipment) emissions) VOC NOx CO HAPs Other: From what year is the following reported actual annual emissions data? 201 9 Use the following table to report the criteria pollutant emissions from source: Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Pollutant Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Units (AP-42, Emissions Emissions8 Emissions Emissions Basis Mfg.,etc.) (tons/year) (tons/year) (tons/year) (tons/year) EJC per VOC 6:24010.28 Iblbbl na.hub.meonAruinia 1.27 1.27 1.5911.85 1 85911.85 I email rec'd NOx CO 11/18/2020 co 5 Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider future process growth. Requested values are required on all APENs,including APEN updates. 7 Attach produced water laboratory analysis,stack test results,and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 8 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide projected emissions. Section 9 - Non-Criteria Pollutant Emissions Information 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, use the following table to report the non-criteria pollutant (HAP)emissions from source: Chemical Emission Factor Actual Annual Emissions Chemical Name Abstract Uncontrolled Source Uncontrolled Controlled Service(CAS) Units (AP-42, Emissions Emissions8 Basis (lbs/year)) (lbs/year) Number Mfg.,etc.) Ibs/ ear Benzene 71432 0003 3.4E-3 lb/bbl Flash Laws..Mats. 36:53 44.79 38.53 44.79 Toluene 108883 0-002 26E-3 lb/1)bl FI.an Liberation MWya. 30.-51 35.01 301-4 3501 Ethylbenzene 100414 5.1E-os 59E-5 ro/bbI flash Lax..,AiW/w 0.68 0 9 0:68 079 Xylene 1330207 4.5E 04 5 3E-4 lb/bbl Flash lah«.nonAnal,4. 804 702 6,04 7 02 n-Hexane 110543 "221-6 026 1 IbrobI n.w.r+mnMalys. 29429 342 68' 294;79 342.68 2,2,4-Trimethylpentane 540841 5.9E-0Gl6.8E-61 ID/bbl Flash ubaononMen. 0:08 0' 09 309 0.09 T Attach produced water laboratory analysis,stack test results,and associated emissions calculations if you are requesting site EJC per specific emissions factors according to the guidance in PS Memo 14-03. email rec'd t Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide 11/18/2020 projected emissions. HAPs in table above reflect PTE values since APEN is requesting site specific emission factors. (COLORADO rr_ ,?'H.= ZcJ7 I c d6'Cod VI-3 t "` �f a't�c'T 11 i..#5) hh t`₹ - ill i 2;., 5 l se „mtianwwa Permit Number: AIRS ID Number: 123 /0277/075 Section 10- 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 GP05 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. .5/21 /2070 Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Environmental Engineer Name(print) Title Check the appropriate box to request a copy of the: Ei Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type,etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with$191.13 and the General Permit For more information or assistance call: registration fee of$312.50, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 Air Pollution Control Division OR APCD-SS-B1 (303)692-3148 4300 Cherry Creek Drive South Denver,CO 80246-1530 APCD Main Phone Number (303)692-3150 Make check payable to: Colorado Department of Public Health and Environment �ICOtORA00 cs ,- r f--, -.ta, St(,-age air.'; � 1� 6 vay.�= 11/18/2020 State.co.us Executive Branch Mail-APEN Redline for Enterprise PW Tanks STATE OF ', ' = COLORADO Chavez-CDPHE, Elie<elie.chavez@state.co.us> APEN Redline for Enterprise PW Tanks Shankaran, Roshini <RShankaran@dcpmidstream.com> Wed, Nov 18, 2020 at 3:19 PM To: "Chavez-CDPHE, Elie"<elie.chavez@state.co.us> Hi Elie, This APEN redline looks good and we have no further comments. I think there is one other email somewhere out there on Enterprise that I'm hunting down with responses for you. 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 ci p Midstream. From: Chavez-CDPHE, Elie <elie.chavez@state.co.us> Sent: Tuesday, November 17, 2020 4:11 PM To: Shankaran, Roshini <RShankaran@dcpmidstream.com> Subject: [EXTERNAL]Fwd: APEN Redline for Enterprise PW Tanks *** WARNING: This email originated from outside of DCP Midstream. Do not click links or open attachments unless you recognize the sender and know the content is safe. Safety and security starts with each of us, *** https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1683738294519433886&simpl=msg-f%3A16837382945... 1/2 11/18/2020 State.co.us Executive Branch Mail-APEN Redline for Enterprise PW Tanks [Quoted text hidden] https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1683738294519433886&simpl=msg-f%3A16837382945... 2/2 INFO TO SUPPORT 6/1/2020 Modification *Note that the information presented in this modification application was subsequently modified with the 9/11/2020 operator comments on the draft permit to add a 30% safety factor to flash emissions. See "operator correspondence" and redlined APEN. CCOLORADO 1�W P De He of Public � � Health&Environment June 30, 2020 Roshini Shankaran Senior Environmental Engineer DCP Operating Company, LP 370 17th Street, Suite 2500 Denver, CO 80202 REF: DCP Operating Company, LP - Enterprise Compressor Station, OP #95OPWE103, FID# 123-0277 SUBJECT: Administrative Completeness Determination for Significant Modification Dear Ms. Shankaran: The application for the revision to the operating permit for the Enterprise Compressor Station (received June 1, 2020) to permit the previously exempt Produced Water Storage Tank point (AIRS 075) has been determined to constitute a significant modification as defined in Regulation No. 3, Part C, Section I.A.7. As stated in that section, significant modifications will be processed using the procedures set forth in Part C of Regulation No. 3, for combined Construction/Operating Permit issuance. Regulation No. 3, Part C, Section III.B.7 requires that facilities submit an application for a combined construction permit and operating permit on a standard application form supplied by the Division. Since the Division currently has no forms for this procedure, your June 1, 2020 letter and attachments (APEN, flow diagram and emission calculation methodology) fulfill this requirement. Fees Colorado Regulation No. 3, Part A Section VI.A.1 requires the division to charge fees to "...recover the direct and indirect costs incurred by the Division in processing permit applications, issuing permits, and in conducting a compliance monitoring and enforcement program. Such fees shall apply without regards to whether a permit is issued, denied, withdrawn, or revoked." With respect to processing applications and issuing permits, fees will be charged for time spent reviewing the application and drafting the permit and associated basis document, including researching regulatory and technical issues related to the application and permit draft as applicable. Chargeable time also includes peer and supervisor review of drafts, as well as time spent by permit engineers and division management in meetings, phone calls, and responding to emaits. The Legislature has set a fee cap of $95.56 per hour for these activities. Please note the statutory fee cap will automatically increase by the rate of inflation annually, and the hourly fee will be set at or below the statutory cap by the Air Quality Control Commission. Qk rc 4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe �7/ s'-'-. .t.\' Jared Polls, Governor I Jill Hunsaker Ryan,MPH, Executive Director ,, ,! Please note that the Division utilizes a quarterly billing system for all operating permits. The bills you receive will reflect chargeable time for the previous quarter. Timeline Significant modifications are processed under the same time lines and procedures as new operating permits, including Public Comment and EPA review. Within sixty (60) days of receiving an application for a significant modification the Division must determine if the application is administratively complete. Under the provisions of Regulation No. 3, Part C, Section IV.C, the Division has 18 months from the receipt of a complete application in order to approve or disapprove the application. The 18 month clock starts on the date a complete application is submitted. Please note that you cannot institute the proposed modifications to your facility until the revised operating permit has been issued. Required Additional Information The Division has determined that the June 1, 2020 application is administratively complete. If during the technical review of your application, the Division determines that additional information is necessary to evaluate or take final action on this application, a request will be made in writing for the information and a reasonable deadline for response set. If you fail to provide the requested information or do not meet the deadline, the Division will be unable to continue with the processing and issuance of the modified permit (Regulation No. 3, Part C, Section IV.D). Please do not hesitate to contact me if you have any questions at 303-692-6332 or elie.chavez@state.co.us. Sincerely, cat) Elie Chavez, P.E. Engineer, Operating Permit Unit Stationary Sources Program Air Pollution Control Division 11/23/2020 State.co.us Executive Branch Mail-PW Tank Sig Mod Completeness Letter for Enterprise I STATE OF Chavez-CDPHE, Elie<elie.chavez@state.co.us> V) COLORADO PW Tank Sig Mod Completeness Letter for Enterprise 1 message Chavez-CDPHE, Elie<elie.chavez@state.co.us> Tue, Jun 30, 2020 at 8:09 AM To: "Shankaran, Roshini"<RShankaran@dcpmidstream.com> Hi Roshini, Please find attached the completeness letter for the application to permit the Enterprise produced water storage tanks (AIRS 075). Again,these changes have already been incorporated into the draft permit you have for Enterprise; I just needed to wait for the application to make it through our internal processes in order to get you the letter. Thanks so much! Elie Chavez Permit Engineer Title V Operating Permit Unit Stationary Sources Program Air Pollution Control Division COLORADO Air Pollution Control Division C ittal Department of Public Health fr Environment P 303 692 6332 4300 Cherry Creek Drive South, Denver, CO 80246-1530 ellechavez@state.co.us I www.colorado.gov/cdphe/aped Are you curious about ground-level ozone in Colorado?Visit our ozone webpage to learn more. ® 123-0277 Sig Mod Completeness Letter 6-30-20.pdf 66K https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permthid=thread-a%3Ar7773216784737229145&simpl=msg-a%3Ar777486926... 1/1 Company Name: DCP Operating Company,LP Facility Name: Enterprise Produced Water Tank Emission Factor using Flash Liberation Sample and AP-42 VOC and HAPs emission factors Flash Emission Factors(Flash Liberation Sample) RCVD 9/11/2020 (via email) Flash Gas Properties 95O P WE 103 Gas to Water Ratio 4.1 scf/bbl 123-0277-075 7.30E-04 m3/L(for APENZ Molecular Weight 33.6 Ib/Ib-mol EJ C VOC 35.74% wt% n-Hexane 3.30% wt% 9/12/2020 Benzene 0.43% wt% Toluene 0.34% wt% Ethylbenzene 0.01% wt% _ Xylene 0.07% wt% 2,2,4-Trimethylpentane 0.00% wt% Emission Factor Calculation Methodoloav Compound emission factor(lb/bbl)=Flash GWR(scf/bbl)x MW of flash gas(Ib/Ib-mol)x[1/379.41 (scf/lb-mol)]x wt%of compound in flash gas(wt%) Emission Factors VOC 0.13 lb/bbl n-Hexane 0.01 lb/bbl Benzene 1.57E-03 lb/bbl Toluene 1.23E-03 lb/bbl Ethylbenzene 2.76E-05 lb/bbl Xylene 2.46E-04 lb/bbl 2,2,4-Trimethylpentane 3.18E-06 lb/bbl Working and Breathing Emission Factors(AP-42) Compound wt%of TOC Working Losses* Breathing Losses* Total W&B Losses Production W&B Emission [Ib/yr] [lb/yr] [lb/yr] (bbls/year) Factor(lb/bbl) TOC 1,992.66 739.14 2,731.80 VOC 53.51% 1,066.19 395.48 1,461.67 0.11 n-Hexane 4.95% 98.58 36.57 . 135.15 0.01 Benzene 0.65% 12.89 4.78 17.67 1.33E-03 Toluene 0.51% 10.07 3.74 13.81 13,299 1.04E-03 Ethylbenzene 0.01% 0.23 0.08 0.31 2.34E-05 Xylene 0.10% 2.02 0.75 2.77 2.08E-04 2,2,4-Trimethylpentane 0.00% 0.03 0.01 0.04 2.69E-06 Note:Gas composition for working and breathing losses based on gas composition from flash liberation sample 'From AP-42 Breathing&Working Calculations Tank emission factors(AP-42+Flash Liberation Sample) Compound Flash EF* W&B EF Combined EF (lb/bbl) (lb/bbl) (lb/bbl) VOC 0.17 0.11 0.28 n-Hexane 0.02 0.01 0.03 Benzene 2.04E-03 1.33E-03 3.37E-03 Toluene 1.59E-03 1.04E-03 2.63E-03 Ethylbenzene 3.59E-05 2.34E-05 5.93E-05 Xylene 3.20E-04 2.08E-04 5.28E-04 2,2,4-Trimethylpentane 4.13E-06 2.69E-06 6.82E-06 DCP is including a 30%buffer on the calculated VOC and HAP Flash emission factors to account for annual variations in liquid composition. Company Name: DCP Operating Company,LP Facility Name: Enterprise Produced Water Storage Tank Emissions Calculations VOC and HAPs PTE Emissions Control Description: None Production for PTE Calculations: 13 299 Control Efficiency: 0% Annualized production based on average daily production Site-specific emission factors based on a flash emissions analysis have been used to calculate emissions. Listed below are the appropriate emission factors. Site Specific Emission Factors have been used to caculate Emissions based on Tanks 4.0.9 and Flash analysis EF(lb/bbl) VOC Benzene n-Hexane Toluene , EBenzene Xylene 2,2,4-TMP Site Specific 0.279 0.003 0.026 0.003 5.929E-05 5.278E-04 6.818E-06 PTE Calculations: Uncontrolled Emissions VOC Benzene n-Hexane Toluene EBenzene Xylene 2,2,4-TMP Flash Gas (ton/yr) (lb/yr) (Ib/yr) (lb/yr) (Ib/yr) (Ib/yr) _(Ib/yrL__ (MMBtu/yr) 1.85 44.79 342.68 35.01 0.79 7.02 0.09 154 PTE tpy=> 0.02 0.17 0.02 0.00 0.00 0.00 33.64 Gas MW* 0.357 Fraction VOC by Weight' Controlled Emissions 1,319.95 Gross Heating Value*(btu/scf) VOC Benzene n-Hexane Toluene EBenzene Xylene 2,2,4-TMP *From Flash Analysis (ton/yr) (lb/yr) (Ib/yr) (Ib/yr) (Ib/yr) (lb/yr) (lb/yr) 1.85 44.79 342.68 35.01 0.79 7.02 0.09 tpy=> 0.02 0.17 0.02 0.00 0.00 0.00 Example Calculations: Omani-fa1/tr/Errrusiwxi —�7h Animal = 16 1 Animal ZhnnanoJl nilTloouglrrt — Einisstvn Fantail /6 ( tr J �.bbl L. bh1 lb i Cannot/eel E unar ns — =Animal Cannoned Tin anti!h£u(-- -Em s,an Faetw {1-Cann o 1 Effcrenc i.) a , VI 1111 bbl, 16 ' +Annual U,cono-oiled Tin auahpnl bbl I.£ruts:;ton Factor' , ,bbl; VOC Emissions,t o,ts�)=Ennss,onsl lb) ( I ron 'i yr t I.Jr/ ,2.000/b) LLAMBtrr I,. n"C B Gas }r I �tot, 12,000M 1 t (3"9-I IS(F Gay I { Btu- f 111hffita t.ncont,vl/'d VO( - — --- HntCanur� i I s� , to s i Cas MWI lb ,ol VUC°a j ,0(1�� )10`Bnt s 8/24/2020 Modification Application DCP Midstream I:IA=1P 370 17th Street,Suite 2500 Denver,CO 80202 Midstream. 303-605-2029 August 21, 2020 Sent via UPS Tracking#: 1Z F46 915 01 9988 0918 Mrs. Elie Chavez Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-BI Denver, CO 80246-1530 Re: DCP Operating Company, LP; Enterprise Compressor Station (123/0277) Title V Permit 9SOPWE103 Significant Modification - Construction Permit (19WE0094) Incorporation Application Mrs. Chavez: DCP Operating Company, LP (DCP) is submitting the attached application for the Enterprise Compressor Station, located in SWSW Section 30, Township 3N, Range 63W, Weld County, Colorado. DCP is requesting that Construction Permit 19WE0094 be incorporated into the active Title V Permit covering this facility, 95OPWE103. Construction Permit 19WE0094 was issued July 17, 2019. Per the requirements detailed in Colorado Regulation 3, Part C, Section III.B.2., an application to incorporate construction permit requirements into an active Title V permit are due within 12 months of issuance of the construction permit. Please note that a draft Title V renewal permit incorporating the requirements included in construction permit 19WE0094 has already been developed by the Division and is currently with DCP for review. The enclosed application serves to satisfy the above Regulation 3 requirement to officially request this incorporation. This application indicates two instances of permit non-compliance at this facility: • As the included Form OP-400 details, the Reciprocating Compressor Blowdowns (AIRS 076) at this facility are currently out of compliance with Construction Permit 19WE0094. Details regarding the non-compliance, as well as a schedule for correcting the identified issues, have been included on Form OP-400. • As indicated on the most recent Title V semi-annual certification submitted for this facility, non-compliance has been identified for the stabilized condensate truck loadout rack (AIRS 066). The facility will achieve compliance as soon as practicable. The application includes the following attachments: A. Most Recent APEN Submittal —AIRS 076, Compressor Blowdowns(12.20.2018) B. Title V Operating Permit Application Form —OP-SO C. Title V Operating Permit Application Form —OP-314 Separator and Natural Gas Venting D. Title V Operating Permit Application Form —OP-400 Compliance and Monitoring If you have any questions or require any additional information about this application, please feel free to contact me at (303) 605-2039 or rshankaran@dcpmidstream.com. Sincerely, DCP Operating Company, LP r� 1 Roshini Shankaran Senior Environmental Engineer Enclosures Attachment A Previous APEN—AIRS 076(COMP-BD) Enterprise Compressor Station CDPHE Gas Venting APEN - Form APCD-211 Ark CO r;,, 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 gas venting only. Gas venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source(e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, 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: AIRS ID Number: 123 /0277 / [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 1 - Administrative Information Company Name1: DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30, T3N, R63W Weld County: NAICS or SIC Code: 4922 Mailing Address: 370 17th Street, Suite 2500 (Include Zip Code) Denver, CO 80202 Contact Person: 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 the APCD via e-mail to the address provided. COLORADO Form APCD-211 - Gas Venting APEN - Revision 7/2018 1 °�"- Permit Number: AIRS ID Number: 123 /0277/ [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 2 - Requested Action ❑✓ NEW permit OR newly-reported emission source -OR- ❑ MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 0 Add point to existing permit ❑ Change permit limit 0 Transfer of ownership' ❑ Other(describe below) -OR • APEN submittal for update only(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 company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted. 4 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: Compressor Engine Blowdowns for maintenance and repair Company equipment Identification No. (optional): COMP-BD For existing sources, operation began on: 1 994 For new, modified, or reconstructed sources, the projected start-up date is: El Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source hours/day days/week weeks/year Operation: Will this equipment be operated in any NAAQS ❑✓ Yes ❑ No nonattainment area? Is this equipment located at a stationary source that is considered a Major Source of(HAP) Emissions? ❑✓ Yes El No Is this equipment subject to Colorado Regulation No. 7, ❑ Yes ❑✓ No Section XVII.G? COLORADO Form APCD-211 Gas Venting APEN - Revision 7/2018 2 I GV Permit Number: AIRS ID Number: 123 /0277 / [Leave blank unless APCD has already assigned a permit«and AIRS ID] Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing O Pneumatic Pump Make: Model: Serial#: Capacity: gal/min ❑ Compressor Rod Packing Make: Model: #of Pistons: Leak Rate: Scf/hr/pist ❑✓ Blowdown Events #of Events/year: 380 Volume per event: See Below* MMscf/event O Other Description: If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? O Yes ❑✓ No Vent Gas Gas Venting Heating Value: 1289.5 BTU/SCF Process Parameters5: Requested: 1.80 MMSCF/year Actual: 1.14 MMSCF/year -OR- Liquid Throughput Requested: bbl/year Actual: bbl/year Process Parameters5: Molecular Weight: 22.3 * Compressor Blowdown VOC (Weight%) 26.18 Volumes: Benzene(Weight%) 0.07 C-238 = 3.96E-03 MMscf/event Vented Gas Toluene(Weight%) 0.08 C-235 = 3.96E-03 MMscf/event Properties: Ethylbenzene (Weight%) 2.38E-03 C-236 = 3.96E-03 MMscf/event C-234 = 3.96E-03 MMMMscf/event Xylene (Weight%) 0.04 C-237 = 7.79E-03 MMscf/event n-Hexane (Weight%) 0.48 2,2,4-Trimethylpentane (Weight%) 5.12E-04 Additional Required Information: ❑✓ Attach a representative gas analysis (including BTEX Et n-Hexane, temperature, and pressure) ❑ Attach a representative pressurized extended liquids analysis (including BTEX l* n-Hexane, temperature, and pressure) 5 Requested values wilt become permit limitations. Requested limit(s)should consider future process growth. A ;COLORADO Form APCD-211 - Gas Venting APEN - Revision 7/2018 3 1 Nca.l...F_r•v.r.flnerl Permit Number: AIRS ID Number: 123 /0277 / [Leave blank unless APCD has already ass gned a permit#and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 /-104.4877 Discharge Height operator Temp. Flow;Rate;:- Velocity Above Ground Level Stack ID No , ('F) (ACFM) (ftisec) �, ENG-BD Indicate the direction of the stack outlet: (check one) O Upward ❑Downward ❑Upward with obstructing raincap O Horizontal El Other(describe): Fugitive Source Indicate the stack opening and size: (check one) ❑Circular Interior stack diameter(inches): El Other(describe): Fugitive Source Section 6 - Control Device Information 0 Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Size: Make/Model: ❑ VRU: Requested Control Efficiency: VRU Downtime or Bypassed: % Pollutants Controlled: Rating: MMBtu/hr Type: Make/Model: Combustion ❑ Requested Control Efficiency: % Device: Manufacturer Guaranteed Control Efficiency: % Minimum Temperature: Waste Gas Heat Content: Btu/scf Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating: MMBtu/hr Pollutants Controlled: ❑ Other: Description: Requested Control Efficiency: 0 Form APCD-211 - Gas Venting APEN - Revision 7,2018 4 I t► °„ E .` ;,, Permit Number: AIRS ID Number: 123 /0277 / [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 7 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined)control efficiency(%reduction): Overall Requested Pollutant Description of Control Method(s) Control Efficiency (%reduction in emissions) PM SO. NO. CO VOC HAPs Other: From what year is the following reported actual annual emissions data? 2017 Criteria Pollutant Emissions Inventory Requested Annual Permit Emission Factor Actual Annual Emissions ' Emission Limit(s)5 Pollutant Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis Units (AP-42, Emissions Emissions° Emissions Emissions Mfg.,etc.) (tons/year) (tons/year) (tons/year) (tons/year) PM SOx NOx CO VOC 11,001.01 Ib/MMscf Eng. Est. 6.29 6.29 9.88 9.88 Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) Uncontrolled Basis Units (AP-42, Emissions Emissions6 Number Mfg.,etc.) (pounds/year) (pounds/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n-Hexane 110543 214.08 Ib/MMscf Eng. Est. 384.39 384.39 2,2,4- Trimethylpentane 540841 Other: 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. COLORADO Form APCD-211 - Gas Venting APEN - Revision 7/2018 5 � Permit Number: AIRS ID Number: 123 /0277/ (Leave _;na.r APCD r3 :a porrn€ and Af S ID Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. tat ZOIZO ifs 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: Ej Draft permit prior to issuance El Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five year term, or when a reportable change is made(significant emissions increase, increase production, new equipment,change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692-3175 or(303)692-3148 APCD-SS-B 1 4300 Cherry Creek Drive South APCD Main Phone Number Denver, CO 80246-1530 (303)692-3150 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https://www.colorado.govicdphe/apcd Fr CD (('' ii 4 IAy COLORADO Form�S [(J-211 Gas �I Yy inlna isl'l...t_I . .x.., -.�y}1w 6 Fz.uA4C .+.rnri Attachment B Title V Operating Permit Form—OP-50 Enterprise Compressor Station . COLORADO Form OP-50 Air Pollution Control Division ':t'Putac`-4e aitt.;u trwormmz Title V Operating Permit Application Form This form must be included with any application submittal to the Title V Operating Permit Unit Title V Operating 950PWE103 Plant AIRS ID 123 - 0277 Permit Number: Number: 1. Instructions Included on the Colorado Air Pollution Control Division Website is an instruction sheet (Form OP-50A) for this application form. Refer to the instruction sheet or contact the Division with questions. Attach a cover letter describing the purpose of the application package if more room is needed. Any form with missing information may be determined administratively incomplete and may result in inability to grant the application shield of Regulation No. 3, Part C, Section II.B. Note that if using copy and paste; the applicant must paste as plain text. See "General Instructions" document for more details. 2. Permit Application Type (check all that apply) ❑ Initial ❑ Renewal - Identify any requested changes below or in a cover letter. Significant Modification ❑ Administrative Modification (e.g. transfer of ownership, correct typographical error, etc.) Minor Modification - The Minor Modification worksheet (Form OP-201) must also be completed if a ❑ source wishes to use the procedures under Colorado Regulation No. 3, Part C, Section X. ❑ Notification of Construction Permit Exempt ❑ Title V Billing Contact Update Unit (APCD PS Memo 09-01, Scenario#7) ❑ ❑ Supplemental Information (describe): Responsible Official Update �r _:. ❑ Other (describe): . 3. General Description - Include brief description describing the purpose of the application package. If more detail is needed, provide in cover letter. General This application is being submitted to officially request the incorporation of individual Description construction permit 19WE0094 into the active Title V Operating Permit for this facility of package (95OPWE103) Form Revised March 2020 Page 11 of 3 ," ; COLOR A DO Heparkmentat PuW� +. -Health Fr Envfronmene COLORADO Form OP-50 Air Pollution Control Division caws+ Put jc Heilrr. r iannrm'.rA.-os 4. Additional Information A. Initial and Renewal Applications ❑ Check this box if you are submitting an initial or renewal application. For all other application types, proceed to Section 4.B. If you are submitting an initial or renewal application, provide the application due date. See Colorado PS- Memo 09-01 for help with Title V Operating Permit application due dates. Application Due Date: _._ . Basis for Application Due Date (Initial Permits Only): -]: r t vnr r B. APEN Attachments Enclose a copy of the most current complete Air Pollution Emission Notice(s) (APENs) on file with the Division. New/revised APENs are required if the facility is requesting a modification that requires a new APEN or changes information on a previously submitted APEN. ❑ New or Revised APENs have been included with this submittal (filing fees must be included) Z Required - Copies of all applicable APENs have been included (no filing fees are needed for these APEN copies). C. Confidential/Trade Secret Information Check the following box if any confidential/trade secret information has been submitted with this application. The pages including confidential information must clearly be labeled as confidential. See PS Memo 98-01 for acceptable confidential information submittals. ❑ This application includes confidential information on the following pages: _ crLEvr D. Submittal The Division is requiring one hardcopy submittal mailed to the APCD (with any wet signatures required; see instruction documents for details) and one electronic copy submittal emailed to APCD. The electronic submittal MUST be submitted in word format (either .doc or .docx) to cdphe apcd title V®state.co.us. For legal purposes, the date the signed hardcopy is received by the Division is considered the date received, not when the electronic copy is emailed. E. Oil and Gas Sources If this facility is associated with Oil & Gas activities, Form OP-202 must be completed if the facility is submitting an initial application or the facility is requesting changes to oil and gas equipment and must be submitted for the application to be considered complete. Oil and Gas SIC codes include, but are not limited to, 1311, 1321, and 4922. ❑ Form OP-202 has been included with this application. ❑x This facility is not an oil and gas facility, and/or the facility is not requesting any changes to the oil and gas equipment. F. Modeling If an emission unit will have to go through modeling as part of a permit action, OP-204 must be completed and attached to the corresponding OP-300 series form. If the applicant has already filled out the optional air quality modeling form as part of the modeling process, the applicant may attach that form in lieu of OP-204. For information about the modeling process, see the page titled "Air Quality Modeling Guidance for Permits" on the Division webpage. • Form OP-204 has been completed and attached. • A copy of the optional air quality modeling form has been attached. LI This facility did not trigger modeling requirements. Form Revised March 2020 Page I 2 of 3 e _ COLORADO Department of Pu 4t -- +`Health b Environment „r ! COLORADO Form OP-50 Air Pollution Control Division 5. Signature of Responsible Official A. Statement of Completeness N I have reviewed this application in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this application are true, accurate and complete. B. Certification of Facility Compliance Status With Federal and State Enforceable Conditions I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements, including compliance certification requirements and any applicable compliance assurance monitoring. Ny I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements, except for the following emissions unit(s)identified below: P016-Stabilized Condensate Atmospheric Truck Loadout Rack (AIRS 066) COMP-BD- Reciprocating Compressor Blowdowns (AIRS 076) C. Certification of Facility Compliance Status With State-Only Enforceable Conditions Li I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. I certify that the facility described in this airpollution permit application is fully in compliance with all applicable requirements, except for the following emissions unit(s)identified below: P016- Stabilized Condensate Atmospheric Truck Loadout Rack (AIRS 066) COMP-BD - Reciprocating Compressor Blowdowns (AIRS 076) WARNING: Any person who knowingly, as defined in S 18-1-501(6), C.R.S., makes any false material statement, representation, or certification in, or omits material information from this application is guilty of a misdemeanor and may be punished in accordance with the provisions of S 25-7 122.1, C.R.S. Responsible Official Charles A. Job Name or Other' Title General Manager, North Area Operations Signature2 Date 8/21/2020 'For the following applications, a signature of a Legally Authorized Person (not a vendor or consultant) is acceptable: Notification of Construction Permit Exempt Unit, Billing contact update, Responsible Official update, and Supplemental Information submittal. For these application types, a Legally Authorized Person must only certify with Section 5.A (5.B and 5.C certifications are not needed). 2This document requires a "wet signature," electronic signatures will not be accepted. SEND MATERIALS TO: Colorado Dept. of Public Health a Environment APCD-SS-B1 ATTN: Title V Unit Supervisor 4300 Cherry Creek Drive South Denver, CO 80246-1530 cdphe_apcd_titte_V@state.co.us Form Revised March 2020 Page 13 of 3 • . COLORADO D.p nment of Public health b pnvnonmeM Attachment C Title V Operating Permit Form—OP-314 Separator and Natural Gas Venting Enterprise Compressor Station ' COLORADO Form OP-314 Air Pollution Control Division 3g i twmaro-se-r. of Ptittx l i ltt;k triancr.^rara nt Separator and Natural Gas Venting Title V Operating 95OPWE103 AIRS ID Number: 123 - 0277 - 076 Permit Number: 1. Instructions Included on the Colorado Air Pollution Control Division Website is an instruction sheet (Form OP-314A) for this separator and natural gas venting form. Refer to the instruction sheet or contact the Division with questions. Any form with missing information may be determined administratively incomplete and may result in inability to grant the application shield of Regulation No. 3, Part C, Section ILB. Renewal and modification applications for equipment already included in the Title V permit are allowed to only complete portions of the form affected by the modification. Note that if using copy and paste; the applicant must paste as plain text. See "General Instructions" document for more details. 2. Vented Equipment Information Facility Identifier COMB-BD (example: 5001) ' Date commenced construction: 1994 Dates Date last modified/reconstructed: N/A Date of first operation: 1994 ❑ Separator ❑ Wellhead Casing Pneumatic Pump Vented Equipment Compressor Rod Packing LI Blowdown Events Other (describe): Click here to enter brief description. ❑ Vapor Recovery Unit (VRU): Click here to enter destination. , ❑ Routed Directly to Process: click here to enter destination. Emissions Routing ❑ Combustion Device 'I Atmosphere Other (describe): Click sere to enter text . General Description Natural gas venting from reciprocating compressor blowdowns of Equipment Underlying LI Yes ❑ No Construction Permit Permit Number: 19WE0094 Exemptions List any state exemptions that apply to this separator (See Instruction Sheet for more information): Click here to enter text. 3. Separator Venting Information , E' Check this box if this form does not address venting from a separator and leave this section blank Separator Type ❑ Low Pressure Separator: Click here to enter quantity. (check all that apply) ❑ High Pressure Separator: Click here to enter quantity. Form Revised March 2020 Page 1 1 of 6 COLOR A DO AIRS ID: 123-0277-076 Department ofP"°ti` Health 6 Environment COLORADO Form OP-314 Air Pollution Control Division v?m It r.:4.i Put t'}Gilt? ,Enorormlent ❑ Vapor Recovery Tower (VRT): Click here to enter quantity. ❑ Other (describe): Click here to enter text and quantity. • Low Pressure Separator: Click here to enter optional facility identifier. ❑ Vapor Recovery Tower: Click here to enter optional facility Exiting Liquids Routing ident itier. ❑ Atmospheric Storage Vessel(s): Click here to enter optional facility identifi Pr. ❑ Other (describe): Click here to enter text. ❑ Two-Phase Separator Separator Design ❑ Three-Phase Separator ❑ Other (describe): Clio here to enter text. Inlet Pressure(s) (psig): Click to list pressure of each separator. Design Information Outlet Pressure(s) (psig): Click to list pressure of each separator. Is this separator heated? ❑ Yes ❑ No ❑ Gas Vented Throughput Limitation (provide units): click to enter Permit Throughput throughput. Limitation ❑ Liquids Throughput Limitation (provide units): Click to enter throughput. Monitoring Method: Click here to describe throughput monitoring Throughput Monitoring method. If metered, enter meter location: Click here to enter meter location. 4. Wellhead Casing Venting Information E Check this box if this form does not address venting from wellhead casing and leave this section blank Upstream Pressure (psig): Click to enter pressure. Design Information Downstream Pressure (psig): Click to enter pressure. Permit Throughput Click to enter throughput. Limitation Monitoring Method: Click here to describe throughput monitoring Throughput Monitoring r"t=t-h=od• • If metered, enter meter location: Click_ here to enter meter location. 5. Pneumatic Pump Venting Information Check this box if this form does not address venting from pneumatic pump(s) and Leave this section blank , Upstream Pressure: Click to enter pressure. Design Information Downstream Pressure: Click to enter pressure. Number of Pumps: Click to enter number of pumps. Permit Throughput Click to enter throughput. Limitation Monitoring Method: Click here to describe throughput monitoring Throughput Monitoring method• If metered, enter meter location: Click here to enter meter location. Form Revised March 2020 Page I2 of 6 CO t.O R A D O AIRS ID: 123-0277-076 llhb D° bEntv'r e 'NeaEnvmnment • . COLORADO Form OP-314 Air Pollution Control Division ccwat " $w vn', t:t i4b4:Ht4ltr,& 'nvtryr.nueri. 6. Compressor Rod Packing Venting Information © Check this box if this form does not address venting from compressor rod packing and leave this section blank Facility Identifier of Compressor(s): Click here to enter compressor identifiers or compressor quantity. Design Information Number of Pistons per Compressor: Click here .to enter compressor pistons. Permit Throughput Click to enter throughput. Limitation Monitoring Method: Click here to describe throughput monitoring Throughput Monitoring method. If metered, enter meter location: click here to enter meter location. i 7. Blowdown Event Venting Information , ❑ Check this box if this form does not address venting from blowdown event(s) and leave this section blank Equipment Vented: C-238, C-235, C-236, C-234, C-237 Design Information Reason for Venting: Maintenance and Repair Annual Venting Events (events/year): 76 Events / Compressor Unit Permit Throughput 76 Events / Compressor Unit Limitation Monitoring Method: #of Blowdown events recorded in onsite log Throughput Monitoring If metered, enter meter location: N/A 8. "Other" Venting Information ❑x Check this box if the venting addressed by this form is covered by any of the preceding equipment-specific sections above and leave this section blank Equipment Vented: Click to enter. equipment. Design Information Reason for Venting: Click to enter text. Annual Venting Events (events/year): Click to enter number of events. Permit Throughput _y . to enter Limitation clickthroughput. Monitoring Method: Click here to describe throughput monitoring Throughput Monitoring w-ethod. If metered, enter meter location: click here to enter meter location. - r 9. State and Federal Regulations Rule Applicability How will you comply with this Regulation? 40 CFR Part 60 Subpart ❑ Subject Click enter text. OOOO l 1-_ Z Not Subject 40 CFR Part 60 Subpart ❑ Subject Click here to enter text. 0000a x Not Subject I Form Revised March 2020 Page I 3 of 6 COLORADO AIRS ID: 123-0277-076 °ep"R"1e"eotP bu. Health b Enu;tonenf COLORADO Form OP-314 '''''„ * Air Pollution Control Division t ttgrt:Mr,r CA PUtAC Health y Envrreu� ay:t Colorado Regulation ❑ Subject Click here to enter text. No. 7 Part D Section I.J ❑x Not Subject Colorado Regulation ❑ Subject No. 7 Part D Section Click here to enter text. I.K ❑x Not Subject Colorado Regulation ❑ Subject No. 7 Part D Section Click here to enter text. II.F El Not Subject 0 Subject RACT for these reciprocating compressor blowdowns has been Reasonably Available ❑ Not Subject determined to be good work practices. Control Technology (RACT) Note that the applicant may be asked to provide a RACT analysis if new or modified equipment in a nonattainment or attainment/maintenance area. Compliance Assurance ❑ Subject If subject, attach Form OP-203 CAM unless CAM has already been Monitoring (CAM) El Not Subject addressed in the permit. Colorado Regulation El Subject No. 1 Opacity These requirements are identified in Form OP-400. Requirements Not Subject Other (specify) clack_ here to enter. text. Colorado Regulation No. ❑ Subject Colorado Regulation No. ❑ Subject 1 PM Requirements ❑x Not Subject 1 SO2 Requirements El Not Subject Colorado Regulation No. ❑ Subject Colorado Regulation No. ❑ Subject 6 PM Requirements ll Not Subject 6 SO2 Requirements C Not Subject 10. Control Device Information Is any emission control equipment or practice used to reduce emissions? El Yes El No If yes, describe control device(s) below: Control Device Click here to describe control device. Description Enter Pollutant PM PM10 PM2.5 SO2 NOx VOC CO Lead Other Control Efficiency Text Text Text Text Text Text Text Text Text Controlled Individual All Enter Enter Enter Enter Enter Enter Enter Enter HAP HAP HAP HAP HAP HAP HAP HAP HAP HAP v Control Efficiency [Text Text Text Text_ Text Text LText Text Text 11. Criteria Pollutant Emission Information Emission Uncontrolled Controlled Factor Source Uncontrolled ' Permitted Pollutant Emission Emission Emission (e.g. AP-42, Potential-to- Limitation Factors Factors Factors Units manufacturer, Emit (tpy) (tpy) , source test, I etc. Form Revised March 2020 Page 14 of 6 'COLOR A D O AIRS ID: 123-0277-076 , ,Dep`xlme , trilkiii_::. ire COLORADO Form OP-314 Mr Pollution Control Division car D inre '.=e cl A,,VIC Reaith E fnvrrt Y,ri PM ES EF EF Units EF Source PTE Limit PM10 EF EF EF Units EF Source PTE Limit PM2.5 ES SF EF Units ES Source PTE Limit SO2 EF ES EF Units EF Source PTE Limit NOx EF EF ES -.,nits EF Source PTE Limit Lb/event (C- 234, 235, 43.52 43.52 VOC 85.63 85.63 236, 238) Mass Balance 9.9 9.9 Lb/event (C- 238) CO ES ES EF Units ES Source PTE Limit Lead EF EF EF Units EF Source PTE Limit Enter EF ES EF Units EF Source PTE Limit Pollutant_ 12. Hazardous Air Pollutant (HAP) Emission Information Emission Uncontrolled Controlled Emission Factor Source Uncontrolled Permitted (e.g. AP-42 Pollutant Emission Emission Factors Potential-to- Limitation Factors Factors Units manufacturer, Emit (tpy) (tpy) source test, etc. Benzene ES EF EF Units ES Source PTE Limit Toluene EF ES EF Units EF Source PTE Limit Ethylbenzene ES ES ES Units EF Source PTE Limit , Xylene ES EF ES Units EF Source PTE Limit Lb/event (C-234, n-Hexane 0.85 0.85 235, 236, Mass Balance 0.2 N/A 1.67 1.67 238) Lb/event (C-238) 2,2,4- EF EF EF Units ,F Source PTE Limitit Trimethylpentane Methanol ES EF ES Units EF Source PTE Limit Enter HAP EF EF EF Units ES Source PTE Limit 13. Compliance and Monitoring I have filled out and attached Form OP-400 Compliance and Monitoring with all known applicable requirements for this emission unit: Z Yes ❑ No 14. Required Attachments The following must be attached in order for the application to be considered administratively complete Form Revised March 2020 Page 15 of 6 ; !COLORADO AIRS ID: 123-0277-076 Department et Public Health 8 Environment :,a COLORADO Form OP-314 Air Pollution Control Division ocy...-, r.Ct?ub c 14caltt; EnOrpr-ncr:( (unless previously submitted): ❑ Simulation Model Inputs & Emission Report (if applicable) • ProMax, HYSYS, etc. ❑ Emission Calculations • Refer to instructions sheet for guidance ❑ Extended Gas Analysis or Pressurized Extended Liquids Analysis • Must include BTEX, n-Hexane & methanol; sample temperature and pressure ❑ Flash Gas Liberation Analysis (if applicable; refer to PS Memo 17-01) • Must include sample, intermediate (if any) and final temperatures and pressures, flash gas volume, flash gas composition (including BTEX, n-Hexane, methanol and H2S), gas-to-oil ratio (GOR) and Reid Vapor Pressure (RVP) ❑ Manufacturer Specifications or Contract Guarantee for Control Equipment (if applicable) __,I Form Revised March 2020 Page 16 of 6 ,,•,,, !COLORADO AIRS ID: 123-0277-076 Depa"'aent of Pub& Health ft Environment Attachment D Title V Operating Permit Form—OP-400 Compliance and Monitoring Enterprise Compressor Station a COLORADO Form OP-400 Air Pollution Control Division G;tu.1-1.,a-Gt PuMC Wain'v Er alfOrtr.ra • Compliance and Monitoring Title V Operating 95OPWE103 AIRS ID Number: 123 - 0277 - 076 Permit Number: 1. Instructions l Complete this form and attach it to the completed corresponding OP-300 series form for the applicable emission unit. Each OP-300 series form must be accompanied by a Compliance and Monitoring form (OP-400). Refer to the instruction sheet or contact the Division with questions. Any form with missing information may be determined administratively incomplete and may result in inability to grant the application shield of Regulation No. 3, Part C, Section II.B. Renewal and modification applications for equipment already included in the Title V permit are allowed to only complete portions of the form affected by the modification. Note that if using copy and paste; the applicant must paste as plain text. See "General Instructions" document for more details. 2. Emission Unit Information Facility Identifier COMP-BD (example: 5001) 3. Applicable Requirements Identify each applicable requirement for the emission unit, any associated compliance monitoring, recordkeeping, and reporting requirements, and the basis for the requirement. If more space is needed, attach additional descriptions. Emission Limitations (tpy, lb/hr, lb/MMBtu, gr/dscf, etc.) VOC - 9.9 tpy Opacity N/A Form Revised March 2020 Page 11 of 3 -'„'k COLORADO AIRS ID: 123-0277-076 � , Department eparture`°s Public , y,4 COLORADO Form OP-400 Air Pollution Control Division a PUI 2D,wr r:of Pubtc 7 Araim 2:Enoror xmt Operational Limitation(s) (hrs/yr, MMscf/yr, lb/yr, etc.) Blowdown Events - Each Compressor: 76 events/yr Other Requirements List all other applicable requirements for this emission point. Annual Extended Gas Analysis RACT - Good Work Practices Final Approval - Complete initial extended gas analysis, submit with first semi-annual report 4. Monitoring Requirements Complete the following monitoring questions about the emission unit. Continuous Emission Monitoring Requirements? ❑ Yes G No Pollutant(s) or Parameter(s): , . Requirement(s): i_ --1 t o t < _ ❑ Continuous Emission Monitoring System (CEMS) ❑ Predictive Emission Monitoring System (PEMS) ❑ Continuous Emission Rate Monitoring System (CERMS) ❑ Other (describe): _.._ _ _ _ . Periodic Compliance Testing? ❑ Yes ❑x No Pollutant(s): _._ . Frequency:Frequency: i , c,k .r, . Date of last Division-approved test: _ . . _ ._ __. _. Other? ❑x Yes ❑ No Describe: Extended Gas Analysis Frequency: Annual Form Revised March 2020 Page I 2 of 3 , COLORADO AIRS ID: 123-0277-076 . Department °'Public ._. Hea[thBEnvironment COLORADO Form OP-400 Air Pollution Control Division PutXc uTaIrr,C fnvu .ners 5. Compliance Status and Commitment Indicate the compliance status of the emission point as of the date of submittal: ❑ In compliance with all applicable requirements I Not in compliance (fill out Section 6 below if schedule of compliance is required) For applicable requirements this emission point is currently in compliance with: FA The emission point will continue to comply with these requirements For applicable requirements that will become effective during this permit term: E The emission point will comply with these requirements in a timely basis B 6. Schedule of Compliance Complete this section if "Not in compliance" was answered in Section 5 and a schedule of compliance is required. Also, complete this section if the applicant is required to submit a schedule of compliance by an applicable requirement. Attach copies of any judicial consent decrees, compliance orders on consent, or administrative orders, etc. for this requirement. 19WE0094 Condition 2: Submit self-certification within 180 days of construction permit issuance. Applicable Requirement 19WE0094 Condition 12: Complete an initial site specific extended gas analysis (Description and Citation) within 180 days of construction permit issuance. Analysis shall be used to calculate site-specific emission factors. Analsis and results provided with Self Certification. Reason for Noncompliance Compliance deadline oversight Narrative Description How Self Certification will be submitted for this construction permit as soon as Compliance Will be practicable, including the required initial testing results described above. Achieved Provide a schedule of corrective action(s), including an enforceable sequence of actions with milestones, leading to compliance, including a date for final compliance. Corrective Action Date to be Achieved Submit Self-Certification with initial testing results. 8/31/2020 e t ("IILL.k hert, ClicK Click hre First Progress Report will be Submitted on: N/A Frequency of Submittals Thereafter: N/A Form Revised March 2020 Page I 3 of 3 mk COLORADO AIRS ID: 123-0277-076 Health artmento Publit INFO TO SUPPORT 8/24/2020 Modification *Note that the information presented in this modification application was subsequently modified with the 10/30/2020 significant modification application. ��0:,. COLORADO ..‘40 Department Department of Public Health 8 Environment August 25, 2020 Roshini Shankaran Senior Environmental Engineer DCP Operating Company, LP 370 17th Street, Suite 2500 Denver, CO 80202 REF: DCP Operating Company, LP - Enterprise Compressor Station, OP #95OPWE103, FID# 123-0277 SUBJECT: Administrative Completeness Determination for Significant Modification Dear Ms. Shankaran: The application for the revision to the operating permit for the Enterprise Compressor Station (received August 24, 2020) to incorporate the applicable requirements from the construction permit issued for equipment blowdowns (19WE0094) has been determined to constitute a significant modification as defined in Regulation No. 3, Part C, Section I.A.7. As stated in that section, significant modifications will be processed using the procedures set forth in Part C of Regulation No. 3, for combined Construction/Operating Permit issuance. Fees Colorado Regulation No. 3, Part A Section VI.A.1 requires the division to charge fees to "...recover the direct and indirect costs incurred by the Division in processing permit applications, issuing permits, and in conducting a compliance monitoring and enforcement program. Such fees shall apply without regards to whether a permit is issued, denied, withdrawn, or revoked." With respect to processing applications and issuing permits, fees wilt be charged for time spent reviewing the application and drafting the permit and associated basis document, including researching regulatory and technical issues related to the application and permit draft as applicable. Chargeable time also includes peer and supervisor review of drafts, as well as time spent by permit engineers and division management in meetings, phone calls, and responding to emails. The hourly permit processing fee is $108.12 beginning on July 1, 2020. Please see https://www.colorado.gov/pacific/cdphe/emissions-and-permitting-fees for additional information about fees. Please note that the Division utilizes a quarterly billing system for all operating permits. The bills you receive will reflect chargeable time for the previous quarter. The Colorado Legislature has directed the Division to inform sources if the time spent processing an application wilt exceed 30 hours. The Division has determined that the time required to process your application for renewal of the operating permit will exceed 30 hours. Based on our experience in processing oc C z. 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe (ye , To` Jared Polls, Governor I Jill Hunsaker Ryan,MPH, Executive Director ,t',,fi; i ) '>-. i N�876r operating permits, we estimate that the total time required to process your application will be between 25 and 100 hours. This letter fulfills the Division's obligation to inform you that the processing time for your operating permit renewal will exceed 30 hours and to provide you with an estimate of the processing time. Timeline Significant modifications are processed under the same time lines and procedures as new operating permits, including Public Comment and EPA review. Within sixty (60) days of receiving an application for a significant modification the Division must determine if the application is administratively complete. Under the provisions of Regulation No. 3, Part C, Section IV.C, the Division has 18 months from the receipt of a complete application in order to approve or disapprove the application. The 18 month clock starts on the date a complete application is submitted. Please note that you must operate under the conditions of construction permit 19WE0094 until the revised operating permit has been issued. Required Additional Information The Division has determined that the August 24, 2020 application is administratively complete. If during the technical review of your application, the Division determines that additional information is necessary to evaluate or take final action on this application, a request will be made in writing for the information and a reasonable deadline for response set. If you fail to provide the requested information or do not meet the deadline, the Division will be unable to continue with the processing and issuance of the modified permits (Regulation No. 3, Part C, Section IV.D). Please do not hesitate to contact me if you have any questions at 303-692-6332 or elie.chavez®state.co.us. Sincerely, CS) Elie Chavez, P.E. Engineer, Operating Permit Unit Stationary Sources Program Air Pollution Control Division 11/23/2020 State.co.us Executive Branch Mail-Completeness Letter for Enterprise Sig Mod .4 4 STATE OF Chavez-CDPHE, Elie<elie.chavez@state.co.us> ' COLORADO Completeness Letter for Enterprise Sig Mod 1 message Chavez-CDPHE, Elie<elie.chavez@state.co.us> Tue, Aug 25,2020 at 3:53 PM To: "Shankaran, Roshini"<RShankaran@dcpmidstream.com> Cc: "Chris Platt(chrisplatt@windriverenvironmental.com)" <chrisplatt@windriverenvironmental.com> Hi Roshini, Please find attached the completeness letter for the 19WE0094 roll-in request for Enterprise. Please let me know if you have any questions or need anything else! Thanks so much, Elie Chavez Permit Engineer Title V Operating Permit Unit Stationary Sources Program Air Pollution Control Division f COLORADO 40 Air Pollution Control Division Department of Public Health&Environment P 303.692.6332 4300 Cherry Creek Drive South, Denver, CO 80246-1530 elie.chavez@state.co.us I www.colorado.gov/cdphe/aped Are you curious about ground-level ozone in Colorado?Visit our ozone webpage to learn more. fibi 123-0277 Sig Mod Completeness Letter 8-25-20.pdf 169K https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permthid=thread-a%3Ar3995320506052346527&simpl=msg-a%3Ar771019700... 1/1 10/30/2020 Modification Application DCP Midstream cicips 370 1701 Street,Suite 2500 _.._....o.� Denver.C()80202 Midstream.. 3034,05-2039 October 29,2020 Sent via UPS Tracking#: I Z F46 915 01 9700 2236 Mrs. Elie Chavez Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South, APCD-SS-BI Denver, CO 80246-1530 Re: DCP Operating Company, LP; Enterprise Compressor Station (123/0277) Title V Permit 95OPWE103 Significant Modification Application COMP-BD (AIRS 076) Revised Emission Calculations Mrs. Chavez: DCP Operating Company, LP (DCP) is submitting the attached application for the Enterprise Compressor Station, located in SWSW Section 30, Township 3N, Range 63W, Weld County, Colorado. DCP is providing revised emission calculations for the compressor blowdown AIRS point (COMB-BD, AIRS 076) to satisfy the initial self-certification requirement in Construction Permit 19WE0094. The self certification requirements contained in this construction permit require DCP to conduct an initial extended gas analysis in order to verify the original lb/event emission factors used to calculate the VOC and HAP emissions from this source. The analysis conducted resulted in emission factors higher than the initial factors provided by DCP. In order to correct this issue, DCP is providing updated emission calculations for this source, per the self certification requirements in permit I9WE0094. As this construction permit has already been incorporated into the pending Title V renewal permit(95OPWEI03) for this source, DCP is providing these emission calculation corrections as a significant modification to the Title V permit, rather than as a modification to the underlying construction permit. DCP is providing all necessary CDPHE Title V operating permit forms necessary to make the requested changes. In the Title V Significant Modification application submitted August 21, 2020, addressing the roll-in of construction permit 19WE0094 into TV permit 95OPWEI03, DCP noted that P016 - Condensate Truck Loadout Rack controlled with a combustor(AIRS 076), was out of compliance due to truck loading events not being controlled. However, it has since been determined that the deviation DCP identified for P016 was in error and was the result of a miscommunication. P016 is associated with truck loading of facility stabilized condensate, which is, and has been, controlled by the facility enclosed combustor. The truck loading that was not controlled, and was the source of the information used in the incorrect identification of the deviation, was associated with un-stabilized condensate, an activity that is included in the Title V Permit as an insignificant activity. Attachments The application includes the following attachments: A. APEN Fees B. Revised APEN form for unit COMB-BD (AIRS 076) C. Revised Emission Calculations and Supporting Documentation (AIRS 076) D. Title V Operating Permit Application Form —OP-50 E. Title V Operating Permit Application Form —OP-102 Plant-Wide Criteria Emissions F. Title V Operating Permit Application Form —OP-202 Oil & Gas Facility Form G. Title V Operating Permit Application Form—OP-314 SEP and NG Venting H. Title V Operating Permit Application Form —OP-400 Compliance and Monitoring 1. Form APCD-102 If you have any questions or require any additional information about this application, please feel free to contact me at (303) 605-2039 or rshankaran@dcpmidstream.com. Sincerely, DCP Operating Company, LP • Roshini Shankaran Senior Environmental Engineer Enclosures Attachment B Revised APEN—COMB-BD (AIRS 076) Enterprise Compressor Station • • Gas Venting APEN - Form APCD-211 4g0 440s Au Pollutani EMISS1O11 C�PHE Application [or Construction Pcrinit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for gas venting only. Gas venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit.does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-2OO)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. 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: 95OPWE 103 AIRS ID Number: 123 /0277 /076 [Leave blank unless APCD has already assigned a permit II and AIRS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30, T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: 370 17th Street, Suite 2500 (Include Zip Code) Denver, CO 80202 Contact Person: 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 the APCD via e-mail to the address provided. 431 3S COLORADO y Form APCD-211 -Gas Venting APEN - Revision /20 1 I it.„ ^' T.t Permit Number: 95OPWE103 03 AIRS ID Number: 123 /o277/076 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly-reported emission source • -OR- ID MODIFICATION to existing permit(check each box below that applies) El Change fuel or equipment ❑ Change company name3 O Add point to existing permit Change permit limit O Transfer of ownership4 O Other(describe below) -OR ▪ APEN submittal for update only(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 Ft Notes: 3 For company name change,a completed Company Name Change Certification Form(Form APCD-106)must he submitted. 4 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: Compressor Engine Blowdowns for maintenance and repair Company equipment Identification No. (optional): COMB-BD For existing sources,operation began on: 1 994 • For new, modified, or reconstructed sources, the projected start-up date is: ❑✓ 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 Witt this equipment be operated in any NAAQS Yes O No nonattainment area? Is this equipment located at a stationary source that is Yes 12 No • considered a Major Source of(HAP)Emissions? Is this equipment subject to Colorado Regulation No. 7, O Yes J No Section XVII.G? au COLORADO Form APCD-211 -Gas Venting APEN - Revision '/20's' 2 I °"" °'=,,, NWI�h/n��nnmml Permit Number: 95OPWE 1 03 AIRS ID Number: 123 /0277/076 [Leave blank unless APCD has already assigned a permit A and AIRS IDI Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: Serial#: Capacity: gal/min ❑ Compressor Rod Packing Make: Model: #of Pistons: Leak Rate: Scf/hr/pist ❑� Blowdown Events #of Events/year: 325 Volume per event: See Below* MMscf/event ❑ Other Description: If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑ Yes 0 No Vent Gas Gas Venting Healing Value: 1,305.6 BTU/SCF Process Parameters5: Requested: 1.22 MMSCF/year Actual: 1.28 MMSCF/year -OR- Liquid Throughput Process Parameters5: Requested: bbl/year Actual: bbl/year Molecular Weight: 22.30 Ib/Ib-mol CorPres rn Rlowdo wn VOC (Weight%) 30.17 Volumes: Benzene(Weight%) 0.05 Vented Gas Toluene(Weight%) 0.05 C-238 = 2,883 scl/event Properties: Ethylbenzene(weight%) 0.003 C-235 = 2,883 sct/event (.-236 = 2,883 scl/event Xylene (Weight%) 0.02 C-234 = 2,88; sd/event n-Hexane(Weight%) 0.38 C-237 = 5,h7.1 scl`event 2,2,4-Trimethylpentane (Weight%) 0.001 Additional Required Documentation: 0 Attach a representative gas analysis(including BTEX 8 n-Hexane, temperature, and pressure) ❑ Attach a representative pressurized extended liquids analysis(including BTEX Et n-Hexane, temperature, and pressure) 5 Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider future process growth. Requested values are required on all APENs,including APEN updates. Am COLORADO Form APCD-211 - Gas Venting APEN - Revision t''/20 3 1 As. Permit Number: 95OPWE 103 AIRS ID Number: 123 /0277/076 (Leave blank unless APCD has already assigned a permit ri and AIRS ID] Section 5 - Geographical/Stack Information • Geographical Coordinates (Latitude/Longitude or UTM) 40.191 /-104.4877 ▪Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Discharge Height Operator Temp. Flow Rate Velocity Above Ground Level Stack ID No. r F) (ACFM) (ft/sec) (Feet) Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Downward ❑ Upward with obstructing raincap ❑Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) ❑Circular Interior stack diameter(inches): ❑ Square/rectangle Interior stack width(inches): Interior stack depth(inches): ❑Other(describe): Section 6 - Control Device Information Q Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Size: Make/Model: ❑ VRU: Requested Control Efficiency: VRU Downtime or Bypassed: Pollutants Controlled: Rating: MMBtu/hr Type: Make/Model: ❑ Combustion Requested Control Efficiency: Device: Manufacturer Guaranteed Control Efficiency: Minimum Temperature: Waste Gas Heat Content: Btu/scf Constant Pilot Light: 0 Yes 0 No Pilot burner Rating: MMBtu/hr Pollutants Controlled: ❑ Other: Description: Requested Control Efficiency: �!► !COLORADO Form APCD-211 - Gas Venting APEN - Revision 1,,/20)._ 4 I ! "'�«m N U.6G Permit Number: 95OPWE 103 AIRS ID Number: 123 /0277/076 [Leave blank unless APCD has already assigned a permit fl and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? O Yes 1 No If yes, describe the control equipment AND state the requested control efficiencies(report the overall,or combined, values if multiple emission control methods were identified in Section 6): Overall Requested Pollutant Control Equipment Description Control Efficiency (%reduction in emissions) PM SOX NO„ CO VOC HAPs Other: From what year is the following reported actual annual emissions data? 201 9 Use the following table to report the criteria pollutant emissions from source: Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Pollutant Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled AP-42, Basis Units ( Emissions Emissions Emissions Emissions Mfg.,etc.) (tons/year) tons/ ear (tons/ ear(tons/year)) (tons/year) (tons/year) PM SO. NO. CO VOC 362.0/712.4 scflevent Mass Balance 2,27 2.27 9.91 9.91 5 Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider future process growth. Requested values are required on all APENs, including APEN updates. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide projected emissions. Potential Emission Estimates C-234. C-235, C-236,C-238=362 scf V0C /event C-237 712.4 scf V0C i event Density of Natural Gas=0.0577 ib/scf Section 8 - Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteria Yes O No pollutants(e.g. HAP - hazardous air pollutant)equal to or greater than 250 lbs/year? If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: Chemical Emission Factor Actual Annual Emissions Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) Uncontrolled Units Basis (AP 42, Emissions Emissions6 Number Mfg.,etc.) (lbs/year) (lbs/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n-Hexane 110543 0.8611.67 lb/event Mass Balance 260 260 2,2,4-Trimethylpentane 540841 Other: 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide projected emissions. COLORADO . 20.9 Ar£ua1 fn7issions 5 >.em• Zo He..ro>:�m.o O234. C-235,C-236. C-238 0.085 lb n-Hexane event C-237 1.67 lb n-Hexane /event Permit Number: 95OPWE 1 03 AIRS ID Number: 123 /0277/076 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. 1012 t /zo2 o Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Senior Environmental Engineer Name(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 $216.00 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692-3175 APCD-SS-B1 OR 4300 Cherry Creek Drive South (303)692-3148 Denver,CO 80246-1530 APCD Main Phone Number Make check payable to: (303)692-3150 Colorado Department of Public Health and Environment �!► COLORADO Form APCD-211 - Gas Venting APEN - Revision /20 ! 6 I f i. NeeMA b ln.+.v.nen Attachment C Emission Calculations and Supporting Documentation (AIRS 076) Enterprise Compressor Station fl Compressor Engine Blowdown Emissions-COMP-BD Enterprise Compressor Station DCP Operating Company,LP Gas Corls8luent _.. Inlet Gassomple' Mama.) {Vol%).. I(lbllbmole Gas) (Wt%) -. Comxted for He VOCwt% VOCWt%r;Buner`.. Helium 4.00 0.000 0.00 0.00 - - - Hydropen 2.02 0.000 0.00 0.00 - - - Carbon Dioxide 44.01 2.400 1.06 4.74 - - Nitrogen 28.00 0.380 0.11 0.49 - - - H2S 34.10 0.000 0.00 0.00 - - - Methane 16.04 72.024 11.55 51.81 53.39 - - Ethane 30.07 13.804 4.15 18.61 19.18 - - Propane 44.10 6.922 3.05 13.69 14.11 14,11% 15.52% i-Butane 58.12 0.876 0,51 2.28 2.35 2.35% 2.59% n-Butane 58.12 2.188 1.27 5.70 5.88 5.88% 6.46% isopentane 72.15 0.498 0.36 1.61 1.66 1.66% 1.83% ',Pentane 72.15 0.525 0.38 1.70 1.75 1.75% 1.93% Cydopentane 70.13 0.023 0.02 0.07 0.07 0.07% 0.08% n-Hexane 86.18 0.087 0,07 0.34 0.36 0.35% 0.38% ' Cyd ..ohesane 84.16 0.019 0.02 0,07 0.07 0.07% 0.08% Other Hexanes 86.18 0.146 0.13 0.56 0.58 0.58% 0.64% Heptanes 100.20 0.056 0.06 0.25 026 0.20% 0.28% Methyicyclohexane 98.19 0.015 0.02 0.07 0.07 0.07% 0.08% 2.2,4 Tnmethylpentane 114,23 0.000 0.00 I 0.00 0.00 0.001% 0.001% Benzene 78.11 0.013 0.01 0.05 0,05 0.05% 0.05% Toluene 92.14 0.010 0.01 0.04 0.04 0.04% 0.05% Ethylbenzene 106.17 0.001 0.00 0.00 0.00 0.003% 0.003% Xylenes 106.20 0.003 0.00 0.01 0.01 0.01% 0,02% C8. 114.23 0.026 0.03 0.13 0.14 0.14% I 0.15% Methanol - 106.10 0.006 0.01 i 0.03 0.03 0.03% I 0.03% Total 100.0 22.40 102.3 .. 100.0 ` 27.42% I 30.17% 'Enterpnse Inlet EGA Dated 8/121_'019 '700 a1%includes a 10%buffer to account(or vanelion in(inure yes composSIon Vent scf/blpwdown a blowrbwns/yr MMscf/yr J tpy VOC9 lb/yr n-Hexane lb/yr Benzene I lb/yr Toluene lb/yr Ethylbenzene 1 lb/yr Xylenes lb/yr 2,2.4-TMP lb/yr McOH Engine C-238/P003 2,883 65 0.19 1 1.66 41.87 6.86 I 5,18 0.36 1.66 0.06 3.56 Engine C-235/P-006 2,883 65 0,19 1.66 41.87 5.86 ! 5.16 0.36 1.66 0.06 3.56 Engine C-236/P-006 2,883 65 0.19 1.66 41.87 5.86 11 5.16 0.36 1.66 0.06 3.56 Engine C-234IP-018 2,883 65 0.19 1.66 41.87 5.86 5.16 0.36 1.66 0.06 3.56 Engine C-237 5.674 65 0.37 3.27 82.40 11.53 I 10.15 0.70 3.28 0,11 7.01 'Total 325 7.12 I 9.97 249.90 34.97 I 30.78 2.73 j 9.93 0.38 I 27.27 'Slowdown volume(set/blowNown)=Itublowdown(Enpmeenn8 Edmore,/Gas Denary(8/12/2018 80.41 'Gae Density=Ralabve Density(9/22/2017 EGA)'Notify of Air at EGA Temo/Proccure • 'VOC/HAPemwslons Itansryrl s scetlowdown•1 2-mel/3795 se('MW/IbAb-mob'Bbwdowns4r•VOC/HAP uH%'1 ton/700016 vEMPACT l!t J Ifnv A . I i EXTENDED NATURAL GAS ANALYSIS(*DNA) MAIN PAGE PRIMARY DB KEY: NAME/DESCRIP: ENTERPRISE LEASE#: PRE TEG INLET FIELD/AREA: PROJECT NO. : 201908082 ANALYSIS NO.: 01 COMPANY NAME: DCP MIDSTREAM ANALYSIS DATE: AUGUST 15,2019 07:25 OFFICE/BRANCH: GREELEY,CO SAMPLE DATE : AUGUST 12,2019 11:55 CUSTOMER REF: PO:0000492677 RC-G033 TO: PRODUCER : EFFECTIVE DATE: ***FIELD DA'T'A*** SAMPLE CYCLE: SAMPLE TYPE: SPOT SAMPLE PRES.: 920 psig PROBE: FLOW PRES.: psig CYLINDER NO.: 1750 LAB PRES: psig SAMPLED BY : CHANDLER COLE SAMPLE TEMP.: 42 "c SAMPLING COMPANY: DCP MIDSTREAM AMBIENT TEMP.: 01 H2S BY STAIN TUBE: _ ppm H2O BY STAIN TUBE: - #/none!' CO2 BY STAIN TUBE: _ Mol%r FIELD COMMENTS: LAB COMMENTS: GPM @ GPM @ COMPONENT MOLE% MASS% 14.73 14.65 ALCOHOLS 0.0060 0.0084 0.0010 0.0010 HELIUM 0.00 0.00 --- --- HYDROGEN 0.00 0.00 --- --- OXYGEN/ARGON 0.00 0.00 --- --- NITROGEN 0.38 0.47 --- --- CARBON DIOXIDE 2.40 4.64 --- --- METHANE 72.02420 50.71560 --- --- ETHANE 13.8043 18.2190 3.7055 3.6853 PROPANE 6.9224 13.3981 1.9141 1.9037 I-BUTANE 0.8763 2.2355 0.2878 0.2863 N-BUTANE 2.1878 5.5814 0.6924 0.6886 I-PENTANE 0.4984 1.5764 0.1811 0.1802 N-PENTANE 0.5252 1.6632 0.1912 0.1902 HEXANES PLUS 0.3754 1.4924 0.1427 0.1420 TOTALS 100.00000 100.00000 7.1158 7.0773 BTEX COMPONENTS MOLE% WT% BTU @ 14.73 14.65 BENZENE 0.0134 0.0460 LOW NET DRY REAL: 1192.6/scl 1186.2/set' TOLUENE 0.0100 0.0404 NET WET REAL: 1171.9/scf 1165.4/scf ETHYLBENZENE 0,0006 0.0028 HIGH GROSS DRY REAL: 1312.7/scf 1305.6/scf XYLENES 0.0028 0.0129 GROSS WET REAL: 1289.9/scf 1282.8/scf TOTAL BTEX 0.0268 0.1021 NET DRY REAL: 19881.4/Ib 19773.4/lb GROSS DRY REAL: 21881.0/Ib 21762.1 /II) RELATIVE DENSITY(AIR=1): 0.7860 "tvE'lAlLEl/IrDRocAlltliM't,V:M_YSlSbvlNV) DENSITY 0.06003 !M/scl' Mod AST,u ITr,>,1/,GPA _'(,l.1 GPI 22,w,. COMPRESSIBILITY FACTOR : 0.99597 n:Au':GP-%2172,(Wel 21-15&TP-17 c•/41W,,&l,o rn REGULAR WOBBE INDEX 1477.3 The data presented herein has been acquired by means of current analytical techniques and represents thejudicioas conclusion E;liPACT Analytical Systems,Inc. Results ofthe analysis can be affected by the sampling conditions,therefore,are mdr warranted through proper lab protocol. EMPACT assumes no responsibility for interpretation or our consequences from application of the reported inforumtion and is the sole liabilifr of the user. The reproduction in any media of this reported information may not be made,in portion or as a whole,without the written permission of E,MPACT Anal tical Systems,inc. EMPACT Analytical Systems Inc. 365 S Main St Brighton,CO 80601 303-637-0150 EMPACT EXTENDED NATURAL GAS ANALYSIS('DHA1 GLYCALC INFORMATION PROJECT NO. : 201908082 ANALYSIS NO.: 01 COMPANY NAME: DCP MIDSTREAM ANALYSIS DATE: AUGUST 15,2019 07:36 ACCOUNT NO. : PO:0000492677 RC-G033 SAMPLE DATE : AUGUST 12,2019 11:55 PRODUCER : CYLINDER NO.: 1750 LEASE NO. : SAMPLED BY : CHANDLER COLE NAME/DESCRIP: ENTERPRISE PRE TEG INLET "'FIELD DATA"' SAMPLE TEMP.: 42 SAMPLE PRES.: 920 AMBIENT TEMP.: H2S BY STAIN TUBE: ppm COMMENTS : SPOT f`0mts0"Gi Mole% wt a4 Helium 0.00 0.00 Hydrogen 0.00 0.00 Carbon Dioxide 2.40 4.64 Nitrogen 0.38 0.47 Methane 72.02420 50.71560 Ethane 13.8043 18.2190 Propane 6.9224 13-3981 Isobutane 0.8763 2.2355 n-Butane 2.1878 5.5814 Isopentane 0.4758 1.5068 n-Pentane 0.5252 1.6632 Cyclopentane 0.0226 0.0696 n-Hexane 0.0868 0.3283 Cyclohexane 0.0191 0-0705 Other Hexanes 0.1458 0.5488 Heptanes 0.0556 0.2429 Methylcyclohexane 0.0154 0.0664 2,2,4 Trimethylpentane 0.0001 0.0005 Benzene 0.0134 0.0460 Toluene 0.0100 0.0404 Ethylbenzene 0.0006 0.0028 Xylenes 0.0028 0.0129 1 a�He8et ee 0 0258 D 1399- Subtotal 99.99400 99.99160 Oxygen/Argon 0.00 0.00 Alcohols 0.0060 0.0084 Total 100.00000 100.00000 RDL-Delon.Detection Limit. The H25 LOS has is detection limit of 0.15 pm,A_tan uderscore)indicates there was nn tube polled for 112S. The data presented herein has been acquired by means of current mmistical teclmignes and represents the judicious eo,talnsion EWAL TAnalytical Systems,Lr. Results of the analysis sis can be affected by Me sampling conditions,therefore,are only warranted through proper lab protocol. E,1IPALT assumes no responsibility for interpretation or any consequences front application film reported information and is the sole liability of the user. The reproduction in any media of this reported information may not be made,in portion or as a whole,without the writYm permission of E lll'ACT Analytical Systems,Inc. EMPACT Analytical Systems Inc. 365 S Main St Brighton,CO 80601 303-637-0150 Attachment D Title V Operating Permit Form —OP-50 Enterprise Compressor Station CtretgACOLORADO Form OP-50 Mr Pollution Control Division Title V Operating Permit Application Form This form must be included with any application submittal to the Title V Operating Permit Unit Title V Operating 95OPWE103 Plant AIRS ID 123 - 0277 Permit Number: Number: 1. Instructions Included on the Colorado Air Pollution Control Division Website is an instruction sheet (Form OP-50A) for this application form. Refer to the instruction sheet or contact the Division with questions. Attach a cover letter describing the purpose of the application package if more room is needed. Any form with missing information may be determined administratively incomplete and may result in inability to grant the application shield of Regulation No. 3, Part C, Section II.B. Note that if using copy and paste; the applicant must paste as plain text.See "General Instructions" document for more details. 2. Permit Application Type (check all that apply) Initial _ Renewal - Identify any requested changes below or in a cover letter. Significant Modification s Administrative Modification (e.g. transfer of ownership, correct typographical error, etc.) Minor Modification - The Minor Modification worksheet (Form OP-201) must also be completed if a source wishes to use the procedures under Colorado Regulation No. 3, Part C, Section X. Notification of Construction Permit Exempt :i Title V Billing Contact Update Unit(APCD PS Memo 09-01, Scenario#7) _E Responsible Official Update Supplemental Information (describe): Click here to enter text. Other (describe): Click here to enter text. 3. General Description- Include brief description describing the purpose of the application package. If more detail is needed, provide in cover letter. This application is being submitted to official request the following changes: General Description of package Revise the Engine Blowdown emission points (AIRS 076) based on an updated extended gas analysis to satisfy the Self Certification requirements in Construction Permit 19WE0094. Form Revised March 2020 Page 11 of 3 COLORADO • H lthf,En of nm n •. 'He>ith 6 EnvuonmeN COLORADO Form OP-50 Air Pollution Control Division 4. Additional Information A. Initial and Renewal Applications Check this box if you are submitting an initial or renewal application. For all other application types, proceed to Section 4.B. If you are submitting an initial or renewal application, provide the application due date. See Colorado PS- Memo 09-01 for help with Title V Operating Permit application due dates. Application Due Date: Click here to enter text. Basis for Application Due Date (Initial Permits Only): Click here to enter text. B. APEN Attachments Enclose a copy of the most current complete Air Pollution Emission Notice(s) (APENs)on file with the Division. New/revised APENs are required if the facility is requesting a modification that requires a new APEN or changes information on a previously submitted APEN. Z New or Revised APENs have been included with this submittal (filing fees must be included) Required - Copies of all applicable APENs have been included (no filing fees are needed for these APEN copies). C. Confidential/Trade Secret Information Check the following box if any confidential/trade secret information has been submitted with this application. The pages including confidential information must clearly be labeled as confidential. See PS Memo 98-01 for acceptable confidential information submittals. :J This application includes confidential information on the following pages: Click here to enter text. D. Submittal The Division is requiring one hardcopy submittal mailed to the APCD (with any wet signatures required; see instruction documents for details) and one electronic copy submittal emailed to APCD. The electronic submittal MUST be submitted in word format (either .doc or .docx) to cdphe apcd title V®state.co.us. For legal purposes, the date the signed hardcopy is received by the Division is considered the date received, not when the electronic copy is emailed. E. Oil and Gas Sources If this facility is associated with Oil 8 Gas activities, Form OP-202 must be completed if the facility is submitting an initial application or the facility is requesting changes to oil and gas equipment and must be submitted for the application to be considered complete. Oil and Gas SIC codes include, but are not limited to, 1311, 1321, and 4922. X Form OP-202 has been included with this application. This facility is not an oil and gas facility, and/or the facility is not requesting any changes to the oil and gas equipment. F. Modeling If an emission unit will have to go through modeling as part of a permit action, OP-204 must be completed and attached to the corresponding OP-300 series form. If the applicant has already filled out the optional air quality modeling form as part of the modeling process, the applicant may attach that form in lieu of OP-204. For information about the modeling process, see the page titled "Air Quality Modeling Guidance for Permits" on the Division webpage. Form OP-204 has been completed and attached. Li A copy of the optional air quality modeling form has been attached. rZ This facility did not trigger modeling requirements. Form Revised March 2020 Page 12 of 3 . COLORADO Deparlmcnl of Publk Hea\h 6 rnvUonment �. _ I C O L O R A D O Form OP-50 is 4 I Air Pollution Control Division 5. Signature of Responsible Official / A. Statement of Completeness ❑x I have reviewed this application in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this application are true, accurate and complete. B. Certification of Facility Compliance Status With Federal and State Enforceable Conditions ❑ I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements, including compliance certification requirements and any applicable compliance assurance monitoring. , i ® I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements, except for the following emissions unit(s) identified below: COMP-BD - Engine Blowdowns (AIRS 077) C. Certification of Facility Compliance Status With State-Only Enforceable Conditions ❑ I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. ® I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements, except for the following emissions unit(s) identified below: COMP-BD - Engine Blowdowns (AIRS 077) WARNING: Any person who knowingly, as defined in 5 18-1-501(6), C.R.S., makes any false material statement, representation, or certification in, or omits material information from this application is guilty of a misdemeanor and may be punished in accordance with the provisions of§ 25-7 122.1, C.R.S. Responsible Official Charles A. Job Name or Others Title General Manager, North Area Operations Signature2 '--1,,,<,-----_ -- Date 10/29/2020 'For the following applications, a signature of a Legally Authorized Person (not a vendor or consultant) is acceptable: Notification of Construction Permit Exempt Unit, Billing contact update, Responsible Official update, and Supplemental Information submittal. For these application types, a Legally Authorized Person must only certify with Section 5.A (5.B and 5.C certifications are not needed). 2This document requires a "wet signature," electronic signatures will not be accepted. SEND MATERIALS TO: Colorado Dept. of Public Health Et Environment APCD-SS-B1 ATTN: Title V Unit Supervisor 4300 Cherry Creek Drive South Denver, CO 80246-1530 cdphe_apcd_title_V®state.co.us Form Revised March 2020 Page I 3 of 3 co 10 R A D o Dpart.nt o1 Public • Health 6 Environment Attachment E Title V Operating Permit Application Form—OP-I02 Plant-Wide Criteria Emissions Enterprise Compressor Station Cglpi ' COLORADO Form OP-102 Air Pollution Control Division Plant Wide Criteria Air Pollutants Title V Operating 95OPWE103 Permit Number: Instructions Complete the following emissions summary for criteria air emissions at this facility. Included on the Colorado Air Pollution Control Website is an instruction sheet (Form OP-102A) for this form. Note that if using copy and paste; the applicant must paste as plain text. See "General Instructions" document for more details. Classification Is this facility considered to be a single source with another facility? -1 Yes X No If yes, list other facility operating permit number(s)and plant AIRS ID(s): Click to enter text. If the facility associated with this Operating Permit application is considered a single source with another facility, fill out the following table for emissions associated with this Operating Permit application only; do not include any emissions from other facilities. Air Pollutant Uncontrolled Potential to Emit (tpy) Controlled Potential to Emit(tpy) Particulates (PM/TSP) 5.7 5.7 PMio 5.7 5.7 PMz.5 5.7 5.7 Sulfur Dioxide (SO2) 0.3 0.3 Nitrogen Oxides (NOx) 130.5 130.5 Volatile Organic Compounds 1,838.8 171.4 (VOC) Carbon Monoxide (CO) 476.5 154.2 Ozone (O3) PTE PTE Lead PTE PTE Fluorides PTE PTE Total Reduced Sulfur PTE PTE Reduced Sulfur Compounds PTE PTE Hydrogen Sulfide (HzS) PTE PTE Sulfur Acid Mist PTE PTE Municipal Waste Combustor PTE PTE • Organics Municipal Waste Combustor PTE PTE Metals Municipal Waste Combustor PTE PTE Acid Gases Form Revised March 2020 Page 11 of 1 COLORADO Deparlmenl of Wbllc Helllb b Env,ronmenl Attachment F Title V Operating Permit Application Form—OP-202 Oil & Gas Facility Form Enterprise Compressor Station COLORADO Form OP-202 Air Pollution Control Division Oil Et Gas Facility Form Title V Operating Permit 95OPWE103 Plant AIRS ID 123 - 0277 Number: Number: 1. Instructions Included on the Colorado Air Pollution Control Website is an instruction sheet (Form OP-202A) for this Oil and Gas Facility Form. Refer to the instruction sheet or contact the Division with any questions. Any form with missing information may be determined administratively incomplete and may result in inability to grant the application shield of Regulation No. 3, Part C, Section II.B. Renewal and modification applications for equipment already included in the Title V permit are allowed to only complete portions of the form affected by the modification. Note that if using copy and paste; the applicant must paste as plain text. See "General Instructions" document for more details. Form Index 2. Storage Tanks 2 3. Glycol Dehydration Units 5 4. Spark Ignition (SI) Engines 7 5. Compression Ignition (CI) Engines 9 6. Reciprocating Compressors 10 7. Centrifugal Compressors 12 8. Natural Gas Driven Pneumatic Pumps 14 9. Natural Gas Driven Pneumatic Controllers 16 10. Fugitive Emissions 17 11. Sweetening Units 20 12. Well Site Facilities 22 13. Transmission Et Storage Facilities 23 14. Emissions Inventory 24 15. Combustion Control Devices 25 Z Attach Facility Emissions Inventory Form (APCD-102) Form Revised March 2020 Page 11 of 27 COLORADO AIRS ID: 123-0277 Department o/Public • . Health b Environment 1 C O L O R A D O Form OP-202 Air Pollution Control Division 14. Emissions Inventory For the following Section, provide the information requested for the Colorado Regulation No. 7 emissions inventory for oil and natural gas operations. Colorado Regulation No. 7, Part D, V: Oil and Natural Gas Operations Emissions Inventory (rule adopted December 19, 2019) n Yes No Subject? If no, list applicable exemption(s): Click here to enter text. } Ijf II Form Revised March 2020 Page 124 of 27 COLORADO AIRS ID: 123-0277 Fail Env ro,,,,.t Attachment G Title V Operating Permit Application Form —OP-314 SEP AND NG VENTING Enterprise Compressor Station : COLORADO Form OP 314 Air Pollution Control Division . -{.art•-;.ra o. .,..;.?;�atit,=lr:v5ese r,rer3. Separator and Natural Gas Venting Title V Operating 95OPWE103 AIRS ID Number: 123 - O277 - O76 Permit Number: 1. Instructions Included on the Colorado Air Pollution Control Division Website is an instruction sheet (Form OP-314A) for this separator and natural gas venting form. Refer to the instruction sheet or contact the Division with questions.. Any form with missing information may be determined administratively incomplete and may result in inability to grant the application shield of Regulation No. 3, Part C, Section II.B. Renewal and modification applications for equipment already included in the Title V permit are allowed to only complete portions of the form affected by the modification. Note that if using copy and paste; the applicant must paste as plain text. See "General Instructions" document for more details. 2. Vented Equipment Information Facility Identifier COMP-BD (example: S001) Date commenced construction: 1994 Dates Date last modified/reconstructed: N/A Date of first operation: 1994 Separator Ll Wellhead Casing Pneumatic Pump Vented Equipment Compressor Rod Packing Blowdown Events LI Other (describe): Click here to enter brief description. 73 Vapor Recovery Unit (VRU): Click here to enter destination. { Ji Routed Directly to Process: Click here to enter destination. Emissions Routing LI Combustion Device Le Atmosphere Other (describe): Click here to enter text. General Description Natural gas venting from reciprocating compressor blowdowns of Equipment Underlying Yes No Construction Permit Permit Number: 19WE0094 List any state exemptions that apply to this separator (See Instruction Sheet for more Exemptions information): Click here to enter text. 3. Separator Venting Information 6 Check this box if this form does not address venting from a separator and leave this section blank Separator Type E Low Pressure Separator: Click here to enter quantity. (check all that apply) El High Pressure Separator: Click here to enter quantity. Form Revised March 2020 Page 11 of 6 COLORADO AIRS ID: 123-0277-076 • NS N'b EnvlronmeM ' COLORADO Form OP-314 4110 `---;: i ;C Air Pollution Control Division Vapor Recovery Tower(VRT): Click here to enter quantity. Other (describe): Click here to enter text and quantity. ::.` Low Pressure Separator: Click here to enter optional facility identifier. Vapor Recovery Tower: Click here to enter optional facility Exiting Liquids Routing identifier. I.. Atmospheric Storage Vessel(s): Click here to enter optional facility identifier. Other(describe): Click here to enter text. Two-Phase Separator Separator Design . Three-Phase Separator ri Other(describe): Click here to enter text. Inlet Pressure(s) (psig): C1 ick to list pressure of each separator. Design Information Outlet Pressure(s) (psig): Click to list pressure of each separator. Is this separator heated? !.1 Yes No Gas Vented Throughput Limitation (provide units): Click to enter Permit Throughput throughput. Limitation Liquids Throughput Limitation (provide units): Click to enter throughput. Monitoring Method: Click here to describe throughput monitoring Throughput Monitoring method. If metered, enter meter location: Click here to enter meter location. 4. Wellhead Casing Venting Information Z Check this box if this form does not address venting from wellhead casing and leave this section blank Upstream Pressure (psig): Click to enter pressure. Design Information Downstream Pressure(psig): Click to enter pressure. Permit Throughput Click to enter throughput. Limitation Monitoring Method: Click here to describe throughput monitoring Throughput Monitoring method. If metered, enter meter location: Click here to enter meter location. 5. Pneumatic Pump Venting Information IE Check this box if this form does not address venting from pneumatic pump(s) and leave this section blank Upstream Pressure: Click to enter pressure. Design Information Downstream Pressure: Click to enter pressure. Number of Pumps: Click to enter number of pumps. Permit Throughput click to enter throughput. Limitation Monitoring Method: Click here to describe throughput monitoring Throughput Monitoring method. If metered, enter meter location: Click here to enter meter location. Form Revised March 2020 Page 12 of 6 • COLORADO AIRS ID: 123-0277-076 DeP.,rlmenl of Public Health b Envnonmenl ' COLORADO Form OP-314 1 Mr Pollution Control Division i , .;>:c^;.!I i�,tr:c;a,;d-s tr i;rvu:n••nr;v ; 6. Compressor Rod Packing Venting Information 1Z Check this box if this form does not address venting from compressor rod packing and leave this section blank Facility Identifier of Compressor(s): Click here to enter compressor identifiers or compressor quantity. Design Information Number of Pistons per Compressor: Click here to enter compressor pistons. Permit Throughput Click to enter throughput. Limitation Monitoring Method: Click here to describe throughput monitoring Throughput Monitoring method. If metered, enter meter location: Click here to enter meter location. 7. Blowdown Event Venting Information El Check this box if this form does not address venting from blowdown event(s)and leave this section blank Equipment Vented: C-238, C-235, C-236, C-234, C-237 Design Information Reason for Venting: Maintenance and Repair Annual Venting Events (events/year): 65 Events / Compressor Unit / Year Permit Throughput 65 Events / Compressor Unit Limitation Monitoring Method: #of Blowdown events recorded in onsite log Throughput Monitoring If metered, enter meter location: N/A 8. "Other" Venting Information Check this box if the venting addressed by this form is covered by any of the preceding equipment-specific sections above and leave this section blank Equipment Vented: Click to enter equipment. Design Information Reason for Venting: Click to enter text. Annual Venting Events (events/year): Click to enter number of events. Permit Throughput Click to enter throughput. Limitation Monitoring Method: Click here to describe throughput monitoring Throughput Monitoring method. If metered, enter meter location: Click here to enter meter location. ' 9. State and Federal Regulations Rule Applicability How will you comply with this Regulation? 40 CFR Part 60 Subpart =- Subject Click hereto enter text. 0000 Not Subject 40 CFR Part 60 Subpart Li Subject Click here to enter text. 0000a 1>1 Not Subject Form Revised March 2020 Page 1 3 of 6 :COLORADO AIRS ID: 123-0277-076 ===.%a nnm,.% Ili AgeCOLORADO Form OP-314 Air Pollution Control Division Colorado Regulation - Subject Click here to enter text. No. 7 Part D Section I.J =l Not Subject Colorado Regulation Subject No. 7 Part D Section Click here to enter text. I.K Z Not Subject Colorado Regulation -- Subject No. 7 Part D Section Click here to enter text. II.F >1 Not Subject Subject RACT for these reciprocating compressor blowdowns has been Reasonably Available Not Subject determined to be good work practices. Control Technology (RACT) Note that the applicant may be asked to provide a RACT analysis if new or modified equipment in a nonattainment or attainment/maintenance area. Compliance Assurance -. Subject If subject, attach Form OP-203 CAM unless CAM has already been Monitoring (CAM) Not Subject addressed in the permit. Colorado Regulation __ Subject No. 1 Opacity These requirements are identified in Form OP-400. Requirements ! Not Subject Other(specify) Click here to enter text. Colorado Regulation No. Subject Colorado Regulation No. I Subject 1 PM Requirements _X Not Subject 1 SO2 Requirements =x Not Subject Colorado Regulation No. -1 Subject Colorado Regulation No. Ti2 Subject 6 PM Requirements Not Subject 6 SO2 Requirements Not Subject 10. Control Device Information Is any emission control equipment or practice used to reduce emissions? [3 Yes x No If yes, describe control device(s) below: Control Device Description Click here to describe control device. Pollutant PM PMio PM2.5 SO2 NOx VOC CO Lead Enter Other Control Efficiency Text Text Text Text Text Text Text Text Text Controlled Individual All Enter Enter Enter Enter Enter Enter Enter Enter HAP HAP HAP HAP HAP HAP HAP HAP HAP HAP Control Efficiency Text Text Text Text Text Text Text Text Text 11. Criteria Pollutant Emission Information Emission Uncontrolled Controlled Factor Source Uncontrolled Permitted Pollutant Emission Emission Emission (e.g. AP 42, Potential-to- Limitation Factors Factors Factors Units manufacturer, Emit (tpy) (tpy) source test, etc. Form Revised March 2020 Page 14 of 6 COLORADO O p O R AD O AIRS ID: 123-0277 076 Nullh Is Envuanmenl Ctirapl ! COLORADO Form OP-314 t Air Pollution Control Division PM EF EF EF Units EF Source PTE Limit PM10 EF EF EF Units EF Source PTE Limit PM2.5 EF EF EF Units EF Source PTE Limit SO2 EF EF EF Units EF Source PTE Limit NOx EF SF EF Units ' EF Source PTE Limit scf/event (C- 234, 235, 2,883 883 VOC 5,674 5674 236, 238) Mass Balance 9.9 9.9 ' scf/event (C- 238) CO EF EF EF Units EF Source PTE Limit Lead EF EF EF Units EF Source PTE Limit Enter EF EF SF Units SF Source PTE Limit Pollutant. 12. Hazardous Air Pollutant (HAP) Emission Information Emission Uncontrolled Controlled Emission Factor Source Uncontrolled Permitted Pollutant Emission Emission Factors (e.g. AP-42, Potential-to- Limitation Factors Factors Units manufacturer, Emit (tpy) (tpy) source test, etc. Benzene EF EF EF Units SF Source PTE Limit Toluene EF EF SF Units EF Source PTE Limit Ethylbenzene EF EF EF Units EF Source PTE Limit Xylene EF EF EF Units SF Source PTE Limit n-Hexane SF EF EF Units EF Source PTE Limit 2'2'4 EF EF EF Units EF Source PTE Limit Trimethylpentane — Methanol EF SF EF Units EF Source PTE Limit Enter HAP EF EF EF Units EF Source PTE Limit 13. Compliance and Monitoring I have filled out and attached Form OP-400 Compliance and Monitoring with all known applicable requirements for this emission unit: 7 Yes 7 No il 14. Required Attachments The following must be attached in order for the application to be considered administratively complete (unless previously submitted): Simulation Model Inputs £t Emission Report (if applicable) • ProMax, HYSYS, etc. El Emission Calculations Form Revised March 2020 Page I 5 of 6 , COLORADO AIRS ID: 123-0277-076 °"""Ten"tPub` - HealN&Envfronmeni Calli774, COLORADO Form OP-314 Air Pollution Control Division • Refer to instructions sheet for guidance Extended Gas Analysis or Pressurized Extended Liquids Analysis • Must include BTEX, n-Hexane Et methanol; sample temperature and pressure Flash Gas Liberation Analysis (if applicable; refer to PS Memo 17-01) • Must include sample, intermediate (if any)and final temperatures and pressures, flash gas volume, flash gas composition (including BTEX, n-Hexane, methanol and H2S), gas-to-oil ratio (GOR)and Reid Vapor Pressure (RVP) L Manufacturer Specifications or Contract Guarantee for Control Equipment (if applicable) Form Revised March 2020 Page 1 6 of 6 COLORADO AIRS ID: 123 0277-076 Health eEnvironment it Attachment H Title V Operating Permit Application Form—OP-400 Compliance and Monitoring Enterprise Compressor Station if } CalSk COLORADO Form OP-400 �.i Air Pollution Control Division Compliance and Monitoring Title V Operating 95OPWE103 AIRS ID Number: 123 - 0277 - 076 Permit Number: 1. Instructions Complete this form and attach it to the completed corresponding OP-300 series form for the applicable emission unit. Each OP-300 series form must be accompanied by a Compliance and Monitoring form (OP-400). Refer to the instruction sheet or contact the Division with questions. Any form with missing information may be determined administratively incomplete and may result in inability to grant the application shield of Regulation No. 3, Part C, Section II.B. Renewal and modification applications for equipment already included in the Title V permit are allowed to only complete portions of the form affected by the modification. Note that if using copy and paste; the applicant must paste as plain text. See "General Instructions" document for more details. 2. Emission Unit Information Facility Identifier COMP-BD (example: 5001) 3. Applicable Requirements Identify each applicable requirement for the emission unit, any associated compliance monitoring, recordkeeping, and reporting requirements, and the basis for the requirement. If more space is needed, attach additional descriptions. Emission Limitations (tpy, lb/hr, lb/MMBtu, gr/dscf, etc.) VOC - 9.9 tpy Opacity N/A Form Revised March 2020 Page I 1 of 3 COLORADO AIRS ID: 123-0277-076 UewHmem et Puhhe Health b fnvuenmem ! COLORADO Form OP-400 CAir Follution Control Division un Operational Limitation(s) (hrs/yr, MMscf/yr, lb/yr, etc.) Blowdown Events- Each Compressor: 65 events/yr Other Requirements List all other applicable requirements for this emission point. Annual Extended Gas Analysis RACT-Good Work Practices 4. Monitoring Requirements Complete the following monitoring questions about the emission unit. • Continuous Emission Monitoring Requirements? 0 Yes x. No , Pollutant(s) or Parameter(s): Click here to enter text. Requirement(s): Click here to enter text. O Continuous Emission Monitoring System (CEMS) O Predictive Emission Monitoring System (PEMS) 0_.; Continuous Emission Rate Monitoring System (CERMS) Other(describe): click here to enter text. Periodic Compliance Testing? El Yes LN No Pollutant(s): Click here to enter text. Frequency: Click here to enter text. Date of last Division-approved test: Click here to enter text. . Other? Z Yes 5 No Describe: Extended Gas Analysis Frequency: Annual Form Revised March 2020 Page 12 of 3 . COLORADO AIRS ID: 123-0277 076 � Health&Ennr omens CM14,3 ! COLORADO Form OP-400 410 Lz7virte7-- Air Pollution Control Division 5. Compliance Status and Commitment Indicate the compliance status of the emission point as of the date of submittal: In compliance with all applicable requirements _A Not in compliance (fill out Section 6 below if schedule of compliance is required) For applicable requirements this emission point is currently in compliance with: The emission point will continue to comply with these requirements For applicable requirements that will become effective during this permit term: c The emission point will comply with these requirements in a timely basis 6. Schedule of Compliance Complete this section if "Not in compliance"was answered in Section 5 and a schedule of compliance is required. Also, complete this section if the applicant is required to submit a schedule of compliance by an applicable requirement. Attach copies of any judicial consent decrees, compliance orders on consent, or administrative orders, etc. for this requirement. 19WE0094 Condition 12: Complete an initial site specific extended gas analysis Applicable Requirement within 180 days of construction permit issuance. Analysis shall be used to (Description and Citation) calculate site-specific emission factors. Analysis and results provided with Self Certification. Reason for Noncompliance Initial Site Specific EGA indicated non-compliance with originally provided emission factors Narrative Description How This significant modification application updates the emission calculations for Compliance Will be this source, allowing for ongoing compliance with revised limits. Achieved Provide a schedule of corrective action(s), including an enforceable sequence of actions with milestones, leading to compliance, including a date for final compliance. Corrective Action Date to be Achieved Submit Title V significant modification application Upon Issuance of Revised TV Permit with revised emission calculations Click here to enter text. Click here to enter text. Click here to enter text. Click here to enter text. Click here to enter. text. Click here to enter text. Click here to enter text. Click here to enter text. Click here to enter text. Click here to enter text. Click here to enter text. Click here to enter text. 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Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information,or lacks payment for the filing fee. The re-submittal will require payment fora new filing fee. This APEN is to be used for gas venting only. Gas venting includes emissions from gas/liquid separators,well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options wilt not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division(APCD)website. 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: 95OPWE 103 AIRS ID Number: 123 /0277 /076 [Leave blank unless APCD has already assigned a permit II and AIRS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30, T3N, R63W county: Weld NAICS or SIC Code: 4922 Mailing Address: 370 17th Street, Suite 2500 (Include Zip Code) Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 E-Mail Address: rshankaran@dcpmidstream.com ' Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. 4313E 11. COLORADO Form APCD-211 - Gas Venting APEN - Revision /20 1 I hl.:n 4""""""""- G.n.n.—, Permit Number: 95O PWE 103 AIRS ID Number: 123 /0277/076 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 2 - Requested Action 0 NEW permit OR newly-reported emission source -OR- Q MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 0 Add point to existing permit D Change permit limit ❑ Transfer of ownership' 0 Other(describe below) -OR- ❑ APEN submittal for update only(Note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- El Limit Hazardous Air Pollutants (HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info£t Notes: 3 For company name change,a completed Company Name Change Certification Form(Form APCD-106)must he submitted. 4 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: Compressor Engine Blowdowns for maintenance and repair Company equipment Identification No. (optional): COMB-BD For existing sources, operation began on: 1 994 For new, modified, or reconstructed sources, the projected start-up date is: El 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 0 Yes ❑ No nonattainment area? Is this equipment located at a stationary source that is • considered a Major Source of(HAP) Emissions? 0 Yes ❑ No Is this equipment subject to Colorado Regulation No. 7, ❑ Yes ❑✓ No Section XVII.G? LORADO Form APCD-211 - Gas Venting APEN • Revision //20<' 2 I '°" ' X Ih6 L,+nnmrn Permit Number: 95OPWE 103 AIRS ID Number: 123 /0277/076 (Leave blank unless APCD has already assigned a permit il and AIRS ID] Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: Serial#: Capacity: gal/min o Compressor Rod Packing Make: Model: #of Pistons: Leak Rate: Scf/hr/pist ❑� Blowdown Events II of Events/year: 325 31 5 Volume per event: See Below MMscf/event O Other EJC per email Description: rec'd 11/30/2020 If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? O Yes No EJC per email rec'd 11/30/2020 1.08 Vent Gas BTU/SCF Gas Venting Heating Value: 1,305.6 Process Parameters: Requested: 1.22 MMSCF/year Actual: 1.28 MMSCF/year -OR- Liquid Throughput Requested: bbl/year Actual: bbl/year Process Parameters: 22.80 Molecular Weight: 22.30 Ib/Ib-mol per email VOC (Weight ` Compressor Blowdown EJC s 30.17 30.11 Vol LIMO: rec'd 11/30/2020 Benzene(Weight%) 0.05 Vented Gas Toluene(Weight%) 0.05 C-238 = 2.883 scf/event Properties: C-235 = 2,883 scl/event p Ethylbenzene(Weight%) 0.003 C-236 = 2,883 sci/event Xylene(Weight%) 0.02 C-23-I = 2,883 sal/event n•Hexane(Weight%) 0.38 C-237 = 3,67-1 scl event 2,2,4-Trimethylpentane (Weight%) 0.001 Additional Required Documentation: • Attach a representative gas analysis(including BTEX 8 n•Hexane, temperature, and pressure) ❑ Attach a representative pressurized extended liquids analysis(including BTEX 8 n-Hexane, temperature, and pressure) 5 Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider future process growth. Requested values are required on all APENs,including APEN updates. �/�►Am. COLORADO Form APCD-211 -Gas Venting APEN - Revision '/20r 3 1 >•irr '° Permit Number: 95O PWE 103 AIRS ID Number: 123 /0277/076 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 /-104.4877 0 Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Discharge Height Operator Temp. Flow Rate Velocity Above Ground Level Stack ID No. (Feet) (�F) (ACFM) (ft/sec) Indicate the direction of the stack outlet: (check one) ❑ Upward O Downward ❑ Upward with obstructing raincap ❑ Horizontal O Other(describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter(inches): ❑Square/rectangle Interior stack width(inches): Interior stack depth(inches): ❑Other(describe): Section 6 - Control Device Information ❑✓ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Size: Make/Model: ❑ VRU: Requested Control Efficiency: VRU Downtime or Bypassed: Pollutants Controlled: Rating: MMBtu/hr Type: Make/Model: ❑ Combustion Requested Control Efficiency: Device: Manufacturer Guaranteed Control Efficiency: % Minimum Temperature: Waste Gas Heat Content: Btu/scf Constant Pilot Light: O Yes O No Pilot burner Rating: MMBtu/hr Pollutants Controlled: ❑ Other: Description: Requested Control Efficiency: % �!► COLORADO '.x' Form APCD-211 - Gas Venting APEN - Revision /20 4 I i�►3i ''��X F6fn Permit Number: 955OPWE 1 03 AIRS ID Number: 123 /0277/076 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑Yes 0 No If yes, describe the control equipment AND state the requested control efficiencies(report the overall,or combined, values if multiple emission control methods were identified in Section 6): Overall Requested • Pollutant Control Equipment Description Control Efficiency (%reduction in emissions) PM SOx NO. CO VOC HAPs • Other: From what year is the following reported actual annual emissions data? 201 9 Use the following table to report the criteria pollutant emissions from source: Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Pollutant Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Units M(�'" ,etc.) Emissions Emissions6 Emissions Emissions Basis fg. (tons/year) (tons/year) (tons/year) (tons/year) PM SOx NO,, CO VOC 362.0/712.4 scf/even) Mass Balance 2.27 2.27 9:41 93i 9 361 / 711 9.8 V8 5 Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider future process growth. Requested values are required on all APENs,including APEN updates. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide projected emissions. Potential Emission Estimates DC emailC-234.C-235, C-236.0.238 362 scf VOC /event 361 p C-237=712.4 scf VOC ;event rec'd 11/30/2020 Density of Natural Gas=0.0577 lb/scf 711 Section 8 - Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteria 0 Yes O No pollutants (e.g. HAP - hazardous air pollutant)equal to or greater than 250 lbs/year? If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: Chemical Emission Factor Actual Annual Emissions Abstract Source Uncontrolled Controlled Chemical Name Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions6 Number Basis Mfg.,etc.) (lbs/year) (lbs/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 EJC per Xylene 1330207 email n-Hexane 110543 045/1 C lw/evenl Mass-Balance 260 269 2,2,4•Trimethylpentane 540841 recd Other: 11/30/20 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide projected emissions. jeet OLOR 4D0 2074 Actual Emissions 5 I C-234, C-235, C-236. C-238 0.085 lb n-Hexane /event C-237- 1.67 lb n-Hexane /event Permit Number: 95jOPWE 1 03 AIRS ID Number: 123 /0277/076 [Leave blank unless APCD has already assigned a permit II and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. 1012 (t/207 t Signature of Legally Authorized Person (not a vendor or consultant) Date Roshini Shankaran Senior Environmental Engineer Name(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$216.00 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692-3175 APCD-SS-B1 OR 4300 Cherry Creek Drive South (303)692-3148 Denver,CO 80246-1530 APCD Main Phone Number Make check payable to: (303)692-3150 Colorado Department of Public Health and Environment y�!►► COLORADO Form APCD-211 - Gas Venting APEN - Revision /20 6 I �17n Nnteh b Ennrnemen 11/30/2020 State.co.us Executive Branch Mail-DCP Enterprise Blowdown Mod STATE OF La J5 COLORADO Chavez-CDPHE,Elie<elie.chavez@state.co.us> DCP Enterprise Blowdown Mod • Shankaran,Roshini<RShankaran@dcpmidstream.com> Mon,Nov 30,2020 at 9:00 AM To:"Chavez-CDPHE,Elie"<elie.chavez@state.co.us> Hi Elie—Yes the APEN looked great,sorry I forgot to respond earlier. Looking forward to getting the permit issued,yaay! Thanks again for all your hard work and hope you had a wonderful Thanksgiving! 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 dcp Midstream From:Chavez-CDPHE,Elie<elie.chavez@state.co.us> Sent:Monday,November 30,2020 7:06 AM To:Shankaran,Roshini<RShankaran@dcpmidstream.com> Subject:Re:[EXTERNAL]DCP Enterprise Blowdown Mod • ***CAUTION!EXTERNAL SENDER"TAKE A CLOSER LOOK!Do you know and trust this sender?Were you expecting this email? Are grammar and spelling correct?Does the content make sense?If suspicious,then do not click links,open attachments or enter your ID or password and report it as Phishing.*** [Quoted text hidden] https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1684801596528057903&simpl=msg-f%3A16848015965... 1/1 INFO TO SUPPORT 10/30/2020 Modification *Note that the information presented in this modification application was subsequently modified per the attached 11/18/2020 email and calculations received. C,. X�« . COLORADO ir Department Public Health b Environment November 4, 2020 Roshini Shankaran Senior Environmental Engineer DCP Operating Company, LP 370 17th Street, Suite 2500 Denver, CO 80202 REF: DCP Operating Company, LP - Enterprise Compressor Station, OP # 95OPWE103, FID# 123-0277 SUBJECT: Administrative Completeness Determination for Significant Modification Dear Ms. Shankaran: The application for the revision to the operating permit for the Enterprise Compressor Station (received October 30, 2020) to modify the compressor blowdown point (AIRS 076) has been determined to constitute a significant modification as defined in Regulation No. 3, Part C, Section I.A.7. As stated in that section, significant modifications will be processed using the procedures set forth in Part C of Regulation No. 3, for combined Construction/Operating Permit issuance. Regulation No. 3, Part C, Section III.B.7 requires that facilities submit an application for a combined construction permit and operating permit on a standard application form supplied by the Division. Since the Division currently has no forms for this procedure, your October 30, 2020 letter and attachments (APEN, flow diagram and emission calculation methodology) fulfill this requirement. Fees Colorado Regulation No. 3, Part A Section VI.A.1 requires the division to charge fees to "...recover the direct and indirect costs incurred by the Division in processing permit applications, issuing permits, and in conducting a compliance monitoring and enforcement program. Such fees shall apply without regards to whether a permit is issued, denied, withdrawn, or revoked." With respect to processing applications and issuing permits, fees will be charged for time spent reviewing the application and drafting the permit and associated basis document, including researching regulatory and technical issues related to the application and permit draft as applicable. Chargeable time also includes peer and supervisor review of drafts, as well as time spent by permit engineers and division management in meetings, phone calls, and responding to emaits. The hourly permit processing fee is $108.12 beginning on July 1, 2020. Please see https://www.colorado.aov/pacific/cdphe/emissions- and-permitting-fees for additional information about fees. ,,- CAF c0-4;-- 4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe a•y 4,, .,r tai Jared Polis,Governor I Jill Hunsaker Ryan,MPH, Executive Director ,, ,,,, %* Please note that the Division utilizes a quarterly billing system for all operating permits. The bills you receive will reflect chargeable time for the previous quarter. The Colorado Legislature has directed the Division to inform sources if the time spent processing an application will exceed 30 hours. The Division has determined that the time required to process your application for renewal of the operating permit will exceed 30 hours. Based on our experience in processing operating permits, we estimate that the total time required to process your application will be between 25 and 100 hours. This letter fulfills the Division's obligation to inform you that the processing time for your operating permit renewal will exceed 30 hours and to provide you with an estimate of the processing time. Timeline Significant modifications are processed under the same time lines and procedures as new operating permits, including Public Comment and EPA review. Within sixty (60) days of receiving an application for a significant modification the Division must determine if the application is administratively complete. Under the provisions of Regulation No. 3, Part C, Section IV.C, the Division has 18 months from the receipt of a complete application in order to approve or disapprove the application. The 18 month clock starts on the date a complete application is submitted. Please note that you cannot institute the proposed modifications to your facility until the revised operating permit has been issued. Required Additional Information The Division has determined that the October 30, 2020 application is administratively complete. If during the technical review of your application, the Division determines that additional information is necessary to evaluate or take final action on this application, a request will be made in writing for the information and a reasonable deadline for response set. If you fail to provide the requested information or do not meet the deadline, the Division will be unable to continue with the processing and issuance of the modified permit (Regulation No. 3, Part C, Section IV.D). Please do not hesitate to contact me if you have any questions at 303-692-6332 or elie.chavez@state.co.us. Sincerely, cap Elie Chavez, P.E. Engineer, Operating Permit Unit Stationary Sources Program Air Pollution Control Division 11/4/2020 State.co.us Executive Branch Mail-Completeness Letter for Enterprise Sig Mod , STATE OF COLORADO -CDPHE, Elie<elie.chavez@state.co.us>.49 r Completeness Letter for Enterprise Sig Mod 1 message Chavez-CDPHE, Elie<elie.chavez@state.co.us> Wed, Nov 4, 2020 at 10:38 AM To: "Shankaran, Roshini"<RShankaran@dcpmidstream.com> Cc: "Chris Platt(chrisplatt@windriverenvironmental.com)"<chrisplatt@windriverenvironmental.com> Hi Roshini, Please find attached the completeness letter for the significant modification application addressing the Enterprise Compressor Station's compressor blowdowns(AIRS 076). Please let me know if you have any questions or need anything else! Thanks so much, Elie Chavez Permit Engineer Title V Operating Permit Unit Stationary Sources Program Air Pollution Control Division COLORADO :41Air Pollution Control Division Department of Public Health b Environment P 303.692.6332 4300 Cherry Creek Drive South, Denver, CO 80246-1530 elie.chavez@state.co.us I www.colorado.gov/cdphe/aped Are you curious about ground-level ozone in Colorado?Visit our ozone webpage to learn more. +m 123-0277 Sig Mod Completeness Letter 11-4-2020.pdf 67K https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permthid=thread-a%3Ar2666330076324572003&simpl=msg-a%3Ar-59539661... 1/1 RCVD 11/18/2020 (via email) 123-0277-076 Compressor Engine Blowdown Emissions-COMP-BD fr'�y t P! t°1 Enterprise Compressor Station 7 �PWE 103 DCP Operating Company,LP Inlet Gas Sampler Ga4Ou+vstituent. ' `;'(fb)lbmole), - (Vol%) (IbitbmoleGas)+ (Wt%)-, Corrected for HO VOCwt%=. 'VOC wt%+Buffer` EJC 11/19/2020 Helium 4.00 0.0000 0.00 0.00 -- -- -- Hydrogen 2.02 0.0000 0.00 0.00 -- -- -- Carbon Dioxide 44.01 2.4000 1.06 4.64 -- -- -- Nitrogen 28.00 0.3800 0.11 0.47 -- -- -- H2S 34.10 0.0000 0.00 0.00 -- -- -- Methane 16.04 72.0242 11.55 50.71 53.44 -- -- Ethane 30.07 13.8043 4.15 18.22 19.20 -- -- Propane 44.10 G.9'224 3.05 13.40 14.12 14.12% 15.53% i-Butane 58.12 0.8763 0.51 2.24 2.36 2.36% 2.59% n-Butane 58.12 2.18 78 1.27 5.58 5.88 5.88% 6.47% Isopentane 72.15 0.4758 0.34 1.51 1.59 1.59% 1.75% n-Pentane 72.15 0.5252 0.38 1.66 1.75 1.75% 1.93% Cyclopentane 70.13 0.0226 0.02 0.07 0.07 0.07% 0.08% n-Hexane 86.18 0.0868 0.07 0.33 0.35 0.35% 0.38% Cyclohexane 84.16 0.0191 0.02 0.07 0.07 0.07% 0.08% Other Hexanes 86.18 0.'1458 0.13 0.55 0.58 0.58% 0.64% Heptanes 100.20 0.0556 0.06 0.24 0.26 0.26% 0.28% Methylcyclohexane 98.19 0.0154 0.02 0.07 0.07 0.07% 0.08% 2,2,4 Trimethylpentane 114.23 0.0001 0.00 0.00 0.00 0.001% 0.001% Benzene 78.11 0.0134 0.01 0.05 0.05 0.05% 0.05% Toluene 92.14 0.0100 0.01 0.04 0.04 0.04% 0.05% Ethylbenzene 106.17 0.0006 0.00 0.00 0.00 0.003% 0.003% Xylenes 106.20 0.0028 0.00 0.01 0.01 0.01% 0.02% C8+ 114.23 0.0258 0.03 0.13 0.14 0.14% 0.15% Methanol 106.10 0.0060 0.01 0.03 0.03 0.03% 0.03% . .. .... Total 100,00 : 22.79 100.00 100.00 - 27.37% 30.11% Enterprise Inlet EGA Dated 8/12/2019 2 VOC wt%includes a 10%buffer to account for variation in future gas composition Gas Properties Gas Density' I 0.7692 Relative Density,Air 0.05769 lb/scf 3 Gas Density=Relative Density(9/22/2017 EGA)*Density of Air at EGA Temp/Pressure(0.075 lb/scf) Total Annual Mass Flow Volumetric Flow Potential Events Venting Vent Details lb/blowdown4 scf/blowdowns blowdowns/yr MMscf/yr tpy VOC lb/yr n-Hexane lb/yr Benzene lb/yr Toluene lb/yr Ethylbenzene lb/yr Xylenes lb/yr 2,2,4-TMP lb/yr McOH Engine C-238/P003 166.34141 2,883 63 0.18 1.64 41.50 5.81 5.11 0.35 1.65 0.06 3.53 Engine C-235/P-005 166.34141 2,883 63 0.18 1.64 41.50 5.81 5.11 0.35 1.65 0.06 3.53 Engine C-236/P-006 166 34141 2,883 63 0.18 1.64 41.50 5.81 5.11 0.35 1.65 0.06 3.53 Engine C-234/P-018 166.34141 2,883 63 0.18 1.64 41.50 5.81 5.11 0.35 1.65 0.06 3.53 Engine C-237 327 31540 5,674 63 0.36 3.23 81.67 11.43 10.06 0.70 3.25 0.12 6.95 Total 315 1.08 9.80 247.68 34.66 30.51 2.11 9.85 0.38 21.08 4Ib/blowdown mass flow estimate from VMGSim Model dated 8/20/2018,provided by Kyle Tivnan 5 Blowdown volume(scf/blowdown)=lb/blowdown(VMGSim Model)/Gas Density 6 VOC/HAP emissions(tons/yr)=scf/blowdown*1 lb-mol/379.5 scf*MW(lb/lb-mol)*Blowdowns/yr*VOC/HAP wt%*1 ton/2000 lb EMPA___C"V w_ a l EXTENDED NATURAL GAS ANALYSIS(*DHA) MAIN PAGE LEASE#: NAME/DESCRIP: ENTERPRISE BOOSTER PRE TEG PROJECT NO. : 201709092 ANALYSIS NO.: 05 COMPANY NAME: DCP MIDSTREAM ANALYSIS DATE: SEPTEMBER 26,2017 14:14 OFFICE/BRANCH: GREELEY,CO SAMPLE DATE : SEPTEMBER 22,2017 11:45 CUSTOMER REF: TO: PRODUCER : EFFECTIVE DATE: ***FIELD DATA*** SAMPLE CYCLE: SAMPLE TYPE: SPOT SAMPLE PRES.: 920 psig CYLINDER NO.: 1751 LAB PRES: psig SAMPLED BY : MATHEW PICKETT SAMPLE TEMP.: �f SAMPLING COMPANY:DCP AMBIENT TEMP.: of H2S BY STAIN TUBE: _ ppm . H2O BY STAIN TUBE: _ #/mmcf CO2 BY STAIN TUBE: _ Mol% FIELD COMMENTS: LAB COMMENTS: MOISTURE OBSERVED IN SAMPLE GPM @ GPM @ COMPONENT MOLE% MASS% 14.730 14.650 ' ALCOHOLS 0.0008 0.0021 HELIUM 0.00 0.00 --- -- HYDROGEN 1.23 0.11 --- --- OXYGEN/ARGON 0.00 0.00 --- --- NITROGEN 0.2300 0.2900 --- --- CARBON DIOXIDE 2.41 4.76 --- --- METHANE 72.43970 52.10160 --- --- ETHANE 13.2963 17.9248 3.5688 3.5494 PROPANE 5.9729 11.8083 1.6511 1.6421 I-BUTANE 0.8741 2.2778 0.2868 0.2852 N-BUTANE 1.9407 5.0572 0.6137 0.6104 I-PENTANE 0.5148 1.6635 0.1881 0.1871 N-PENTANE 0.5382 1.7409 0.1962 0.1951 HEXANES PLUS 0.5525 2.2638 0.2190 0.2180 TOTALS 100.00000 100.00000 6.7237 6.6873 BTEX COMPONENTS MOLE% WT% BTU @ 14.730 14.650 BENZENE 0.0197 0.0690 LOW NET DRY REAL: 1171.4/scf 1165.0/scf TOLUENE 0.0205 0.0847 NET WET REAL: 1151.0/scf 1144.6/scf ETHYLBENZENE 0.0005 0.0024 HIGH GROSS DRY REAL: 1289.5/scf 1282.5/scf XYLENES 0.0027 0.0128 GROSS WET REAL: 1267.1 /scf 1260.1 /scf TOTAL BTEX 0.0434 0.1689 NET DRY REAL: 19940.1 /lb 19831.8/lb GROSS DRY REAL: 21955.0/lb 21835.8/lb (CALC:GPA STD 2145&TP-17 @ 14.696&60 I') RELATIVE DENSIW AIR*1). 07692; '(DETAILED HYDROCARBON ANALYSIS/N.11993);ASTM D6730 COMPRESSIBILITY FACTOR : 0.99619 The data presented herein has been acquired by means of current analytical techniques and represents the judicious conclusion EMPACT Analytical Systems,Inc. Results of the analysis Mil he affected hs the sampling conditions,thercjhre,are only warranted through proper lab protocol. E:1r1PAC'T assumes no responsibility for interpretation or any consequences from application of the reported in foraration and is the.sole liability of the miser. The reproduction in any media of this reported information moe not he made.in portion or as a whole,without the written permission of F,'11P 1 CT Analytical,i stems,Inc. EMPACT Analytical Systems Inc. 365 S Main St Brighton,CO 80601 303-637-0150 ( t : EMPACT qtr .l1 /7Ily EXTENDED NATURAL GAS ANALYSIS(*DHA) GLYCALC INFORMATION PROJECT NO. : 201908082 ANALYSIS NO.: 01 COMPANY NAME: DCP MIDSTREAM ANALYSIS DATE: AUGUST 15,2019 07:36 ACCOUNT NO. : PO:0000492677 RC-G033 SAMPLE DATE : AUGUST 12,2019 11:55 PRODUCER CYLINDER NO. : 1750 LEASE NO. : SAMPLED BY : CHANDLER COLE NAME/DESCRIP: ENTERPRISE PRE TEG INLET ***FIELD DATA*** SAMPLE TEMP.: 42 SAMPLE PRES.: 920 AMBIENT TEMP.: H2S BY STAIN TUBE: - ppm COMMENTS SPOT cornronet J'Aole% Wt% Helium 0.00 0.00 Hydrogen 0.00 0.00 Carbon Dioxide 2.40 4.64 Nitrogen 0.38 0.47 Methane 72.02420 50.71560 Ethane 13.8043 18.2190 Propane 6.9224 13.3981 Isobutane 0.8763 2.2355 n-Butane 2.1878 5.5814 Isopentane 0.4758 1.5068 n-Pentane 0.5252 1.6632 Cyclopentane 0.0226 0.0696 n-Hexane 0.0868 0.3283 Cyclohexane 0.0191 0.0705 Other Hexanes 0.1458 0.5488 Heptanes 0.0556 0.2429 Methylcyclohexane 0.0154 0.0664 2,2,4 Trimethylpentane 0.0001 0.0005 Benzene 0.0134 0.0460 Toluene 0.0100 0.0404 Ethylbenzene 0.0006 0.0028 Xylenes 0.0028 0.0129 C8.ueaet es 0 0258 0 1329 Subtotal 99.99400 99.99160 Oxygen/Argon 0.00 0.00 Alcohols 0.0060 0.0084 Total 100.00000 100.00000 BDL-Below Detection Limit. The H2S LOS has a detection limit of 0.25 ppm.A_(an uderscore)indicates there was no tube pulled for II2S. Ike data prea.nr-d herein hot been acquired i_means at current anala rechni,+cs.narepareni'the galleSant cane.'uainn hell'4(-t;inalytiat Sstems,lne. Results Of the analysis 10,2 l e /fe..4 d b,the sump/6w caa.J iin.,,there.__r e.are an r warranted rbr a,eb proper lab',ralo 1. l i19f./ T as:cumes a s respansibilits or interpretatitrn ci any carreegaorna<^s fan applicaniau of the_reported eat-u,a_nti.r_r an<.cc the soh,ta_aae,,.t,r�the arser. I.he reprartaciian in any media of thi, erpurred infiun tatirn may not he made,in naafi t o„r ac a rr t,.c, s it..a In:,,rrttr,a,, aawxaaa,i t_iIP.tl.T snary Lira;,system_¢.toe. EMPACT Analytical Systems Inc. 365 S Main St Brighton,CO 80601 303-637-0150 11/23/2020 State.co.us Executive Branch Mail-DCP Enterprise Blowdown Mod STATE OF COLORADO Chavez-CDPHE, Elie<elie.chavez@state.co.us> DCP Enterprise Blowdown Mod Shankaran, Roshini <RShankaran@dcpmidstream.com> Wed, Nov 18, 2020 at 4:20 PM To: "Chavez-CDPHE, Elie"<elie.chavez@state.co.us>, "Chris Platt(chrisplatt@windriverenvironmental.com)" <chrisplatt@windriverenvironmental.com> Hi Elie, I think this is the final outstanding email on Enterprise. Please see responses to your questions in the email below, and also attached are revised calculations. Thanks again for getting Enterprise to the finish line! 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 Midstream From: Chavez-CDPHE, Elie<elie.chavez@state.co.us> Sent: Tuesday, November 3, 2020 2:48 PM To: Chris Platt(chrisplatt@windriverenvironmentalcom)<chrisplatt@windriverenvironmental.com>; Shankaran, Roshini <RShankaran@dcpmidstream.com> Subject: [EXTERNAL]DCP Enterprise Blowdown Mod *** WARNING: This email originated from outside of DCP Midstream. Do not click links or open attachments unless you recognize the sender and know the content is safe. Safety and-security https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1683742153406853655&simpl=msg-f%3A16837421534... 1/2 11/23/2020 State.co.us Executive Branch Mail-DCP Enterprise Blowdown Mod starts with each of us. *** Hi Chris and Roshini, I've gone through the Enterprise mod and it looks good to me. I'll have to wait for the physical copy to actually get you a completeness letter, but it's a complete application for my purposes. I think the calculation method is totally fine, but I am calculating slightly higher emissions. This could very well be from rounding, but I wanted to follow up on a couple of things just to make sure: • The calculated weight%adds up to 102.3% and I think that might be where the difference in calculations are coming from. I'm wondering if it's the calculated molecular weight- I'm getting closer to 22.8 Ib/Ibmol. Normally I wouldn't care about the molecular weight since it's so close, but I think the total weight% should be 100, so I wanted to bring it up just in case. You are correct, there was a slight issue with the summation of the individual component MW's in the emission calculations. The corrected value is 22.8 Ib/Ib-mol, matching your calculation. In order to balance out the slight increase in VOC and HAP emissions resulting from this correction, DCP has decreased the number of requested events/compressor from 65/compressor to 63/compressor. Please see the attached revised emission calculations for details and the final proposes VOC/HAP emission limits. • Just to confirm-are the lb/blowdown emission factors the same as what we had for 19WE0094 (327.32 lb for C- 237 and 166.34 lb/blowdown for all others)? Correct. The final PTE estimates for this source are derived from the same modeled lb/event mass-flow emission values used for the original calculations provided with the initial CP application. These values were converted into scf/event volumetric-flow emission factors using the density information taken from the 2017 EGA. Just to make sure there is no confusion, the indicated Ib/blowdown mass- flow values are the modeled total lbs of expressed gas from each blowdown event, and won't be used for compliance demonstrations moving forwards. The provided scf/blowdown factors will be used for these emission calculations, coupled with the MW and wt% speciation data from sampling information, as detailed in the current draft of the Title V permit for this facility. • The 8/12/2019 EGA lists a gas density of 0.06003 lb/scf, however, in the APEN,the density is listed as 0.0577. Was the density corrected for something and if so, can I please get that calculation? In order to calculate as conservative PTE estimates as possible, DCP used the density from the original 2017 EGA to convert the lb/event baseline values. The value used, 0.0577, was calculated by multiplying the Relative Density from the 2017 EGA (0.7692) by the density of air at STP (0.075 Ib/scf). This slightly lower density estimate provides slightly higher scf/event emission factors, and we wanted to make sure we accounted for potential variability in future EGAs. Please see the attached revised emission calculations for details. • I agree with the calculated vented throughput of 1.12 MMScf/year, however, it looks like the APEN is requesting 1.22 MMScf. Just wanted to confirm this is a typo- I can redline no problem. The accurate value was 1.12 MMscf/yr. The value of 1.22 MMscf/yr on the APEN appears to be a typo. Please note that the final value, after the corrections identified in item#1 above, will be 1.08 MMscf/yr(please see revised emission calcs for details). Thank you for redlining this for us! Let me know if you have any questions or need any clarification on the above! [Quoted text hidden] 2020.11.10 -Revised COMB-BD Emission Calculations.pdf 304K https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1683742153406853655&simpl=msg-f%3A16837421534... 2/2 11/19/2020 Modification Application 123-0277 95OPWE103 DCP Midstream &EP- Received 11/19/2020 370 17th Street,Suite 2500 Denver,CO 80202 Midstream. EJC 303-605-2029 November 18, 2020 Sent via UPS Tracking#: 1Z F46 915 01 9693 2368 Mrs. Elie Chavez Colorado Department of Public Health and Environment Air Pollution Control Division 4300 Cherry Creek Drive South,APCD-SS-B 1 Denver, CO 80246-1530 Re: DCP Operating Company, LP; Enterprise Compressor Station (123/0277) Title V Permit 95OPWE103 Significant Modification - Construction Permit (19WE0492) Incorporation Application Dear Mrs. Chavez: DCP Operating Company, LP (DCP) is submitting the attached application for the Enterprise Compressor Station, located in SWSW Section 30, Township 3N, Range 63W, Weld County, Colorado. DCP is requesting that Construction Permit 19WE0492 be incorporated into the active Title V Permit covering this facility, 95OPWE103. Construction Permit 19WE0492 was issued November 19, 2019. Per the requirements detailed in Colorado Regulation 3, Part C, Section III.B.2., an application to incorporate construction permit requirements into an active Title V permit is due within 12 months of issuance of the construction permit. A draft Title V renewal permit incorporating the requirements included in construction permit 19WE0492 has already been developed by the Division and is currently with DCP for review.The enclosed application serves to satisfy the above Regulation 3 requirement to officially request this incorporation. Additionally,please note that unit D-3,AIRS point 077 has not yet been constructed at this facility. DCP will provide a Notice of Startup, as well as the required self-certification documentation per the schedules provided in construction permit 19WE0492. The application includes the following attachments: A. Most Recent APEN Submittals—AIRS 063, 066, and 077 B. Title V Operating Permit Application Form—OP-50 C. Title V Operating Permit Application Form—OP-202 D. Title V Operating Permit Application Form —OP-300 Series Forms E. Title V Operating Permit Application Form—OP-400 Series Forms F. Form APCD-102 If you have ally questions or require any additional information about this application, please feel free to contact me at (303) 605-2039 or rshankaran@dcpmidstream.com. Sincerely, DCP Operating Company, LP Roshini Shankaran Senior Environmental Engineer Enclosures Attachment A Previous APENs AIRS 063 (P013 Condensate Storage) AIRS 066 (P016 Condensate Truck Loadout) AIRS 077 (D-3 145 MMscfd TEG Dehy) Enterprise Compressor Station Condensate Storage Tank(s) APEN A CDPHE ►" Form APCD-205 NAY 1 7 2019 CO Air Pollutant Emission Notice (APEN) and 'Po; i Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for tanks that store condensate associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source(e.g. crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-2OO)is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/pacific/cdphe/air-permits. 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: G 2 AIRS ID Number: 123 /0277 / 063 [Lease blank nie5 APCD has?lre4id, t.si r d 1 perm' an,i RS 9D Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location: Site Location SWSW Section 30, T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: (include zip code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 E-Mail Address2: rshankaran@dcpmidstream.com ' Use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. 359 w® COLORADO Form APCD 205 Condensate Stora;e 7anktsl APEN pe,'sion 3 2Qt9 1 i/S� Permit Number: AIRS ID Number: 123 /0277/063 c' .'c .°CD bz;already dss'g1 d a poi I .<`.d =R`ID; _.. Section 2 - Requested Action O NEW permit OR newly-reported emission source • Request coverage under traditional construction permit ▪ Request coverage under a General Permit ❑ GP01 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of$312.50 must be submitted along with the APEN filing fee. -OR- • MODIFICATION to existing permit(check each box below that applies) ❑ Change in equipment ❑ Change company name3 O Change permit limit ❑ Transfer of ownership" ❑ Other(describe below) -OR- ❑ APEN submittal for update only(Note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- Q APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info E Notes: Increase throughput, no change in emission factors 3 For company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted. 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: stabilized condensate tanks Company equipment Identification No. (optional): P013 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Storage tank(s) located at: O Exploration&Production(E&P)site 0 Midstream or Downstream (non E&P)site Will this equipment be operated in any NAAQS nonattainment area? Q Yes O No Are Flash Emissions anticipated from these storage tanks? O Yes ❑ No Is the actual annual average hydrocarbon liquid throughput≥ 500 bbl/day? O Yes Q No If"yes", identify the stock tank gas-to-oil ratio: m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) ❑ Yes ❑ No 805 series rules?If so, submit Form APCD-105. Are you requesting≥6 ton/yr VOC emissions(per storage tank), or are uncontrolled actual ❑ Yes ❑ No emissions≥6 ton/yr(per storage tank)? COLORADO Form APCI 2'35 Ccndensa?e Storage Tanks) APEN - Revision 3 2019 2 I ,E,y^M, Permit Number: AIRS ID Number: 123 /0277/063 APCD ti;i air= dI _53 ff,C all. ,3S!Di Section 4 - Storage Tank(s) Information Actual Annual Amount Requested Annual Permit Limits (bbi/year) (bbl/year) I Condensate Throughput: 54,165 202.848 Frain wile year rs the actual onnuc) armmnt' 2018 Average API gravity of sales oil: 65.4 degrees RVP of sales oil: 10 Tank design: v❑Fixed roof ❑ Internal floating roof O External floating roof Storage #of Liquid Manifold Storage Total Volume of Installation Date of Most Date of First Tank ID Vessels in Storage Tank Storage Tank Recent Storage Vessel in Production (bbl) Storage Tank(month/year) (month/year) P013 8 2,400 1993 1993 Wells Serviced by this Storage Tank or Tank Battery6(E&P Sites Only) API Number Name of Well Newly Reported Well O . . O O O O 5 Requested values will become permit limitations. Requested limit(s)should consider future growth. 6 The E&P Storage Tank APEN Addendum(Form APCD-212)should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 /-104.4877 Operator Stack Discharge Height Above Temp. Flow Rate Velocity ID No. Ground Level(feet) (°F) (ACFM) (ft/sec) P013 15 Indicate the direction of the stack outlet: (check one) 0 Upward O Downward ❑Upward with obstructing raincap ❑ Horizontal O Other(describe): Indicate the stack opening and size: (check one) Circular Interior stack diameter(inches): ❑Square/rectangle Interior stack width(inches): Interior stack depth(inches): ❑Other(describe): COLORADO Form APCD 205 CondEn;ate Storage Tank(s) APEN - Revision 3.`2019 3 I . V Permit Number: AIRS ID Number: 123 /0277/063 ai3i-:F!;i£,..,A7--CD r,.} ply ei5it=*' Haim = 1„ v` Gj Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions,and skip to the next section, Pollutants Controlled: Vapor Size: Make/Model: ❑ Recovery Unit (VRU): Requested Control Efficiency: VRU Downtime or Bypassed(emissions vented): Pollutants Controlled: VOC, HAPs Rating: NA MMBtu/hr Type: Enclosed Combustor Make/Model: LEED Combustion ® Requested Control Efficiency: 95 Device: Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: NA Waste Gas Heat Content: NA Btu/scf Constant Pilot Light: 0 Yes 0 No Pilot Burner Rating: NA MMBtu/hr Description of the closed loop system: 0 Closed Loop System Pollutants Controlled: ❑ Other: Description: Control Efficiency Requested: Section 7 - Gas/Liquids Separation Technology Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? psig Describe the separation process between the well and the storage tanks: 4 ANT COLORADO Form APCG 205 Condensate Slam e Tanks) APEN • ReE:ision 3.'2019' su'^ , Permit Number: AIRS ID Number: 123 /0277/063 [te..r .irk ,.l °as APCD'has ?d a p . n .,S :0) Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form7. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined)control efficiency(%reduction): Overall Requested Control Pollutant Description of Control Method(s) Efficiency (%reduction in emissions) VOC Enclosed Combustor 95% NOx CO HAPs Enclosed Combustor 95% Other: From what year is the following reported actual annual'emissions data' 201 8 Criteria Pollutant Emissions Inventory Emission Factor? Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Pollutant Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis Units (AP-42, Emissions Emissions8 Emissions Emissions Mfg.,etc.) (tons/year) (tons/year) (tons/year) (tons/year) VOC 0.332 Ib/bbl Tanks 4.0.9d 8.99 0.45 33.67 1.68 NOx CO Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions Chemical Name Abstract Source Uncontrolled Controlled Service(CAS) Uncontrolled Units 8 Number Basis (AP-42, Emissions Emissions Mfg.,etc.) (pounds/year) (pounds/year) Benzene 71432 4.00E-03 Ib/bbl Eng, Est. 217 11 Toluene 108883 1.50E-02 lb/bbl Eng.Est. 812 41 Ethylbenzene 100414 1.00E-03 Ib/bbl Eng. Est. 54 3 Xylene 1330207 1.10E-02 Ib/bbl Eng,Est, 596 30 n-Hexane 110543 3.20E-02 lb/bbl Eng, Est. 1,733 87 2,2,4- 540841 Trimethylpentane 5 Requested values will become permit limitations.Requested limit(s)should consider future growth. 7 Attach condensate liquid laboratory analysis,stack test results,and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14.03. 8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. Av coLoRADo Form APCC Z 5 Condensate Storage Tanks) APEN - Revision 3='2019 5 Permit Number: AIRS ID Number: 123 10277/063 [..ca., CE ,,, a 112'1` .APCD ha-.a'lit..a, acs ,e.:a a'.i:?IRS's j Section 9 - 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 GP01 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. / 7 Signature of Legally Authorized Person(not a vendor or consultant) Date Marie Cameron Senior Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: Draft permit prior to issuance 0 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 5191.13 and the General Permit For more information or assistance call: registration fee of$312.50, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 or(303)692.3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692.3150 Denver,CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https:fiwww.colerado.Qov/cdpheiapcd Aviv COLORADO Form APCD-2J5 Condensate Storage Tan'Fisj APEN - Pevi;icrr 3`2Ji9 6 I `„ 7:, ;, MAY 1 7 2019 c o P H E Hydrocarbon Liquid Loading APEN ' ` Wit► Form APCD-208 CO If Air Pollutant Emission Notice (APEN) and Application for Construction Permit Alt sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for hydrocarbon liquid loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source(e.g. amine sweetening unit, glycol dehydration unit, condensate storage tanks, 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/aped. 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: oq w E 0 4 4 2 AIRS ID Number: 123 / 0277 / 066 [Leave black uniess APCD has already a- ,fined a permit "and AIRS ID] Section 1 - Administrative Information Company Name': DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30, T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: 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 the APCD via e-mail to the address provided. 399697 AvCOLORADO Form APCD-2C8 Hydrocarbon Liquid Loading APEN - Re,nsian 3/2019 1 I ° .,.'A,", Permit Number: AIRS ID Number: 123 /0277/066 (i a.,= bI.. K_.rt,ss A,FC€1 <, a= a y z.c; 7 pyr ,t a-ci A,RS Section 2 - Requested Action ❑ NEW permit OR newly-reported emission source O Request coverage under construction permit ❑ Request coverage under General Permit GP07 If General Permit coverage is requested,the General Permit registration fee of$312.50 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 ❑ Change permit limit O Transfer of ownership' ❑ ,Other(describe below) -OR- ❑ APEN submittal for update only(Note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- El Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info Et Notes: Increase throughput, no change in emission factor 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106)must be submitted, 4 For transfer of ownership,a completed Transfer ce Ownership Certification Form (Form APCD-104)must be submitted. Section 3 - General Information General description of equipment and purpose: Loadout of stabilized condensate to trucks Company equipment Identification No. (optional): P016 For existing sources, operation began on: 1993 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? i❑ Yes O No Is this equipment located at a stationary source that is considered a Major Source of(HAP) Yes ❑ No emissions? Does this source load gasoline into transport vehicles? ❑ Yes ✓❑ No Is this source located at an oil and gas exploration and production site? ❑ Yes No If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual ❑ Yes O No average? Does this source splash fill less than 6750 bbl of condensate per year? ❑ Yes ❑ No Does this source submerge fill less than 16308 bbl of condensate per year? ❑ Yes ❑ No c0LORAwO Form ARCD-2CS Hydrocarbon Liquid Loading APEN Rev Sinn 3'20'9 2 I MI" Permit Number: AIRS ID Number: 123 /0277/066 _...�[_ k,,.,F r`C ' p t d ui r KS 1?D Section 4 - Process Equipment Information Product Loaded: 0 Condensate ❑ Crude Oil O Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded5: 202,848 bbl/year Actual Volume Loaded: 54,165 bbl/year This product is loaded from tanks at this facility into: tank trucks (e.g. "rail tank cars"or"tank trucks") If site specific emission factor is used to calculate emissions,complete the following: Average temperature of 58.1 6 Saturation Factor: 0.6 bulk liquid loading: F True Vapor Pressure: Psia®60 'F Molecular weight of 66.00 lb/lb-mot 4.65 displaced vapors: If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: bbl/year Actual Volume Loaded: bbl/year Product Density: tb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume: ft3/truckload 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. p co4o8ADo Form APCD-2108 Hydrocarbon Liquid Loading APEN Revision 3-2019 3 I � � , II Permit Number: AIRS ID Number: 123 /0277/066 [Lea,,'ti.,r)L ur ..55 A:=CD ',red r ;;rid AlP3 ID Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTMM) 40.191 /-104.4877 Discharge Height Above operator Temp. Flow Rate Velocity Ground Level Stack ID No. , (IF) - ; (ACFM) fft/sec) (feet) P016 Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Downward 0 Upward with obstructing raincap ❑ Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) ❑Circular Interior stack diameter(inches): ❑Other(describe): Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. 0 Loading occurs using a vapor balance system: Requested Control Efficiency: Used for control of: VOC, HAPs Rating: NA MMBtu/hr Type: Enclosed Combustor Make/Model:LEED ❑ Combustion Device: Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: NA °F Waste Gas Heat Content: NA Btu/scf Constant Pilot Light: 0 Yes ❑ No Pilot Burner Rating: NA MMBtu/hr Pollutants Controlled: ❑ Other: Description: Requested Control Efficiency: COLORADO Form APCD 208 Hydrocarbon Liquid Loading APEN Revisor 3`2019 4 ( °;�. Permit Number: AIRS ID Number: 123 /0277/066 w:nl .s 6PC..1 f _ a ._ AIRS ID] Section 7- Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall(or combined)control efficiency(%reduction): Overall Requested Pollutant Description of Control Method(s) Control Efficiency (%reduction in emissions) PM SOx NOx CO VOC Enclosed Combustor 95% HAPs Enclosed Combustor 95% • Other: ❑ Using State Emission Factors(Required for GP07) VOC Benzene n•Hexane ❑Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL ❑Crude 0.104 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported cctuci crnuct emissions data 2018 Criteria Pollutant Emissions Inventory • Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Pollutant Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Basis Units (AP-42, Emissions Emissions6 Emissions Emissions Mfg.,etc-) (tons/year) (tons/year) (tons/year) (tons/year) PM Sox NO. CO VOC 0.186 lb/bbl AP-42 5.03 0.25 18.83 0,94 Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions Abstract Chemical Name Service CAS Uncontrolled Source Uncontrolled Controlled ( ) Basis Units (AP•42, Emissions Emissions6 Number Mfg.,etc.) (pounds/year) (pounds/year) Benzene 71432 5.16E-04 Ib/bbl Eng.Est. 28 1 Toluene 108883 6.34E-04 Ib/bbl Eng.Est. 34 2 Ethylbenzene 100414 1.78E-05 lb/bbl Eng.Est. 1 0 Xylene 1330207 9.62E-05 Ib/bbl Eng.Est. 5 0 n-Hexane 110543 3.62E-03 lb/bbl Eng.Est. 196 10 2,2,4- Trimethyipentane 540841 Other: 5 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported.If source has not yet started operating,leave blank. coloRAoo Form APCD 208 Hydrocarbon Liquid Loading APEN Revision 3.`2019 5 *. `Mn , Permit Number: AIRS ID Number: 123 /0277/066 1Lea.c ^1.'K; 1:.<„APCD ha%;3'r .,,;,7 SI-33. :?perm i "i--0 A;R I]%. 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 GP07, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP07. / ,'-'y t Signature of Legally Authorized Person (not a vendor or consultant) Date Marie Cameron Senior Environmental Engineer Name(print) Title Check the appropriate box to request a copy of the: 0 Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type,etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with$191.13 and the General Permit For more information or assistance call: registration fee of$312.50, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 or(303)692-3148 Air Pollution Control Division APCD-SS-B1 APCD Main Phone Number 4300 Cherry Creek Drive South (303)692.3150 Denver, CO 80246-1530 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment https:I/www.colorado,gov.cdphe/aped COLORADO Form AFC -208 Hydrocarbon Liquid Lo.rlding APEN Reis' n 3 20196 I �� • MM 1 7 2019 Glycol Dehydration Unit APEN ..1, Form APGD-202 >F. c Air Pollutant Emission Notice (APEN) and Application for Construction Permit _ Alt sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs wilt be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or tacks payment for the filing fee. The re-submittal will require payment for a new filing fee, This APEN is to be used for glycol dehydration(dehy)units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source(e.g. amine sweetening unit, hydrocarbon Liquid loading,condensate storage tanks,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 Ar Pollution Control Division(APCD)website at:www.coiorado.govfcdphelapcd. , 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: I01 J O 4 AIRS ID Number: 123 / 0277 / 0-11 [Leave blank unless APCD has already assigned a permit#and AIRS IDI Section 1 - Administrative Information Company Namei: DCP Operating Company, LP Site Name: Enterprise Compressor Station Site Location Site Location: SWSW Section 30, T3N, R63W County: Weld NAICS or SIC Code: 4922 Mailing Address: (Include Zip Code) 370 17th Street, Suite 2500 Denver, CO 80202 Contact Person: Roshini Shankaran Phone Number: 303-605-2039 E-Mail Address': rshankaran@dcpmiidstream.com i 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 wilt be issued by the APCD via e-mail to the address provided. 399625 COLORADO Form APCD-202 - Gtycot Dehydration Unit APEN - Revision 3/2019 1 I r;=,=, Permit Number: AIRS ID Number: 123/02771 ni<ink tint.ss='aCD c is a:E.Nddy ass/'„i,nc1 A 7ennct 4 and AIRS ID] Section 2 - Requested Action NEW permit OR newly-reported emission source -OR- ❑ MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit • Change permit limit O Transfer of ownership4 O Other(describe below) -OR- ❑ APEN submittal for update only (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& Notes: 3 For company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted. 4 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 Company equipment Identification No. (optional): D-3 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: TBD Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source hours/day days/week weeks/year Operation: Will this equipment be operated in any NAAQS Yes El No nonattainment area? ❑✓ Is this unit located at a stationary source that is consideredEl Yes ❑ No a Major Source of(HAP) Emissions? t== COLORADO Form APCD•2O2 Glycol Dehydration Unit APEN - Revision 3/2019 2 I vs .u. Permit Number: AIRS ID Number: 123/ozn I €tamp entess AP(P if,s at,cad/tee ,ned a permit at and AIRS IDI Section 4 - Dehydration Unit Equipment Information Manufacturer: TBD Model Number: TBD Dehydrator Serial Number: TBD Reboiter Rating: 1.5 MMBTU/hr Glycot Used: ❑ Ethylene Glycol(EG) O DiEthytene Glycol(DEG) ❑ TriEthytene Glycol(TEG) Glycol Pump Drive: ❑ Electric O Gas If Gas, injection pump ratio: / Acfm/gpm Pump Make and Model: FMC Triplex #of pumps: 2 (1 P+1 B) Glycol Recirculation rate(gal/min): Max: 25.0 Requested: 25.0 Lean Glycol Water Content: 1.0 Wt.% Design Capacity: 145 MMSCF/day Dehydrator Gas Throughput: Requested5: 52,925 MMSCF/year Actual: "` MMSCF/year Inlet Gas: Pressure: 1,100 psig Temperature: 115 .F Water Content: Wet Gas: tb/MMSCF ® Saturated Dry gas: 5.0 lb/MMSCF Flash Tank: Pressure: 50 psig Temperature: 140 `F ❑ NA Cold Separator: Pressure: psig Temperature: 'F 0 NA Stripping Gas: (check one) 0 None O Flash Gas ❑Dry Gas O Nitrogen Flow Rate: scfm Additional Required Information: Ei Attach a Process Flow Diagram Q Attach GRI-GLYCaIc 4.0 Input Report&Aggregate Report(or equivalent simulation report/test results) ❑✓ Attach the extended gas analysis(including BTEX& n-Hexane, temperature,and pressure) 5 Requested values wilt become permit limitations. Requested limit(s)should consider future process growth. W COLORADO Form APCD-202 Gtycal Dehydration Unit APEN Revision 3/2019 3 I :=1;11V.,,.. ., Permit Number: AIRS ID Number: 12310277/ [Leave blank unless APCD has already assigned a permit and AIRS iD Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.191 /-104.4877 Operator Discharge Height p Temp. Flow Rate Velocity Stack ID No. Above Ground Level ( • F) (ACM) (ft/sec) (feet) ECD-1 25.0 Indicate the direction of the stack outlet: (check one) Q Upward ❑Downward ❑Upward with obstructing raincap ❑Horizontal ❑Other(describe): Indicate the stack opening and size: (check one) ['Circular Interior stack diameter(inches): 36.0 ❑Square/rectangle Interior stack width (inches): Interior stack depth(inches): ❑Other(describe): ECD eel ahcasttun device used Inc still scut cortri al has a 1,0'to annual dekw•utinaw for maintenance and repairs. Still vent emissions will vent to atnausphert during periods of ECD dewutime, Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions,and skip to the next section. , Used for control of: 0 Condenser: Type: Make/Model: Maximum Temp: °F Average Temp: °F Requested Control Efficiency: Used for control of: Flash Tank vent stream VRU: Size: NA Make/Model: TBD Requested Control Efficiency: 100 VRU Downtime or Bypassed: 5 Used for control of: still Vent stream Rating: NA MMBtu/hr Type: Enclosed Combustor Make/Model:LEED/ L30-0018-00 ❑ Combustion Device: Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: NA °F Waste Gas Heat Content: 1,500 Btu/scf Constant Pilot Light: ✓❑ Yes 0 No Pilot Burner Rating: 0.11 MMBtu/hr Closed Used for control of: 0 Loop Description: System: System Downtime: Used for control of: Flash Tank during 5%annual VRU downtime ❑✓ Other: Description: Enclosed Combustor Requested Control Efficiency: 95 COLORADO Form APCD-202 Glycol Dehydration Unit APEN - Revision 3/2019 4 I > Permit Number: AIRS ID Number: 123/0277/ (Leave Nark mites,AD(=i)has true=slid assi;nwd poi anti AIRS ID] Section 7- Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall(or combined)control efficiency(%reduction): Overall Requested Pollutant Description of Control Method(s) Control Efficiency (0 reduction in emissions) PM SO. NO. CO VOC Vapor Recovery Unit t Enclosed Combustor 100%/95% FIAPs Vapor Recovery Unit/Enclosed Combustor 100%/95% Other: From what year is the fo;towirtg.reported actual annual emissions data' NA Criteria Pollutant Emissions inventory Requested Annual Permit Emission Factor Actual Annual Emissions } 5 Pollutant Emission Limit(s) Uncontrolled Source Uncontrolled Controlled Uncontrolled Controlled Baroll Units (AP-42, Emissions Emissions6 Emissions Emissions s Mfg-,etc-) (tons/year) (tons/year) (tons/year) (tons/year) PM SOX NOx 0.068 Ib/MMBtu AP-42 -- _ -4752-L. ( Liti CO 0.31 Ib/MMBtu AP-42 — — '6.74" ,6- VOC 22.96 lb/MMscf GLYCalc -- ,64 AP Emissions ions represent Potential to Emit for this proposed source ti . 15.16 Non-Criteria Reportable Pollutant Emissions Inventory Chemical Emission Factor Actual Annual Emissions Abstract Chemical Name Source Uncontrolled Controlled Service(CAS) Uncontrolled Units 6 Number Basis (AP 42, Emissions Emissions Mfg.,etc,) (poundslyear) (pounds/year) Benzene 71432 2.52 lb/MMscf GLYCalc 133,283 7,773 Toluene 108883 3.77 Ib/MMscf GLYCalc 199,612 11,751 Ethylbenzene 100414 0.12 Ib/MMscf GLYCalc 6,227 369 Xylene 1330207 0.87 lb/MMscf GLYCalc 45,786 2,725 n-Hexane 110543 0.47 Ib/MMscf GLYCalc -24,842, 85* 74,014 8 Trimethylpentane 540841 0.0003 Ib/MMscf GLYCalc 17 1 Other: 67561 (Methanol) 0.003 lb/MMscf Eng,Est, 159 5 5 Requested values will become permit limitations.Requested timit(s)should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported.If source has not yet started operating,leave blank. COLORADO Form APCD-202 Gtycot Dehydration Unit ADEN - Revision 3/2019 5 I co Permit Number: AIRS ID Number: 123/0277/ [ vavf tai r unh:5s APCD has already assigned a pt+rnut 'and AIRS IDl Section 8 -Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. Signature of Legally Authorized Person(not a vendor or consultant) Date Marie Cameron Senior Environmental Engineer Name (print) Title Check the appropriate box to request a copy of the: Draft permit prior to issuance D Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with$191.13 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303)692.3175 or(303)692-3148 APCD-SS-B1 4300 Cherry Creek Drive South APCD Main Phone Number Denver, CO 80246-1530 (303)692-3150 Make check payable to: Or visit the APCD website at: Colorado Department of Public Health and Environment httns://;rrwa.colorado,,ov/cdohe/apcd COLORADO Form APCD-202 Glycol Dehydration Unit APEN - Revision 3/2019 6 I M=, Attachment B Title V Operating Permit Form—OP-50 Enterprise Compressor Station COLORADO FormOP-50 Mr Pollution Control Division D:iwrvm)Putt lic lu&En vrrtx=•re.,r.t Title V Operating Permit Application Form This form must be included with any application submittal to the Title V Operating Permit Unit Title V Operating 95OPWE103 Plant AIRS ID 123 - 0277 Permit Number: Number: 1. Instructions Included on the Colorado Air Pollution Control Division Website is an instruction sheet (Form OP-50A) for this application form. Refer to the instruction sheet or contact the Division with questions. Attach a cover letter describing the purpose of the application package if more room is needed. Any form with missing information may be determined administratively incomplete and may result in inability to grant the application shield of Regulation No. 3, Part C, Section II.B. Note that if using copy and paste; the applicant must paste as plain text. See "General Instructions" document for more details. 2. Permit Application Type (check all that apply) ❑ Initial ❑ Renewal - Identify any requested changes below or in a cover letter. El Significant Modification ] Administrative Modification (e.g. transfer of ownership, correct typographical error, etc.) ❑ Minor Modification - The Minor Modification worksheet (Form OP-201) must also be completed if a source wishes to use the procedures under Colorado Regulation No. 3, Part C, Section X. ❑ Notification of Construction Permit Exempt ❑ Title V Billing Contact Update Unit (APCD PS Memo 09-01, Scenario#7) ❑ Supplemental Information (describe): ❑ Responsible Official Update ❑ Other (describe): 1 ,, . 3. General Description - Include brief description describing the purpose of the application package. If more detail is needed, provide in cover letter. General This application is being submitted to officially request the incorporation of individual Description construction permit 19WE0492 into the active Title V Operating Permit for this facility of package (95OPWE103) Form Revised March 2020 Page 11 of 3 Department a Public H, th b Enri+onment COLORADO Form OP-50 'e Air Pollution Control Division N trt nrl'- (}k alts h E rex.^Krt 4. Additional Information A. Initial and Renewal Applications El Check this box if you are submitting an initial or renewal application. For all other application types, proceed to Section 4.B. If you are submitting an initial or renewal application, provide the application due date. See Colorado PS- Memo 09-01 for help with Title V Operating Permit application due dates. Application Due Date: F c'r 1 n . Basis for Application Due Date (Initial Permits Only): c _ k enter B. APEN Attachments Enclose a copy of the most current complete Air Pollution Emission Notice(s) (APENs) on file with the Division. New/revised APENs are required if the facility is requesting a modification that requires a new APEN or changes information on a previously submitted APEN. ❑ New or Revised APENs have been included with this submittal (filing fees must be included) • Required - Copies of all applicable APENs have been included (no filing fees are needed for these APEN copies). C. Confidential/Trade Secret Information Check the following box if any confidential/trade secret information has been submitted with this application. The pages including confidential information must clearly be labeled as confidential. See PS Memo 98-01 for acceptable confidential information submittals. ❑ This application includes confidential information on the following pages: r r t.„_ D. Submittal The Division is requiring one hardcopy submittal mailed to the APCD (with any wet signatures required; see instruction documents for details) and one electronic copy submittal emailed to APCD. The electronic submittal MUST be submitted in word format (either .doc or .docx) to cdphe apcd title V@state.co.us. For legal purposes, the date the signed hardcopy is received by the Division is considered the date received, not when the electronic copy is emailed. E. Oil and Gas Sources If this facility is associated with Oil a Gas activities, Form OP-202 must be completed if the facility is submitting an initial application or the facility is requesting changes to oil and gas equipment and must be submitted for the application to be considered complete. Oil and Gas SIC codes include, but are not limited to, 1311, 1321, and 4922. E Form OP-202 has been included with this application. ❑ This facility is not an oil and gas facility, and/or the facility is not requesting any changes to the oil and gas equipment. F. Modeling If an emission unit will have to go through modeling as part of a permit action, OP-204 must be completed and attached to the corresponding OP-300 series form. If the applicant has already filled out the optional air quality modeling form as part of the modeling process, the applicant may attach that form in lieu of OP-204. For information about the modeling process, see the page titled "Air Quality Modeling Guidance for Permits" on the Division webpage. ❑ Form OP-204 has been completed and attached. ❑ A copy of the optional air quality modeling form has been attached. • This facility did not trigger modeling requirements. Form Revised March 2020 Page I 2 of 3 ,t:, COLORADO Department al public Health 6 Envimnment ; COLORADO Form OP-50 ' Air Pollution Control Division ce.". 5. Signature of Responsible Official A. Statement of Completeness E I have reviewed this application in its entirety and, based on information and belief formed after reasonable inquiry, I certify that the statements and information contained in this application are true, accurate and complete. B. Certification of Facility Compliance Status With Federal and State Enforceable Conditions E I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements, including compliance certification requirements and any applicable compliance assurance monitoring. I I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements, except for the following emissions unit(s) identified below: 1 C. Certification of Facility Compliance Status With State-Only Enforceable Conditions E I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements. ET. I certify that the facility described in this air pollution permit application is fully in compliance with all applicable requirements, except for the following emissions unit(s) identified below: WARNING: Any person who knowingly, as defined in § 18-1-501(6), C.R.S., makes any false material statement, representation, or certification in, or omits material information from this application is guilty of a misdemeanor and may be punished in accordance with the provisions of S 25-7 122.1, C.R.S. Responsible Official Charles A. Job Name or Other' Title General Manager, North Area Operations Signature2 e ,------ �1 Date 'For the following applications, a signature of a Legally Authorized Person (not a vendor or consultant) is acceptable: Notification of Construction Permit Exempt Unit, Billing contact update, Responsible Official update, and Supplemental Information submittal. For these application types, a Legally Authorized Person must only certify with Section 5.A (5.B and 5.C certifications are not needed). 2This document requires a "wet signature,"electronic signatures will not be accepted. SEND MATERIALS TO: Colorado Dept. of Public Health & Environment APCD-SS-B1 ATTN: Title V Unit Supervisor 4300 Cherry Creek Drive South Denver, CO 80246-1530 cdphe_apcd_title_V®state.co.us Form Revised March 2020 P 2 13 of 3 m COLORADO Lleportmenl of Public Health b Environment Attachment C Title V Operating Permit Form—OP-202 Enterprise Compressor Station ( COLORADO Form OP-202 4 Air Pollution Control Division 4i tkTar^*air t+f?t,,GK Walt11 k EnvvQrmr :.t Oil Et Gas Facility Form Title V Operating Permit 95OPWE103 Plant AIRS ID 123 - 0277 Number: Number: 1. Instructions Included on the Colorado Air Pollution Control Website is an instruction sheet (Form OP-202A) for this Oil and Gas Facility Form. Refer to the instruction sheet or contact the Division with any questions. Any form with missing information may be determined administratively incomplete and may result in inability to grant the application shield of Regulation No. 3, Part C, Section II.B. Renewal and modification applications for equipment already included in the Title V permit are allowed to only complete portions of the form affected by the modification. Note that if using copy and paste; the applicant must paste as plain text. See "General Instructions" document for more details. Form Index 2. Storage Tanks 2 3. Glycol Dehydration Units 5 4. Spark Ignition (SI) Engines 7 5. Compression Ignition (CI) Engines 9 6. Reciprocating Compressors 10 7. Centrifugal Compressors 12 8. Natural Gas Driven Pneumatic Pumps 14 9. Natural Gas Driven Pneumatic Controllers 16 10. Fugitive Emissions 17 11. Sweetening Units 20 12. Well Site Facilities 22 13. Transmission Et Storage Facilities 23 14. Emissions Inventory 24 15. Combustion Control Devices 25 Attach Facility Emissions Inventory Form (APCD-1O2) Form Revised March 202O Page 11 of 27 COLORADO AIRS ID: 123-0277 o`w""""`°�wetu _. ':Health b Environment ,� COLORADO Form OP-202 �� Air Pollution Control Division 9,145' G_.2 rN PUh:[1-tedn En nro r m nt 2. Storage Tanks Check this box if this facility does not have storage tanks and leave this section blank. For the following Section, provide the information requested for each storage tank located at this facility. If this facility has multiple storage tank points, fill out one copy of this Section for each point. This Section is not required for storage tanks that are classified as insignificant activities under Colorado Regulation No. 3, Part C, Section II.E. Note that if the storage tank is subject to a Reg 7 requirement, or if any storage vessel included within the storage tank is subject to a MACT/NSPS requirement, they are NOT considered to be an insignificant activity and must be reported in this Section. Refer to instruction sheet OP-202A for more information. Equipment AIRS ID 123-0277-063 Equipment Unique ID P013 Storage Tank Contents Stabilized condensate Date of Storage Tank 4 tanks - 1993, 4 tanks - 2013 Construction Operational Configuration ❑ Parallel ❑ Series ❑ Single Vessel ❑ Other (describe): click_ here to enter text. Control Device Used: ❑ ECD ❑ RTO ❑ Open Flare ❑ Other (describe): Click here (check all that apply) ❑ TO ❑ VRU ❑ None enter text. Colorado Regulation No. 7, Part D, Section I.D-F: System-wide Control Requirements for Condensate Tanks and Storage Tank Control Strategy in the Ozone Non-Attainment Area (rule adopted December 19, 2019) IIYes UNo Subject? If no, provide explanation: This facility is a compressor station, exempt via Part D, Section I.I. If not subject, stop here. Do not complete the rest of this section for Part D, Section l.D-F. Is this facility permitted to use alternative emissions control equipment? Compliance Alternatives ❑ Yes ❑ No (Part D, Section I.D.4) If yes, describe: Click here to enter text. Exemptions Does this facility meet the exemption criteria of Part D, Section I.F.1.h? (Part D, Section I.F.1.h) ❑ Yes ❑ No Colorado Regulation No. 7, Part D, Section II.C: Control Requirements for VOC and Hydrocarbon Emissions from Storage Tanks (rule adopted December 19, 2019) ❑ Yes ❑ No Subject? If no, provide explanation: Click here to enter text . If not subject, stop here. Do not complete the rest of this section for Part D, Section II.C. Have Contents Been • Stabilized? C Yes ❑ No (Part D, Section II.C.2.b) Is this storage tank exempted from installing and operating air pollution control Exemptions equipment due to excessive supplemental fuel requirements? (Part D, Section O Yes ❑ No II.C.1.c.(iii)) If yes, the Division may request additional documentation. Form Revised March 2020 Page I 2 of 27 •µ`z COLORADO AIRS ID: 123-0277 Heparonent el Puh encahh b Environment COLORADO FormOP-202 Mr Pollution Control Division I Dcortmm s Puttx 1-4'i s Er,,roanent 40 CFR Part 60 Subpart OOOO: Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution for which Construction, Modification or Reconstruction Commenced After August 23, 2011 and on or before September 18, 2015 (rule published June 3, 2016) ❑ Yes No List equipment unique ID of subject vessel(s): C1ick here to enter text. Subject? ❑ Attach determination calculation of potential VOC emissions (560.5365(e)) If no, provide explanation: 4 tanks predate Subpart 0000 applicability. While 4 additional tanks were installed in 2013, the PTE for all tanks is limited to < 6 tpy. If not subject, stop here. Do not complete the rest of this 0000 section. ❑ Group 1 Storage Vessels (list): ^❑_c'.K here to list all affected Groups eqaipment (560.5395(a)) ❑ Group 2 Storage Vessels (list): c:_i.ck rere t:. - _st a1 _ arfecie,a,. equipment. Emission Reduction ❑ Reduce VOC emissions by 95% Standards (560.5395(d)) ❑ Reduce uncontrolled actual VOC emissions < 4 tpy Cover and Closed Vent System • Emissions Routing: i❑ Control Device ❑ Process • Bypass Device: ❑ Yes ❑ No Compliance Options • Control Device Type (if used): c1 here to r ter text. (560.5395(e)) • Manufacturer's Performance Test (for combustion control devices only): ❑ Yes ❑ No ❑ Floating Roof Design 40 CFR Part 60 Subpart OOOOa: Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 (rule published March 12, 2018) ❑ Yes C No List equipment unique ID of subject vessel(s): c1i r core to enter text . Subject? (§60.5365a(e)) ❑ Attach determination calculation of potential VOC emissions If no provide explanation: The installation of all 8 storage tanks predate the applicability date for Subpart 0000a If not subject, stop here. Do not complete the rest of this 0000a section. Emission Reduction ❑ Reduce VOC emissions by 95% Standards (560.5395a(a)) ❑ Reduce uncontrolled actual VOC emissions < 4 tpy ❑ Cover and Closed Vent System • Emissions Routing: ❑ Control Device ❑ Process • Bypass Device: ❑ Yes ❑ No Compliance Options • Control Device Type (if used): click here to enter text. (560.5395a(b)) • Manufacturer's Performance Test (for combustion control devices only): ❑ Yes ❑ No ❑ Floating Roof Design Form Revised March 2020 Page 13 of 27 w COLORADO AIRS ID: 123-0277 Department el Public Hcatth b Enwonment COLORADO Form OP-202 Air Pollution Control Division I 40 CFR Part 60 Subpart Kb: Standards of Performance for Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels)for Which Construction, Reconstruction, or Modification Commenced after July 23, 1984 (rule published October 15, 2003) Yes No Subject? List equipment unique ID of subject vessel(s): click here to enter text. (§60.110b(a)) If no, provide explanation: All 8 storage tanks have individual volumes of 300 bbl each, less than the 75 m3 threshold for Subpart Kb applicability. If not subject, stop here. Do not complete the rest of this Kb section. ❑ Fixed Roof in Combination with Internal Floating Roof Compliance Options (§60.112b(a)) ❑ External floating roof ❑ Closed Vent System and Control Device Compliance Alternatives ❑ Internal Floating Roof Complying with 40 CFR Part 65, Subpart C (§60.110b(e)) ❑ External Floating Roof Complying with 40 CFR Part 65, Subpart C 40 CFR Part 63 Subpart HH: National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities (rule published August 16, 2012) ❑ Yes ENo Subject? List equipment unique ID of subject vessel(s): click here to enter text. (§63.760(b)) If no, provide explanation: Enterprise Compressor Station is an area source of HAP emissions, per the definition included in Subpart HH. There are no applicable requirements for storage tanks at an area source of HAP emissions. If not subject, stop here. Do not complete the rest of this HH section. ❑ Process Vent Connected to Control Device Through a Closed-Vent System Compliance Options ❑ Pressure Vessel Operated with No Detectable Emissions (§63.766(b)) ❑ Closed Vent System Connected to Process Natural Gas Line —9 Form Revised March 2020 Page 14 of 27 COLORADO AIRS ID: 123 0277 • Health E Department, ,,,C,,, COLORADO Form OP 202 Air Pollution Control Division DYh -'^K"`=W"Ptr'f He tith&F.ri.rrcA`rnt?nt 3. Glycol Dehydration Units ❑ Check this box if this facility does not have glycol dehydration units and leave this section blank. For the following Section, provide the information requested for the glycol dehydration unit(s) located at this facility. If this facility has multiple glycol dehydration units, fill out one copy of this Section for each point. Equipment AIRS ID 123-0277-077 Equipment Unique ID D-3 Glycol Type TEG ❑ DEG ❑ EG Control Device Used: ECD ❑ RTO ❑ Open Flare ❑ Other (describe): Click here (check all that apply) ❑ TO > VRU ❑ None to enter text. Colorado Regulation No. 7, Part D, Section I.H: Emission Reductions from Glycol Natural Gas Dehydrators (rule adopted December 19, 2019) Yes ❑ No Subject? If no, provide explanation: Click here to enter text. Colorado Regulation No. 7, Part D, Section II.D: Statewide Control Requirements for Dehydrators (rule adopted December 19, 2019) x Yes ❑ No Subject? If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this section for Part D, Section II.D. Dehydration Unit Location Located Within 1,320 Feet of Building Unit or Outdoor Activity? El Yes El No (Part D, Section II.D.3 & 4) 40 CFR Part 63 Subpart HH: National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities (rule published August 16, 2012) Subject? Yes ❑ No (563.760(a) & (b)) If no, provide explanation: Click here to enter tort. If not subject, stop here. Do not complete the rest of this HH section. Facility Classification Is this facility considered to be a production field facility? ❑ Yes LI No (563.761) Facility HAP Status (as defined in Subpart HH): ❑ Major LI Area Large Glycol Dehydration Unit at Major Sources of HAP ❑ Process vent connected to control device through a closed-vent system Process Vent Compliance ❑ Process vent connected to control device through a closed-vent system and Options outlet benzene emissions from control device < 0.9 Megagrams per year (< -1 (563.765(b) & (c)) tpy) Other (describe): Click here to describe alternative. ❑ Small Glycol Dehydration Unit at Major Sources of HAP Process Vent Compliance ❑ Process vent BTEX emissions < limit determined by Equation 1 or Equation 2 Options of 63.765(b)(1)(iii) (563.765(b) & (c)) ❑ Other (describe): click here to describe alernative. LI TEG Dehydration Unit at Area Sources of HAP Form Revised March 2020 Page I 5 of 27 COLORADO AIRS ID: 123-0277 Department or Public Health b Environment COLORADO Form OP-202 Air Pollution Control Division caws par ,,5 Pt+ Hie-WM tJ Enos{ nert Is this unit located in an area that is in a UA plus offset and UC boundary and Process Vent Compliance complies byconnecting the process vent to a control device through a closed- Options vent system? ❑ Yes No (§63.765(b) & (c), Is this unit located in an area that is not in a UA plus offset and UC boundary and 563.764(d)) complies using Lops? Z Yes ❑ No ❑ Other (describe): Click here to describe alternative. Actual average natural gas flowrate to the glycol dehydration unit < 85 thousand Exemptions standard cubic meters per day (< -3 MMSCFD)? ❑ Yes No (563.764(e)) Actual average benzene emissions from glycol dehydration unit process vent to atmosphere < 0.9 megagrams per year (< -1 tpy)? ❑ Yes ® No 40 CFR Part 63 Subpart HHH: National Emission Standards for Hazardous Air Pollutants From Natural Gas Transmission and Storage Facilities (rule published August 16, 2012) Subject? ❑ Yes No (563.1270(a) & (b)) If no, provide explanation: Compressor Stations are not subject to Subpart HHH If not subject, stop here. Do not complete the rest of this HHH section. ❑ Large Glycol Dehydration Unit ❑ Process vent connected to control device through a closed-vent system Process Vent Compliance ❑ Process vent connected to control device through a closed-vent system and Options outlet benzene emissions from control device < 0.9 Megagrams per year (< -1 (§63.1275(b) & (c)) tpy) ❑ Other (describe): Click here to describe alternative. ❑ Small Glycol Dehydration Unit Process Vent Compliance ❑ Process vent BTEX emissions < limit determined by Equation 1 or Equation 2 Options of 63.1275(b)(1)(iii) (§63.1275(b) & (c)) ❑ Other (describe): Click here to describe alternative. Form Revised March 2020 Page I 6 of 27 COLORADO AIRS ID: 123-0277 °I Healthb Envis°ntnent F COLORADO Form OP 202 Au Pollution Control Division rc#,At 1'y�>prr err 1,1,1)k Kraft h i{roroc,-ncnt 4. Spark Ignition (SI) Engines ❑ Check this box if this facility does not have spark ignition engines and leave this section blank. For the following Section, provide the information requested for the spark ignition engine(s) located at this facility. If this facility has multiple spark ignition engine points, fill out one copy of this Section for each point. This Section is not required for spark ignition engines that are classified as insignificant activities under Colorado Regulation No. 3, Part C, Section 11.E. Note that if a spark ignition engine is subject to a MACT/NSPS/Reg 7 requirement, it is NOT considered to be an insignificant activity and must be reported in this Section. Refer to instruction sheet OP-202A for more information. Equipment AIRS ID xXX-xYXx-xxx Equipment Unique ID Click here to enter text . Colorado Regulation No. 7, Part E, Sections I.A - C: Control of Emissions from Engines in the 8 Hour Ozone Control Area (rule adopted December 19, 2019) ❑ Yes ❑ No Subject? If no, provide explanation: Click_ here to enter text. If not subject, stop here. Do not complete the rest of this section for Part E, Section i.A-C. ❑ Install NSCR Et AFR Compliance Options for SI Engines > 500 hp ❑ Install CatOx (Part E, Section I.A-C) ❑ Exempted Under Part E, Section I.C (provide citation): click here to enter text. Colorado Regulation No. 7, Part E, Section I.D: Statewide Control of Emissions from New, Modified, Existing, and Relocated Natural Gas Fired Reciprocating Internal Combustion Engines (rule adopted December 19, 2019) ❑ Yes ❑ No Subject? If no, provide explanation: click r_ere to enter text. If not subject, stop here. Do not complete the rest of this section for Part E, Section I.D. Compliance Options (check all that apply) ❑ Table 1 Standards ❑ Install NSCR Et AFR ❑ Install CatOx (Part E, Section I.D.2 a 3) Compliance Alternatives (Part E, Section I.D.3.a.(ii) ❑ Retrofit Cost Analysis and b.(ii)) Exemptions Is this engine subject to an emissions control requirement listed in a federal (Part E, Section MACT, NSPS or BACT limit (rich burn RICE > 500 hp only)? I.D.3.a.(i)(B)) ❑ Yes ❑ No Colorado Regulation No. 7, Part E, Section II: Control of Emissions from Stationary and Portable Combustion Equipment in the 8-Hour Ozone Control Area (rule adopted December 19, 2019) ❑ Yes ❑ No Subject? If no, provide explanation: click here to enter text. If not subject, stop here. Do not complete the rest of this section for Part E, Section II. Major Source of NOx ❑ Major source of NOx status as of 6/3/2016 (100 tpy NOx threshold) Facility Classification Date (Part E, Section II.A.1) ] Major source of NOx status as of 1/27/2020 (50 tpy NOx threshold) Form Revised March 2020 Page 17 of 27 _COLORADO AIRS ID: 123-0277 Dapa„mentoltha e _.. '.Health 6 Eneironmenl COLORADO Form OP-202 Air Pollution Control Division G'>sva' '.C1+''ut t4Cditt•.,�Er orar,"nt Compliance Options for ❑ Combustion Process Adjustment Engines Located at Major Sources of NOx ❑ Exempted Under Part E, Section II.A.2 (provide citation): Click here to (Part E, Section II.A) enter text . 40 CFR Part 63 Subpart ZZZZ: National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (rule published February 27, 2014) Subject? ❑ Yes ❑ No (563.6585) If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this ZZZZ section. Facility Classification Is this facility considered to be a production field facility? ❑ Yes ❑ No (563.6675) Facility HAP Status (as defined in Subpart ZZZZ): ❑ Major ❑ Area Type of Engine (check all that apply) DI Remote (if remote, the Division may request additional documentation) ❑ Limited Use (S63.6590, §63.6603) Form Revised March 2020 Page 18 of 27 m;.z COLORADO AIRS ID: 123 0277 Departmentot Public Health bEnvizonment -,:i.... COLORAL O Form OP 202 y� Air Pollution Control Division w+i i va putt(Hfldtt3 Eflorew!,rwer:S 5. Compression Ignition (CI) Engines Check this box if this facility does not have compression ignition engines and leave this section blank. For the following Section, provide the information requested for the compression ignition engine(s) located at this facility. If this facility has multiple compression ignition engine points, fill out one copy of this Section for each point. This Section is not required for compression ignition engines that are classified as insignificant activities under Colorado Regulation No. 3, Part C, Section 11.E. Note that if a compression ignition engine is subject to a MACT/NSPS/Reg 7 requirement, it is NOT considered to be an insignificant activity and must be reported in this Section. Refer to instruction sheet OP-202A for more information. Equipment AIRS ID xxx--tixxx-XXx Equipment Unique ID Click here to enter text. Displacement click here to ente:-t displacement. (L/cylinder) Colorado Regulation No. 7, Part E, Section II: Control of Emissions from Stationary and Portable Combustion Equipment in the 8-Hour Ozone Control Area (rule adopted December 19, 2019) ❑ Yes ❑ No Subject? If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this section for Part E, Section 11. Major Source of NOx ❑l Major source of NOx status as of 6/3/2016 (100 tpy NOx threshold) Facility Classification Date (Part E, Section II.A.1) ElMajor source of NOx status as of 1/27/2020 (50 tpy NOx threshold) Compliance Options for ❑ Emission Limitation Engines Located at Major Li Combustion Process Adjustment Sources of NOx ❑ Exempted Under Part E, Section II.A.2 (provide citation): Click here to (Part E, Section II.A) enter text. 40 CFR Part 63 Subpart ZZZZ: National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (rule published February 27, 2014) Subject? ❑ Yes ❑ No (563.6585) If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this ZZZZ section. Facility Classification Is this facility considered to be a production field facility? ❑ Yes L❑ No ' (563.6675) Facility HAP Status (as defined in Subpart ZZZZ): ❑ Major ❑ Area Type of Engine ❑ Limited Use (563.6590) Form Revised March 2020 Page 19 of 27 ':w:;• COLORADO AIRS ID: 123-0277 ❑epottment of FuEffe Health b Environment eCOLORADO Form OP-202 ff Air Pollution Control Division C.: tr, ', c,.11,1.4tbc Health b EMATOrMIM 6. Reciprocating Compressors ❑ Check this box if this facility does not have reciprocating compressors and leave this section blank. For the following Section, provide the information requested for the reciprocating compressor(s) located at this facility. Multiple reciprocating compressor(s) may be addressed in a single section; it is not necessary to fill out a copy of this section for each compressor individually. Equipment Unique ID Click here to enter text. Colorado Regulation No. 7, Part D, Section I.J: Requirements for Compressors Operating in Ozone Non- Attainment Areas (rule adopted December 19, 2019) ❑ Yes ❑ No Subject? If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this section for Part D, Section I.J. Reciprocating Compressor Compliance Options ❑ Change Rod Packing ❑ Closed Vent System (Part D, Section I.J.2.a & b) Compliance Alternatives (Part D, Section I.J.2.d. & ❑ Part D, Section I.L (LDAR) ❑ 40 CFR Part 60 e) Colorado Regulation No. 7, Part D, Section 11.6.3: Statewide Requirements for Compressors (rule adopted December 19, 2019) ❑ Yes ❑ No Subject? If no, provide explanation: Click here to enter text. 40 CFR Part 60 Subpart OOOO: Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution for which Construction, Modification or Reconstruction Commenced After August 23, 2011 and on or before September 18, 2015 (rule published June 3, 2016) Subject? ❑ Yes ❑ No (560.5365(c)) If no, provide explanation: Click here to enter. text. If not subject, stop here. Do not complete the rest of this 0000 section. • Change Rod Packing Compliance Options (560.5385(a) & ❑ Closed Vent System §60.5411(a)) • Emissions Routing: ❑ Control Device ❑ Process • Bypass Device: ❑ Yes ❑ No 40 CFR Part 60 Subpart OOOOa: Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 (rule published March 12, 2018) Subject? ❑ Yes ❑ No (560.5365a(c)) If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this 0000a section. Compliance Options ❑ Change Rod Packing (560.5385a(a) & §60.5411a(a)) ❑ Closed Vent System Form Revised March 2020 Page 110 of 27. •,.= COLORADO AIRS ID: 123-0277 Health b b Enrt et Pub e Hvironment .^„„ COLORADO Form OP-202 ' ' Air Pollution Control Division ASFT_?tt4.= c t*tit -Ream,..{r£nor«r-neat • Emissions Routing: ❑ Control Device ❑ Process • Bypass Device: ❑ Yes ❑ No Compliance Alternatives r tc U, rir_e alternative. (AMEL) (560.5398a) Form Revised March 2020 Page 111 of 27 COLORADO AIRS ID: 123 0277 Health b Environment COLORADO Form OP-202 Air Pollution Control Division NparrIvn +Ptatbx Hatt, 1rsv rerenera 7. Centrifugal Compressors ❑ Check this box if this facility does not have centrifugal compressors and leave this section blank. For the following Section, provide the information requested for the centrifugal compressor(s) located at this facility. Multiple centrifugal compressor(s) may be addressed in a single section; it is not necessary to fill out a copy of this section for each compressor individually. Equipment Unique ID Click here to enter text. Colorado Regulation No. 7, Part D, Section l.J: Requirements for Compressors Operating in Ozone Non- Attainment Areas (rule adopted December 19, 2019) ❑ Yes ❑ No Subject? If no, provide explanation: click here to enter test. If not subject, stop here. Do not complete the rest of this section for Part D, Section I.J. Emissions Routing Control Device Process (Part D, Section I.J.1.b) ❑ ❑ Compliance Alternatives (Part D, Section I.J.1.i & ❑ Part D, Section IA. ( DAR) ❑ 40 CFR Part 60 j) Colorado Regulation No. 7, Part D, Section II.B.3: Statewide Requirements for Compressors (rule adopted December 19, 2019) ❑ Yes ❑ No Subject? If no, provide explanation: Click here to enter text. 40 CFR Part 60 Subpart OOOO: Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution for which Construction, Modification or Reconstruction Commenced After August 23, 2011 and on or before September 18, 2015 (rule published June 3, 2016) Subject? ❑ Yes ❑ No (560.5365(b)) If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this 0000 section. ❑ Cover and Closed Vent System Compliance Options • Emissions Routing: ❑ Control Device ❑ Process (560.5380(a), • Bypass Device: ❑ Yes ❑ No §60.5411(a), • Control Device Type (if used): click here to _enter text. §60.5412(a), • If control device is a boiler or process heater, are all vent streams introduced with the primary fuel? ❑ Yes Li No §60.5417(b)) • Manufacturer's Performance Test (for combustion control devices only): ❑ Yes ❑ No 40 CFR Part 60 Subpart 0000a: Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015(rule published March 12, 2018) Subject? ❑ Yes ❑ No (560.5365a(b)) If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this 0000a section. Compliance Options Li Cover and Closed Vent System Form Revised March 2020 Page 112 of 27 COLORADO AIRS ID: 123-0277 ra`,,;iPe,,, COLORADO Form OP-202 Air Pollution Control Division t -at ' t (§60.5380a(a), • Emissions Routing: ❑ Control Device ❑ Process §60.5411 a(a), • Bypass Device: ❑ Yes ❑ No §60.5412a(a), • Control Device Type (if used): Click here to enter text. §60.5417a(b)) • If control device is a boiler or process heater, are all vent streams introduced with the primary fuel? ❑ Yes ❑ No • Manufacturer's Performance Test (for combustion control devices only): ❑ Yes ❑ No Form Revised March 2020 Page 113 of 27 i COLORADO AIRS ID: 123-0277 Ert Heahh b Envlscnment COLORADO Form OP-202 Air Pollution Control Division I IITMO:^ dal± &tnvtrt rTnert; 8. Natural Gas Driven Pneumatic Pumps ❑ Check this box if this facility does not have natural gas driven pneumatic pumps and leave this section blank. For the following Section, provide the information requested for the natural gas driven pneumatic pump(s) located at this facility. Multiple natural gas driven pneumatic pump(s) may be addressed in a single section; it is not necessary to fill out a copy of this section for each pneumatic pump individually. Colorado Regulation No. 7, Part D, Section I.K: Requirements for Natural Gas Driven Pneumatic Pumps Operating at Natural Gas Processing Plants or Well Production Facilities Located in an Ozone Non-Attainment Area (rule adopted December 19, 2019) ❑ Yes ❑ No Subject? If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this section for Part D, Section I.K. El Natural Gas Processing Plant Compliance Options ❑ VOC Emission Rate of Zero (Part D, Section I.K.1) Compliance Alternatives ❑ 40 CFR Part 60 (Part D, Section I.K.5) ❑ Well Production Facility Compliance Options ❑ Infeasible per Technical (check all that apply) ❑ Route to Process ❑ Control Device Assessment Click here to list all (Part D, Section I.K.2) affected equipment. Compliance Alternatives (check all that apply) ❑ Part D, Section I. ❑ 40 CFR Part 60 (LDAR) (Part D, Section I.K.4 & 5) 40 CFR Part 60 Subpart OOOOa: Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 (rule published March 12, 2018) Subject? ❑ Yes ❑ No (560.5365(h)) If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this 0000a section. • Natural Gas Processing Plant Compliance Options (§60.5393a(a)) ❑ Natural Gas Emission Rate of Zero ❑ Well Site Facility Type (§60.5393a(b)) ❑ Greenfield ❑ Non-Greenfield Operating Hours (560.5365a(h)(2)) Does any pneumatic pump operate < 90 days? ❑ Yes ❑ No Compliance Options ❑ Closed Vent System Form Revised March 2020 Page 114 of 27 =b 'COLORADO AIRS ID: 123-0277 Health ,N , COLORADO Form OP-202 Air Pollution Control Division ttriAt WNW Enviror,rwm (§60.5411 a(a), • Emissions Routing: ❑ Control Device ❑ Process 560.5393a(b)) • Bypass Device: ❑ Yes ❑ No ❑ Infeasibility Determination: Click here to list all affected equipment. Form Revised March 2020 Page 115 of 27 °COLORADO AIRS ID: 123-0277 Public Health₹e Envis°nene 1 �•� COLORADO Form OP-202 Air Pollution Control Division GO r*t G2p,,',,,,,,0 buts[HCalth [mire anent 9. Natural Gas Driven Pneumatic Controllers ❑ Check this box if this facility does not have natural gas driven pneumatic controllers and leave this section blank. For the following Section, provide the information requested for the natural gas driven pneumatic controller(s) located at this facility. Multiple natural gas driven pneumatic controller(s) may be addressed in a single section; it is not necessary to fill out a copy of this section for each pneumatic controller individually. Colorado Regulation No. 7, Part D, Section III: Requirements for Natural Gas Driven Pneumatic Controllers Located at or Upstream of Natural Gas Processing Plants (rule adopted December 19, 2019) ❑ Yes ❑ No Subject? If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this section for Part D, Section III. Types Used ❑ High Bleed ❑ No Bleed (check all that apply) (Part D, Section III.C) ElLow Bleed ❑ Intermittent Bleed Exemptions ❑ Safety Purposes (attach list of exempted controllers) (check all that apply) (Part D, Section III.C) ❑ Process Purposes (attach list of exempted controllers) 4O CFR Part 6O Subpart OOOO: Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution for which Construction, Modification or Reconstruction Commenced After August 23, 2011 and on or before September 18, 2015 (rule published June 3, 2016) Subject? ❑ Yes ❑ No (560.5365(d)) If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this 0000 section. Controller Types ❑ Bleed Rate = 0 scfh: Click here to list quantity. (560.5390(a), (b}(1), Ft ❑ Bleed Rate < 6 scfh: Click here to list quantity. (c)(1)) ❑ Bleed Rate > OOOO Standard: click here to list quantity. 4O CFR Part 6O Subpart 0000a: Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 (rule published March 12, 2018) Subject? ❑ Yes ❑ No (§60.5365a(d)) If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this 0000a section. Controller Types ❑ Bleed Rate = 0 scfh: Click here to list quantity. (560.5390a(a), (b)(1), Et ❑ Bleed Rate < 6 scfh: Click here to list quantity. (c)(1)) ❑ Bleed Rate > 0000a Standard: Click here to list quantity. 1 Form Revised March 2020 Page 116 of 27 COLORADO AIRS ID: 123-0277 '• DepaHmentotPublie Health b Environment C O L O R A D O Form OP-202 iff, Fur Pollution Control Division o,,,,,,0-,r t Th.,b4C}44 z(th, Env,r0,,-nem 10. Fugitive Emissions For the following Section, provide the information requested for the fugitive emissions at this facility. If this facility has multiple fugitive emission points (i.e., multiple AIRS IDs for fugitive emissions within one facility), fill out one copy of this Section for each point. Equipment AIRS ID Click here to list all affected equipment. Equipment Unique ID Click here to list all affected equipment. Colorado Regulation No. 7, Part D, Section LL: Fugitive Emissions Requirements for Well Production Facilities and Natural Gas Compressor Stations Located in the 8 Hour Ozone Control Area (rule adopted December 19, 2019) [II Yes [II No Subject? If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this section for Part D, Section 1.L. Compliance Options ❑ EPA Method 21 (Part D, Section I.L.1 s* El IR Camera I.L.2) El Other (describe): Click here to enter text. Compliance Alternatives n Alternative AIMM (describe): Click here to enter text. (Part D, Section I.L.8) Colorado Regulation No. 7, Part D, Section II.E: Statewide Fugitive Emissions Requirements for Well ' Production Facilities and Natural Gas Compressor Stations (rule adopted December 19, 2019) ❑ Yes ❑ No Subject? If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this section for Part D, Section 11.E. El Protocol for Equipment Leak Emission Estimates EPA 453/R-95-017, Table 2-4 Emission Factors ❑ Protocol for Equipment Leak Emission Estimates EPA 453/R-95-017, Table 2-8 (Part D, Section II.E.2) El Other (describe): Click here to: enter text. ❑ EPA Method 21 ' Compliance Options ❑ IR Camera (Part D, Section II.E.3) El Other (describe): Click here to enter text. 40 CFR Part 60 Subpart KKK: Standards of Performance for Equipment Leaks of VOC From Onshore Natural Gas Processing Plants for Which Construction, Reconstruction, or Modification Commenced After January 20, 1984, and on or Before August 23, 2011 (rule published August 16, 2012) Subject? ❑ Yes El No 060.630) If no, provide explanation: Cl.ick here to enter text. If not subject, stop here. Do not complete the rest of this KKK section. Exceptions (560.633) Click here to enter applicable e exception. Compliance Alternatives Click here to describe alternative. (AMEL) (560.634) 40 CFR Part 60 Subpart OOOO: Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution for which Construction, Modification or Reconstruction Commenced After August ; Form Revised March 2020 Page 11 7 of 27 „ :COLORADO AIRS ID: 123-0277 _ Department°I Health&Environment COLORADO Form OP-202 41440015- Air Pollution Control Division DesamnmtotscHealmlarmrexmcm 23, 2011 and on or before September 18, 2015 (rule published June 3, 2016) Subject? ❑ Yes ❑ No (560.5365(f)) If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this 0000 section. Compliance Options ❑ 40 CFR Part 60 Subpart VVa (EPA Method 21) (560.5400(a)) Exceptions (860.5401) Click here to enter applicable exception. Compliance Alternatives (AMEL) (560.5402) Click here to describe alternative. 40 CFR Part 60 Subpart OOOOa: Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 (rule published March 12, 2018) Subject? ❑ Yes ❑ No (560.5365a(f)) If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this 0000a section. ❑ Well Site ❑ Optical Gas Imaging (OG1) Compliance Options ❑ EPA Method 21 (560.5397a(c)(2)) ❑ Other (describe): Click here to enter text. Compliance Alternatives (AMEL) (560.5398a) Click here to describe alternative. ❑ Compressor Station ❑ Optical Gas Imaging (OGI) Compliance OptionsEl EPA Method 21 (560.5397a(c)(2)) ❑ Other (describe): click here to enter text. Compliance Alternatives (AMEL) (560.5398a) Click here to describe alternative. ❑ Natural Gas Processing Plant Compliance Options ❑ 40 CFR Part 60 Subpart VVa (EPA Method 21) (560.5400a(a)) Exceptions (560.5401a) Click here to enter applicable exception.. Compliance Alternatives Click here to describe alternative. (AMEL) (560.5402a) 40 CFR 63 Subpart HH: National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities (rule published August 16, 2012) Form Revised March 2020 Page 118 of 27 e,*,,COLORADO O L O R A D O AIRS ID: 123-0277 Hearth b€Department of Pubent COLORADO Form OP-202 Air Pollution Control Division Subject? ❑ Yes ❑ No (563.760(a) a(b)) If no, provide explanation: dick here to enter text. If not subject, stop here. Do not complete the rest of this HH section. Ancillary Equipment Click here to list all categories. Categories Exceptions ❑ Compressor/ancillary equipment VHAP content < 10 wt% (563.764(e)(2) a ❑ Compressor/ancillary equipment in VHAP service < 300 hours/year 63.764(c)(7)) ❑ Reciprocating compressor in wet gas service Form Revised March 2020 Page 119 of 27 ₹ COLORADO AIRS ID: 123-0277 Depastmentet Public Heahh h Envuor..mern ,,,, * COLORADO FormOP-202 Air Pollution Control Division Da v*r-^°'s of Pubt C 1 rRit6 t•Envtrcrrrte 11. Sweetening Units ❑ Check this box if this facility does not have sweetening units and leave this section blank. For the following Section, provide the information requested for the sweetening unit(s) located at this facility. If this facility has multiple sweetening unit points, fill out one copy of this Section for each point. Equipment AIRS ID Click here to list all affected equipment. Equipment Unique ID Click here to list all affected equipment. 40 CFR Part 60 Subpart LLL: Standards of Performance for S02 Emissions From Onshore Natural Gas Processing for Which Construction, Reconstruction, or Modification Commenced After January 20, 1984, and on or Before August 23, 2011 (rule published August 16, 2012) ❑ Yes ❑ No Subject? If no, list applicable exemption(s): Click here to enter text. If not subject, stop here. Do not complete the rest of this LLL section. Is the design capacity < 2 LT/D H2S in the acid gas (expressed as sulfur)? ❑ Yes ❑ No Unit Design If no, list design capacity (LT/D): Click here to enter text. (§60.640 a §60.646(e)) Is the acid gas produced completely reinjected or otherwise not released to atmosphere? ❑ Yes ❑ No Monitoring Options ❑ Install, calibrate and maintain monitoring devices (check all that apply) ❑ Perform daily measurements (560.646(a) &t §60.648) ❑ Tutwiler Procedure ❑ Oxidation Control System followed by a continually operated incineration device ❑ Reduction Control System followed by a continually operated incineration Compliance Options device (§60.646(b), (c) and (e)) ❑ Reduction Control System not followed by a continually operated incineration device ❑ Sulfur emission reduction efficiency calculation for units < 150 LT/D H2S design capacity 40 CFR Part 60 Subpart OOOO: Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution for which Construction, Modification or Reconstruction Commenced After August 23, 2011 and on or before September 18, 2015 (rule published June 3, 2016) ❑ Yes ❑ No Subject? If no, List applicable exemption(s): Click here to enter text. If not subject, stop here. Do not complete the rest of this 0000 section. Is the design capacity < 2 LT/D H2S in the acid gas (expressed as sulfur)? Unit Design ❑ Yes ❑ No (560.5365(g) Et If no, list design capacity (LT/D): Click here to enter text. §60.5407(e)) Is the acid gas produced completely reinjected or otherwise not released to atmosphere? ❑ Yes ❑ No Form Revised March 2020 Page 120 of 27 :_.;h;• CO 1.O R A c o AIRS ID: 123-0277 l Depenm . etp"h en )k tth&Ent°nvimnment COLORADO Form OP-202 . Air Pollution Control Division ca+4 C rr.t of Pau-Hci m r. r xt t s Monitoring Options ElInstall, calibrate and maintain monitoring devices (check all that apply) ❑ Perform daily measurements (560.5407(a) a §60.5408) D Tutwiler Procedure ❑ Oxidation Control System followed by a continually operated incineration device ❑ Reduction Control System followed by a continually operated incineration Compliance Options device (§60.5407(b), (c) and (e)) ❑ Reduction Control System not followed by a continually operated incineration device ❑ Sulfur emission reduction efficiency calculation for units < 150 LT/D H2S design capacity 40 CFR Part 60 Subpart OOOOa: Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 (rule published March 12, 2018) ❑ Yes ❑ No Subject? If no, list applicable exemption(s): here to enter text. If not subject, stop here. Do not complete the rest of this 0000a section. Is the design capacity < 2 LT/D H2S in the acid gas (expressed as sulfur)? Unit Design ❑ Yes ❑ No (§60.5365a(g) Et If no, list design capacity (LT/D): lick here to enter text. §60.5407a(e)) Is the acid gas produced completely reinjected or otherwise not released to atmosphere? ❑ Yes ❑ No Monitoring Options ❑ Install, calibrate and maintain monitoring devices (check all that apply) ❑ Perform daily measurements (§60.5407a(a) Et §60.5408a) ❑ Tutwiler Procedure ❑ Oxidation Cortrot System followed by a continually operated incineration device ❑ Reduction Control System followed by a continually operated incineration Compliance Options device (560.5407a(b), (c) and (e)) ❑ Reduction Control System not followed by a continually operated incineration device ❑ Sulfur emission reduction efficiency calculation for units < 150 LT/D H2S design capacity Form Revised March 2020 Page 121 of 27 :: COLORADO AIRS ID: 123 0277 • DepartmeHealthsE:°Public, COLORADO Form OP-202 Air Pollution Control Division 1120 Orfi! f?ioiorr'o PL+t.'.t Herrin-, Environment nt 12. Well Site Facilities Z Check this box if this facility is not a well site facility and leave this section blank. For the following Section, provide the information requested for a well site facility. Colorado Regulation No. 7, Part D, Section II.F & G: Control of Emissions from Well Production Facilities Et Emissions During Downhole Well Maintenance, Well Liquids Unloading Events and Well Plugging (rule adopted December 19, 2019) Commencement of Operation Click here to enter text- . (Part D, Section II.A.5) Subject? ❑ Colorado Regulation No. 7, Part D, Section II.F (Separator Emissions Control) (check all that apply) ❑ Colorado Regulation No. 7, Part D, Section II.G (Venting/Unloading/Plugging) 40 CFR Part 60 Subpart 0000: Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution for which Construction, Modification or Reconstruction Commenced After August 23, 2011 and on or before September 18, 2015 (rule published June 3, 2016) ❑ Yes ❑ No Subject? If no, provide explanation: Click here to enter text. If not subject, stop here. Do not complete the rest of this 0000 section. ❑ Wildcat Click here to list quantity. Specialty Well Types (check all that apply) ❑ Delineation Click here to list quantity. (560.5375(f)) ❑ Low Pressure Click here to list quantity. State/Local Emission Is this gas well facility subject to a more stringent state or local emission control Control Requirements (560.5375(a)) requirement? ❑ Yes ❑ No Refracturing (560.5365(h)) Has this gas well facility been hydraulically refractured? ❑ Yes ❑ No 40 CFR Part 60 Subpart OOOOa: Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 (rule published March 12, 2018) ❑ Yes ❑ No Subject? If no, provide explanation: click here to enter text. If not subject, stop here. Do not complete the rest of this 0000a section. Fluid Properties Does this affected well facility operate with less than 300 scf of gas per stock (560.5375a(g)) tank barrel of oil produced? ❑ Yes ❑ No ElWildcat Click here to list quantity. Specialty Well Types (check all that apply) ❑ Delineation Click here to list quantity. (560.5375a(f)) ❑ Low Pressure click here to list quantity. Compliance Alternatives (AMEL) Click here to describe alternative. (S60.5398a) Form Revised March 2020 page I 22 of 27 COLORADO AIRS ID: 123-0277 H b ri ihtbueom ICOLORADO Form OP-202 Air Pollution Control Division + vn-uer;o Puw He lm&£nor '^n.it 13. Transmission £t Storage Facilities El Check this box if this facility is not a natural gas transmission and storage facility and leave this section blank. For the following Section, provide the information requested for a natural gas transmission and storage facility. Colorado Regulation No. 7, Part D, IV: Control of Emissions the Natural Gas Transmission and Storage Segment (rule adopted December 19, 2019) Subject? ❑ Yes Form Revised March 2020 ,.:, COLORADO Page 23 of 27 AIRS ID: 123-0277 Health een:e ErEt°' , ,: �ro�,menr ! COLORADO Form OP-202 440 Air Pollution Control Division V.: , ..,s(Plitkr H€alak&Enern r.rwrt 14. Emissions Inventory For the following Section, provide the information requested for the Colorado Regulation No. 7 emissions inventory for oil and natural gas operations. Colorado Regulation No. 7, Part D, V: Oil and Natural Gas Operations Emissions Inventory (rule adopted December 19, 2019) C Yes ❑ No Subject? If no, list applicable exemption(s): CIci, here to enter text. Form Revised March 2020 Page 124 of 27 :„R'COLORADO AIRS ID: 123-0277 sepa�n„e„En menttoiPet c Kett,& viron COLORADO Form OP-202 Air Pollution Control Division 15. Combustion Control Devices ❑ Check this box if this facility does not have combustion control devices and leave this section blank. For the following Section, provide the information requested for the combustion control device(s) located at this facility. If this facility has multiple combustion control devices, fill out one copy of this Section for each point. Note that this section must be filled out for each combustion control device located at the facility, regardless of whether or not the device has its own AIRS ID. Refer to instruction sheet OP-202A for more information. Equipment AIRS ID N/A Equipment Unique ID N/A - Combined with TEG Dehydration unit D-3 ILi Enclosed Combustor (ECD) Thermal Oxidizer (TO) Combustion Control ❑ Regenerative Thermal Oxidizer (RTO) Device Design Is this RTO designed for Supplemental Fuel Injection (SFI) Mode? ❑ Yes ❑ No ❑ Open Flare Assist Type: ❑ Air ❑ Steam ❑ Gas ❑ None ❑ Other (describe): Click here tc enter text . Emission Units Controlled D-2, AIRS 068 OR D-3, AIRS 077 Throughput Measurement Stream (provide Emission Factor Source Method units) Li AP-42 Chapter 1.4 LI Meter [1] TCEQ 50 scf/hr Calculation Z Pilot ❑ Mass Balance 0.44 MMscf/yr C Mfg. ❑ Other (describe): ciicL_ Specification here to enter text. ❑ AP-42 Chapter 1.4 ❑ El Meter Ciick her: ❑ TCEQ ❑ Calculation Combustion Streams Supplemental to entereter ❑ Mass Balance Fuel (check all that apply) text. 'p Mfg. ❑ Other (describe): click Specification here to enter text. Li AP-42 Chapter 13.5 0 Meter 3,200 scf/hr ❑ TCEQ ❑ Calculation Li Assist Gas 28.03 El Mass Balance ❑ Mfg. MMscf/yr ❑ Other (describe): disk Specification her' to enter text. ❑ AP-42 Chapter 13.5 ❑ Meter Click here ❑ TCEQ ❑ Calculation ❑ Purge Gas -Lc- enter t.� t. ❑ Mass Balance ❑ Mfg. ❑ Other (describe): Click Specification Form Revised March 2020 Page 125 of 27 a COLORADO AIRS ID: 123-0277 Department of Public Health 6 Environment COLORADO Form OP-202 '''' „, © Mr Pollution Control Division 0,,,,,r?arns 4f pu�7c i e,mth H Enetror.went here to enter text. ❑ AP-42 Chapter 1.4 ❑ Meter Click here ❑ TCEQ ❑ Burner Gas enter er ❑ Calculation ❑ Mass Balance text . ❑ Mfg. ❑ Other (describe): click Specification here to enter text. ❑ AP-42 Chapter 13.5 ❑ Meter ❑ TCEQ Z Waste Gas 93.73 a Mass Balance Calculation MMscf/yr ❑ Mfg. ❑ Other (describe): Click Specification here to enter text. ❑ AP-42 Chapter 1.4 ❑ Other ❑ AP-42 Chapter 13.5 ❑ Meter (describe): Click here ❑ TCEQ ❑ Calculation Click here to enter to enter text. ❑ Mass Balance ❑ Mfg. text . ❑ Other (describe): Click Specification here to enter text. Colorado Regulation No. 7, Part D, Section I: Volatile Organic Compound Emissions from Oil and Gas Operations in Ozone Non-Attainment Area(s) (rule adopted December 19, 2019) Is this combustion control device used to comply with any requirement in Subject? Colorado Regulation No. 7, Part D, Section I? © Yes ❑ No If not subject, stop here. Do not complete the rest of this section for Part D, Section I. Date Permitted 4/22/2016 (Part D, Section I.D.3.a) Date Installed 04/11/2016 (Part D, Section I.C.1.e) Alternative Emission Has this combustion control device received approval for alternative emissions Control Equipment control equipment under the provisions of Section I.D.4? ❑ Yes ❑x No (Part D, Section I.D.4) If yes, the Division may request additional documentation. Colorado Regulation No. 7, Part D, Section II: Statewide Controls for Oil and Gas Operations (rule adopted December 19, 2019) Subject? Is this combustion control device used to comply with any requirement in Colorado Regulation No. 7, Part D, Section II? Z Yes ❑ No If not subject, stop here. Do not complete the rest of this section for Part D, Section II. Date Permitted (Part D, Section II.C.1.b, 4/22/2016 II.C.1.c >;t II.D.3.a) Date Installed 4/11/2016 (Part D, Section II.B.2.d) Alternative Emission Has this combustion control device received approval for alternative emissions Control Equipment control equipment under the provisions of Section II.B.2.e? ❑ Yes Z No Form Revised March 2020 Page 126 of 27 .. t 'COLORADO AIRS ID: 123-0277 Department of FUM1e Health b Envirenrnent L M ' C O I. O R A Dt O Form OP-202 Air Polluti Control Division on Dever-w::rd ,,t':�Ht`alit 1;Error ,44-:4 (Part D, Section II.B.2.e) If yes, the Division may request additional documentation. Form Revised March 2020 Page 127 of 27 COLORADO Department OI P btie AIRS ID: 123 0277 Health s Environment ;^ �" COLORADO Form OP-202.7 4 Air Pollution Control Division ns.t. Oil &t Gas Facility Form - Additional Combustion Devices Title Y Operating Permit 95OPWE103 Plant AIRS ID 123 - 0277 Number: Number: 1. Instructions This form is to be used for additional combustion control device points that were not addressed on OP-202 (i.e. multiple combustion control devices at one facility). OP-202 must be filled out in its entirety before this form is to be used. Note that if using copy and paste; the applicant must paste as plain text. See "General Instructions" document for more details. 2. Combustion Control Devices For the following Section, provide the information requested for the combustion control device(s) located at this facility. If this facility has multiple combustion control devices, fill out one copy of this Section for each point. Note that this section must be filled out for each combustion control device located at the facility, regardless of whether or not the device has its own AIRS ID. Refer to instruction sheet OP-202A for more information. Equipment AIRS ID N/A Equipment Unique ID N/A - Used to control emissions from the stabilized condensate storage tanks and truck loadout rack ❑ Enclosed Combustor (ECD) ❑ Thermal Oxidizer (TO) Combustion Control ❑ Regenerative Thermal Oxidizer (RTO) Device Design Is this RTO designed for Supplemental Fuel Injection (SFI) Mode? ❑ Yes ❑ No ❑ Open Flare Assist Type: ❑ Air ❑ Steam ❑ Gas ❑ None ❑ Other (describe): Click here to enter text. Emission Units Controlled P013 (AIRS 063), P016 (AIRS 066) Throughput Stream (provide Emission Factor Source Measurement Method units) ❑ AP-42 Chapter 1.4 ❑ Meter Click here ❑ TCEQ Calculation Combustion Streams El Pilot to enter El Mass Balance ❑ to El Mfg. check all that apply) describe ( PP y) ❑ Other (describe): Click Specification here to enter text. ❑ AP-42 Chapter 1.4 ❑ Meter ❑ Clink here ❑ TCEQ ❑ Calculation Supplemental to enter Fuel text. ❑ Mass Balance ❑ Mfg. ❑ Other (describe): click Specification Form Revised March 2020 Page 11 of 3 ;-°: COLORADO AIRS ID: 123-0277 HeathbeneFl en Health beg nment L ' COLORADO Form OP-202.7 Air Pollution Control Division t'm r.'.;d sPthstr.kfiaftt,k En.ntex:-tk�r:.i here to enter text. ❑ AP-42 Chapter 13.5 ❑ Meter here ❑ TCEQ ❑ Assist Gas to enter ❑ Mass Balance ❑ Calculation ext. ❑ Mfg. ❑ Other (describe): Click Specification here to enter text . ❑ AP-42 Chapter 13.5 ❑ Meter ruck here ❑ TCEQ LI Calculation ❑ Purge Gas to enter ❑ Mass Balance text. ❑ Mfg. ❑ Other (describe): Click Specification here to enter text. ❑ AP-42 Chapter 1.4 ❑ ❑ Meter her. TCEQ ❑ Calculation Burner Gas et ❑ Mass Balance ❑ ext. ❑ Mfg. ❑ Other (describe): Click Specification here to enter text. ❑ AP-42 Chapter 13.5 ❑ TCEQ El Meter ElWaste Gas 0.74 MMscf/yr ElMass Balance © Calculation ❑ Mfg. ❑ Other (describe): Click Specification here to enter text. ❑ AP-42 Chapter 1.4 ❑ Other ❑ AP-42 Chapter 13.5 ❑ Meter (describe): Click her ❑ TCEQ ❑ Calculation Click here -o enter to enter text. ❑ Mass Balance ❑ Mfg. text. ❑ Other (describe): Click Specification here to enter text. Colorado Regulation No. 7, Part D, Section I: Volatile Organic Compound Emissions from Oil and Gas Operations in Ozone Non-Attainment Area(s) (rule adopted December 19, 2019) Subject? Is this combustion control device used to comply with any requirement in Colorado Regulation No. 7, Part D, Section I? 0 Yes ❑ No If not subject, stop here. Do not complete the rest of this section for Part D, Section I. Date Permitted 1993 (Part D, Section I.D.3.a) Date Installed 1993 (Part D, Section I.C.1.e) Alternative Emission Has this combustion control device received approval for alternative emissions Control Equipment control equipment under the provisions of Section I.D.4? ❑ Yes © No (Part D, Section I.D.4) If yes, the Division may request additional documentation. Colorado Regulation No. 7, Part D, Section II: Statewide Controls for Oil and Gas Operations (rule adopted December 19, 2019) Form Revised March 2020 Page 12 of 3 = { COLORADO AIRS ID: 123-0277 oepanmenaotr t - Neaith b Envimnmmt COLORADO Form OP-202.7 Air Pollution Control Division "tAtc Reaim&EnWOrfnerit Subject? Is this combustion control device used to comply with any requirement in Colorado Regulation No. 7, Part D, Section II? El Yes ❑ No If not subject, stop here. Do not complete the rest of this section for Part D, Section 11. Date Permitted (Part D, Section II.C.1.b, 1993 II.C.1.c I* II.D.3.a) Date Installed 1993 (Part D, Section II.B.2.d) Alternative Emission Has this combustion control device received approval for alternative emissions Control Equipment control equipment under the provisions of Section II.B.2.e? ❑ Yes No (Part D, Section II.B.2.e) If yes, the Division may request additional documentation. Form Revised March 2020 Page 13 of 3 r COLORADO AIRS ID: 123 0277 at Public H ` lthbe°'„ro w, Attachment D Title V Operating Permit Form—OP-300 Series Forms OP-303 Tanks OP-306 Dehydrator OP-308 Liquid Loadout Enterprise Compressor Station COLORADO Form OP 303 Air Pollution Control Division r .ak,,,,, of'Ut+Mc Wai[h,,.,trcnretr'.'nrrt Storage Tanks Title V Operating 95OPWE103 AIRS ID Number: 123 - O277 - O63 Permit Number: 1. Instructions Included on the Colorado Air Pollution Control Website is an instruction sheet (Form OP-303A) for this storage tank form. Refer to the instruction sheet or contact the Division with questions. Any form with missing information may be determined administratively incomplete and may result in inability to grant the application shield of Regulation No. 3, Part C, Section II.B. Renewal and modification applications for equipment already included in the Title V permit are allowed to only complete portions of the form affected by the modification. Note that if using copy and paste; the applicant must paste as plain text. See "General Instructions" document for more details. 2. Storage Tank Information Facility Identifier P013 (example: S001) Date commenced construction: 1993 Date last modified/reconstructed: N/A Dates Date of first operation: 1993 Installation date of most recent storage vessel: 1993 Does this storage tank point include multiple storage vessels? I Yes ❑ No Number of Storage If yes, how many liquid manifolded storage vessels are contained in this storage tank Vessels point?8 Volume of storage vessel(s): 300 bbl x8 E Fixed Roof ❑ Internal Floating Roof ❑ External Floating Roof ❑ Domed External Floating Roof ❑ Variable Vapor Space ❑ Pressure Vessel Design Information ❑ Other (describe): Click here to enter text. (check all that apply) Are the storage vessels heated? ❑ Yes Z No Are the storage vessels blanketed? ❑ Yes C No If yes, indicate the type of blanket gas: Click here to enter text. Is there a separator located directly upstream of these storage vessels? ❑ Yes E No Separator Operating Temperature (`F): click here to enter the operating Upstream Separator temperature of the separator. Separator Operating Pressure (prig): click here enter the operating pressure of the separator. General Description 8x 300 bbl vertical fixed roof atmospheric stabilized condensate storage tanks of Equipment Yes ❑ No Underlying Permit Number: 19WE0492 Construction Permit General Permit (if applicable): Click here to enter type and package. Exemptions List any state exemptions that apply to these storage vessel(s) (See Instruction Sheet for more information): click here to enter text. Form Revised March 2020 Page 11 of 5 -. y COLORADO AIRS ID: 123-0277-063 r Departmen Mtc t of Bu :Nealth b Environment - COLORADO Form OP-303 Air Pollution Control Division G_SAVV'neM Of-Pubkc i-4 Itdl b Envir<X'arrcnt 3. Storage Tank Throughput a Contents Information Permit Throughput 202,848 bbl/year Limitation Throughput How is the throughput to these storage vessel(s) measured? Sales or haul tickets Monitoring Is the throughput divided evenly among the storage vessel(s)? r Yes ❑ No D N/A Maximum Reid Vapor Pressure (psig): 10 Vapor Pressure Maximum True Vapor Pressure (psia): 6.1 Flash Emissions Are flash emissions anticipated from these storage vessel(s)? ❑ Yes II No ❑x Condensate Average API gravity (degrees): 65.4 ❑ Crude Oil Average API gravity (degrees): Click cere to enter text ❑ Produced Water Estimated Hydrocarbon Content (%vol): click here to enter t. Physical Properties t"' (check all that ❑ Refined Product Stored: click here to enter text . apply) Petroleum Products Click here to enter a description of the liquids ❑ Other stored in this vessel. 4. State and Federal Regulations Rule Applicability How will you comply with this Regulation? 40 CFR Part 63 ❑ Subject Cl,'-•k here to enter text. Subpart R X❑ Not Subject 40 CFR Part 63 ❑ Subject Click here to enter text. Subpart CC 0 Not Subject 40 CFR Part 63 ❑ Subject Click here to enter text. Subpart HH a Not Subject 40 CFR Part 63 ❑ Subject Subpart BBBBBB Click here to enter text. P C Not Subject 40 CFR Part 63 ❑ Subject Subpart CCCCCC Click `.ere to enter text. P Not Subject 40 CFR Part 60 ❑ Subject Click here to enter text. Subpart K 0 Not Subject 40 CFR Part 60 ❑ Subject Click here to enter text. Subpart Ka 0 Not Subject 40 CFR Part 60 ❑ Subject Click here to enter text . Subpart Kb 0 Not Subject 40 CFR Part 60 ❑ Subject Click ere to enter text. Subpart OOOO 0 Not Subject Form Revised March 2020 Page 12 of 5 3 CO L o R A D O AIRS ID: 123-0277-063 D`P"""`"`° ttf, ..- !Nea14h b Envi�ommt COLORADO Form OP-303 Air Pollution Control Division ��W�� .. ,a*^ °;;?A Putts uxitrr:t+rn morn me 40 CFR Part 60 ❑ Subject Click here to enter- text. Subpart 0000a 0 Not Subject Colorado Regulation ❑ Subject Click here to enter text. No. 7 Part B Section 1 Not Subject Colorado Regulation ❑ Subject Click here- to entek text. No. 7 Part B Section II ❑, Not Subject Colorado Regulation ❑ Subject No. 7 Part B Section Click here to enter text. IV X Not Subject Colorado Regulation ❑ Subject Click here to enter text. No. 7 Part B Section V Z Not Subject Colorado Regulation ❑ Subject No. 7 Part D Section Click sere to enter text. I.C-I.F LI Not Subject Colorado Regulation ❑ Subject No. 7 Part D Section Click here to enter I.G L. Not Subject Colorado Regulation Z Subject Enclosed Combustor used for emissions control, recordkeeping, No. 7 Part D Section reporting Elre Not Subject P g L Subject Emissions are routed to enclosed combustor to achieve required Reasonably Available ❑ Not Subject DRE of 95% Control Technology (RACT) Note that the applicant may be asked to provide a RACT analysis if new or modified equipment in a nonattainment or attainment/maintenance area. Compliance Assurance ❑ Subject If subject, attach Form OP-203 CAM unless CAM has already been Monitoring (CAM) LI Not Subject addressed in the permit or a CAM plan is not due yet. Colorado Regulation ;x, Subject No. 1 Opacity These requirements are identified in Form OP-400. Requirements ❑ Not Subject Other (specify) Click here to enter Colorado Regulation No. ❑ Subject Colorado Regulation No. ❑ Subject 1 PM Requirements ❑x Not Subject 1 SO2 Requirements ❑x Not Subject Colorado Regulation No. ❑ Subject Colorado Regulation No. ❑ Subject 6 PM Requirements L, Not Subject 6 SO2 Requirements Z Not Subject 5. Control Device Information Is any emission control equipment or practice used to reduce emissions?. LI Yes ❑ No If yes, describe control device(s) below: Control Device Enclosed Combustor Description Form Revised March 2020 Page I 3 of 5 3 ;COLORADO AIRS ID: 123-0277-063 ',°ew",,rtme '°Environment jCOLORADO Form OP-303 Pollution Contort i)ivision 7 Pollutant PM PM10 PM2.5 SO2 NOx VOC CO Lead Enter Other Capture Efficiency Text Text Text Text Text 100% Text Text Text ' Control Efficiency Text Text Text Text Text 95% Text Text Text Controlled Individual All Enter Enter Enter Enter Enter Enter Enter HAP: HAPs HAP HAP HAP HAP HAP HAP HAP Enter HAP Capture Efficiency 100% Text Text Text Text Text Text Text Text Control Efficiency 95% Text Text Text Text Text Text Text Text 6. Criteria Pollutant Emission Information Emission Factor Source Uncontrolled Controlled Emission (e.g. AP-42, Uncontrolled Permitted Pollutant Emission EmissionPotential-to- Limitation Factors Factors Factors Units manufacturer, Emit (tpy) (tpy) source test, etc. PM EF EF LE Units EF Source 'ATE Limit PM10 EF EF' EF Units EF Source PIE :,unit PM2.5 EF EF EF Units EF Source PIE Limit SO2 EF EF EF Units EF Source PTE Limit NOx EF EF EP Units EF Source PTE Limit VOC 0.332 0.017 Lb/bbl AP-42 33.7 1.7 CO HP H- ._F Units EF Source PIE Limit Lead Li' EF EF Units EF Source PTE Limit Enter EF EF EF Units EF Source PTE Limit Po ll 7. Hazardous Air Pollutant(HAP) Emission Information Emission Uncontrolled Controlled Emission Factor Source Uncontrolled Permitted Pollutant Emission Emission Factors (e g AP 42, Potential-to- Limitation Factors Factors Units manufacturer, Emit (tpy) (tpy) source test, etc. Benzene 4.0 x 10-3 2.0 x 10-4 Lb/bbl Eng. Est. 0.41 0.02 Toluene 1.5 x 10-2 7.5 x 10 4 Lb/bbl Eng. Est. 1.52 0.08 Ethylbenzene 1.0 x 10-4 5.0 x 10'5 Lb/bbl Eng. Est. 0.10 0.01 Xylene 1.1 x 10-2 5.5 x 104 Lb/bbl Eng. Est. 1.12 0.06 n-Hexane 3.2 x 10-2 1.6 x 10-3 Lb/bbl Eng. Est. 3.25 0.16 2,2,4- oF EF a: :_rinis EF Source PTE Trimethylpentane Limit Methanol EF EF EF Units EF Source PIE Limit Form Revised March 2020 Page 14 of 5 , .COLORADO AIRS ID: 123-0277-063 _ 'Department et t��btic t[eatth ft Envuortment COLORADO Form OP-303 Air Pollution Control Division owe+ " i..'3v^' �':'4t'`'L,L+'.r.}f,e}!tt* £nw .>rxrt Enter HAP EF EF EU Units EF Source PTE Limit r8. Compliance and Monitoring I have filled out and attached Form OP-400 Compliance and Monitoring with all known applicable requirements for this emission unit: Z Yes ❑ No 9. Required Attachments The following must be attached in order for the application to be considered administratively complete (unless previously submitted): ❑ Simulation Model Inputs Et Emission Report (if applicable) • ProMax, HYSYS, EEtP Tanks, TANKS 4.0.9d, etc. ❑ Emission Calculations • Refer to instructions sheet for guidance ❑ Extended Liquids Analysis (if applicable) • Must include BTEX, n-Hexane Et methanol; sample temperature and pressure ❑ Flash Gas Liberation Analysis (if applicable; refer to PS Memo 17-01) • Must include sample, intermediate (if any) and final temperatures and pressures, flash gas volume, flash gas composition (including BTEX, n-Hexane, methanol and H2S), gas-to-oil ratio (GOR) and Reid Vapor Pressure (RVP) ❑ Manufacturer Specifications or Contract Guarantee for Control Equipment (if applicable) Form Revised March 2020 Page 15 of 5 °;, !COLORADO AIRS ID: 123-0277-063 }Sealthb Department hb O` ` Environment COLORADO Form OP-308 Mr Pollution Control Division '- MICr-• w't CtitP Ht,ltt,h&nrcat-rutrnt Liquid Loadout Title V Operating 950PWE103 AIRS ID Number: 123 - 0277 - 066 Permit Number: 1. Instructions Included on the Colorado Air Pollution Control Website is an instruction sheet (Form OP-308A) for this liquid loadout form. Refer to the instruction sheet or contact the Division with questions. Any form with missing information may be determined administratively incomplete and may result in inability to grant the application shield of Regulation No. 3, Part C, Section II.B. Renewal and modification applications for equipment already included in the Title V permit are allowed to only complete portions of the form affected by the modification. Note that if using copy and paste; the applicant must paste as plain text. See "General Instructions" document for more details. 2. Loadout Information Facility Identifier P016 (example: 5001) Date commenced construction: 1993 Dates Date commenced operation: 1993 Date last modified/reconstructed: N/A Underlying © Yes ❑ No Construction Permit Permit Number: 19WE0492 Exemptions List any state exemptions that apply to this loadout (See Instruction Sheet for more information): Clio_ rrere to enter text. General Description of Stabilized condensate atmospheric truck loadout rack Equipment Description of Vessel Tank trucks Liquid is Loaded Into 3. Specific Liquid Loadout Unit Characteristics Identify the most appropriate Section that best represents the liquid loadout source. Check that Section and provide the required information. ® Hydrocarbon Liquid Loadout Product Loaded Z Condensate ❑ Crude Oil ❑ Other (specify) click to enter text. Type of fill conducted Submerged ❑ Splash Are vapors displaced from cargo carrier? L Yes ❑ No If yes, fill out the information below Permitted Volume 202,848 bbl/yr Loaded 0.6 Saturation Factor Average Temperature of 58.16 deg F Bulk Liquid Loading Form Revised March 2020 Page 11 of 4 COLORADO AIRS ID: 123-0277-066 � Department of Public Health b Environment COLORADO Form OP-308 Air Pollution Control Division _>?t=."^ :Gd?uMc k4'Mtn 0 En•If xre'n.tt e True Vapor Pressure 4.65 Molecular Weight of 66 lb/lb-mol Displaced Vapors Are vapors are displaced from pressurized loading tines? ❑ Yes Z No If yes, fill out the information below Permitted Volume Click here to enter volume (bbl/year) . Loaded Product Density Click here to enter density (ib/ft-) Load Line Volume Clink here to enter volume (ft'/truckload). Vapor Recovery Line Click here to enter volume (ft'/truckload) . Volume Is this liquid loadout located at one of the following facilities? ❑ Terminal ❑ Bulk Plant. ❑ Gasoline Loadout Does this source load gasoline into transport vehicles? ❑ Yes ❑ No Type of fill conducted ❑ Submerged ❑ Splash Permitted Volume Click here to enter volume (bbl/year) Is this liquid loadout located at one of the following facilities? ❑ Terminal ❑ Bulk Plant ❑ Gasoline Dispensing Facility (GDF) ❑ Other Loadout Permitted Volume Loaded Click here to enter volume (bbl/year) . Description of Liquids Click here to enter description of liquids. Loaded 4. State and Federal Regulations Rule Applicability How will you comply with this Regulation? 40 CFR Part 63 ❑ Subject Click here to enter text. Subpart BBBBBB El Not Subject 40 CFR Part 63 ❑ Subject Subpart R lice_ here to enter text. P LI Not Subject 40 CFR Part 63 ❑ Subject Subpart CC Click __ere to enter text. P © Not Subject 40 CFR Part 63 ❑ Subject Click here to enter text. Subpart EEEE LII Not Subject 40 CFR Part 60 ❑ Subject Subpart XX Click here to enter text. P 0 Not Subject Colorado Regulation ❑ Subject No. 7 Part B Section Click here to enter text. IV LI Not Subject Form Revised March 2020 Page I 2 of 4 ;_ L COLORADO AIRS ID: 123-0277-066 Heaiihni tot Pu en 'Health b Encnrontnent COLORADO Form OP-308 Air Pollution Control 13iviston - iDA ''_•- C,erwr;wx U 3u 1+'.f!.altt in rx-r,nt Colorado Regulation ❑ Subject No. 7 Part B Section Click here to enter text. VII 0 Not Subject Colorado Regulation Z Subject Enclosed Combustor used for emissions control, recordkeeping, No. 7 Part D Section II.C.5 ❑ Not Subject reporting Z Subject Reasonably Available Submerged Fill ❑ Not Subject Control Technology (RACT) Note that the applicant may be asked to provide a RACT analysis if new or modified equipment in a nonattainment or attainment/maintenance area. Compliance ❑ Subject If subject, attach Form OP-203 CAM unless CAM has already been Assurance Monitoring Z (CAM) Z Not Subject addressed in the permit or a CAM plan is not due yet. Colorado Regulation E Subject No. 1 Opacity These requirements are identified in Form OP-400. Requirements ❑ Not Subject Other (specify) click here _ _._ eter text . Colorado Regulation No. ❑ Subject Colorado Regulation No. ❑ Subject 1 PM Requirements z Not Subject 1 SO2 Requirements Z Not Subject Colorado Regulation No. ❑ Subject Colorado Regulation No. ❑ Subject 6 PM Requirements Z Not Subject 6 SO2 Requirements Z Not Subject 5. Control Device Information Are there emission control device(s) or practice(s) used to reduce emissions? '�—Ix Yes ❑ No If yes, describe control device(s) below: Control Device Enclosed Combustor Description Pollutant PM PM10 PM2.s SO2 NOx VOC CO Lead E+`=e Other Capture Efficiency Text Text Text Text Text 100% Text Text 'text Control Efficiency Text Text Text Text Text 95% Text Text Text. Controlled All Enter Enter Enter Enter Enter Enter Enter Enter Individual HAP: HAPs HAP HAP HAP HAP HAP HAP H_P? HAP Capture Efficiency 100% Tent Text Tex Text Text Text Text Text Control Efficiency 95% Tent Text Text Text Text Text Text Text 6. Criteria Pollutant Emission Information For oil and gas hydrocarbon liquid loading facilities: are emissions calculated using the State approved emission factors? ❑ Yes Z No Pollutant Uncontrolled Controlled Emission Emission Uncontrolled Permitted Emission Emission Factors Units Factor Source Potential-to- Limitation Form Revised March 2020 Page 13 of 4 -r:_ :COLORADO AIRS ID: 123-0277-066 Department of tc m . !Wealth b Environment COLORADO Form OP-308 Air Pollution Control Division t -Icr:ci Puthc H afti'h E,eOrx,k t Factors Factors (e.g. AP-42, Emit (tpy) (tpy) manufacturer, source test, etc. PM EF EF EF Units EF Source PTE -Limit PM1© EF EF EF Units EF Source PTE Limit PM2.5 EF EF EF Units EF Source PTE Limit SO2 EF EF EE Units EF Source PTE Limit NOx EF EF EF Units EF Source PTE Limit VOC 0.186 0.009 Lb/bbl AP-42 18.8 0.94 CO Er EF EF Units EF Source PTE Limit Lead EF EF EF Units EF Source PTE Limit Enter EF EF Units EF source PTE Limit Pollutant 7. Hazardous Air Pollutant (HAP) Emission Information Emission Factor Source Uncontrolled Controlled Emission Uncontrolled Permitted Pollutant Emission Emission Factors (e.g. AP-42, Potential-to- Limitation manufacturer, Factors Factors Units source test, Emit (tpy) (tpy) etc. Benzene 5.16 x 10-4 2.58 x 10-5 Lb/bbl Eng. Est. 0.05 0.003 Toluene 6.34 x 10-4 3.17 x 10 5 Lb/bbl Eng. Est. 0.06 0.003 Ethylbenzene 1.78 x 10-5 8.90 x 10' Lb/bbl Eng. Est. 0.002 0.0001 Xylenes 9.62 x 10-5 4.81 x 10-6 Lb/bbl Eng. Est. 0.01 0.0005 n-Hexane 3.62 x 10-3 1.81 x 10'4 Lb/bbl Eng. Est. 0.37 0.018 Enter HAP EF EF EF Enits EF Source PTE Limit Enter HAP EF FE Er Units EF Source PTE Limit Enter HAP EF EF EF Units EF Source PTE Limit 8. Compliance and Monitoring I have filled out and attached Form OP-400 Compliance and Monitoring with all known applicable requirements for this emission unit: url�' Yes ❑ No 9. Required Attachments The following must be attached in order for the application to be considered administratively complete (unless previously submitted): ❑ Emission Calculations ❑ Manufacturer Specifications or Contract Guarantee for Control Equipment (if applicable) a Form Revised March 2020 Page 14 of 4 -•. COLORADO AIRS ID: 123-0277-066 °ep"""e6CO` �Health b Fsrris°nment geCOLORADO Form OP-306 Air Pollution Control Division >.;"t ter: i'Ut-`c Realty C Enviror,n,:rtt Glycol Dehydration Unit Title V Operating 950PWE103 AIRS ID Number: 123 - 0277 - 077 Permit Number: 1. Instructions Included on the Colorado Air Pollution Control Website is an instruction sheet (Form OP-306A) for this dehydration unit form. Refer to the instruction sheet or contact the Division with questions. Any form with missing information may be determined administratively incomplete and may result in inability to grant the application shield of Regulation No. 3, Part C, Section II.B. Renewal and modification applications for equipment already included in the Title V permit are allowed to only complete portions of the form affected by the modification. Note that if using copy and paste; the applicant must paste as plain text. See "General Instructions" document for more details. 2. Dehydration Unit Information Facility Identifier D-3 (example: 5001) Manufacturer Manufacturer Manufacturer Dehydration Unit Information TBD TBD TBD Date commenced construction: TBD Dates Date commenced operation: TBD Date last modified/reconstructed: N/A Underlying Yes ❑ No Construction Permit Permit Number: 19WE0492 Exemptions List any state exemptions that apply to this dehydration unit (See Instruction Sheet for more information): Cliok here to enter text. 3. Dehydration Unit Characteristics General Description 145 MMscfd TEG Dehydration Unit for water removal of equipment Type of Glycol Used ❑ Ethylene Glycol (EG) ❑ Diethylene Glycol (DEG) LI Triethylene Glycol (TEG) Number of Pumps: 2 (1 primary + 1 backup) Pump Type: LI Electric ❑ Gas Pump Information If gas, provide the injection pump ratio: Click here to enter text. Pump Make and Model: FMC Triplex / TBD Maximum (gpm): 25 Glycol Circulation Permitted (gpm): 25 Rate How is the circulation rate measured? Glycol flow meter, or assume max design pump rate Design Capacity (MMscf/day): 145 Throughput Wet Gas Throughput Limitation (MMscf/year): 52,925 Emission Information Condenser Is control being claimed for a condenser? ❑ Yes LI No Form Revised March 2020 Page 11 of 4 COLORADO AIRS ID: 123-0277-077 Departmen`ot Public Health&Environment v...i.rv't COLORADO Form OP-306 Air Pollution Control Division spur otrurzmom+3f Kit.`,c Hems%v E.nwww.x-:2 If yes, provide maximum condenser outlet temperature (°F): click here to enter text. Does this unit operate with a flash tank? 0 Yes ❑ No Flash Tank Are pre-control flash tank emissions metered? ❑ Yes 0 No Where are flash tank emissions routed? Recycled to inlet via VRU. Sent to enclosed combustor during 5.0%annual VRU downtime Are pre-control still vent emissions metered? ❑ Yes 0 No Still Vent Where are still vent emissions routed? Enclosed Combustor. Sent to atmosphere during 1.0% annual combustor downtime. 4. Reboiler Information ❑ Check this box if the dehydration unit is not equipped with a direct-fired reboiler. If a direct-fired reboiler is not used in this dehydration unit, leave the rest of this section blank. Maximum Design Rating (MMBtu/hr): 1.5 Fuel: Residue Natural Gas Is the reboiler subject to additional regulatory requirements (e.g. NSPS Dc): No 5. State and Federal Regulations Rule Applicability How will you comply with this Regulation? 40 CFR Part 63 0 Subject Subpart HH L-Opt Determination, Recordkeeping, Reporting p ❑ Not Subject 40 CFR Part 63 ❑ Subject Click here to enter text. Subpart HHH 0 Not Subject Colorado Regulation 0 Subject Enclosed combustor used for still vent control, and flash tank No. 7 Part D Section control during VRU downtime 5% , recordkeeping,, reporting I.H ❑ Not Subject ( ) P� g P g Colorado Regulation 0 Subject Enclosed combustor used for still vent control, and flash tank No. 7 Part D Section control during VRU downtime 5% recordkeeping, reporting II.D � Not Subject { ), P� g� P g 0 Subject Enclosed Combustor used for still vent control and flash tank Reasonably Available control during VRU downtime will achieve 95% descturction Control Technology ❑ Not Subject efficiency. (RACT) Note that the applicant may be asked to provide a RACT analysis if new or modified equipment in a nonattainment or attainment/maintenance area. Compliance Assurance 0 Subject If subject, attach Form OP-203 CAM unless CAM has already been Monitoring (CAM) ❑ Not Subject addressed in the permit or a CAM plan is not due yet. Colorado Regulation 0 Subject No. 1 Opacity These requirements are identified in Form OP-400. Not Subject Requirements Other (specify) Click here to enter text. Colorado Regulation No. 1 ❑ Subject Colorado Regulation No. ❑ Subject PM Requirements 1 SO2 Requirements Form Revised March 2020 Page I 2 of 4 x ,COLORADO AIRS ID: 123-0277-077 Department E " COLORADO Form OP-306 L Air Pollution Control Division fi`4" 2gvn^k',r;,d rutec F4n th,Env nrrt Z Not Subject Z Not Subject Colorado Regulation No. 6 ❑ Subject Colorado Regulation No. ❑ Subject PM Requirements ❑ Not Subject 6 SO2 Requirements ® Not Subject 6. Control Device Information Is any emission control equipment or practice used to reduce emissions? ' Yes ❑ No If yes, describe control device(s) below: Control Device Enclosed Combustor Description Pollutant PM PM10 PM2.5 SO2 NOx VOC CO Lead Enter Other Control Efficiency Text Text Text Text Text 95% Text Text Text Controlled All Enter Enter Enter Enter Er er Enter Enter Enter Individual HAP: HAPs HAP HAP HAP HAP F= HAS HAP HAP Control Efficiency 95% Text Text Text Text Text Text Text Text 7. Criteria Pollutant Emission Information Emission Factor Uncontrolled Controlled Emission Source Uncontrolled Permitted Pollutant Emission Emission Factors (e.g. AP-42, Potential-to- Limitation Factors Factors Units manufacturer, Emit (tpy) (tpy) source test, etc. PM EF EP EF. Units E. Source PTE Limit PM10 EF EP EF Units EF Source PTE Limit PM2.5 EF EF EF mils EP Source PTE Limit 5O2 EF EF EF _;nits EF Source PTE Limit NOx 0.068 0.068 Lb/MMBtu AP-42 1.5 1.5 VOC 22.96 0.83 Lb/MMscf GLYCaIc 644.9 24.0 CO 0.31 0.31 Lb/MMBtu AP-42 6.7 6.7 Enter Pollutant EF E_ EF Units Source PTE Limit Po 1 8. Hazardous Air Pollutant (HAP) Emission Information Emission Uncontrolled Controlled Emission Factor Source Uncontrolled Permitted (e.g. AP-42, Pollutant Emission Emission Factors Potential-to- Limitation manufacturer, Factors Factors Units source test, Emit (tpy) (tpy) etc. Benzene 2.52 0.15 Lb/MMscf GLYCalc 66.64 3.89 Toluene 3.77 0.22 Lb/MMscf GLYCalc 99.81 5.88 Ethylbenzene 0.12 0.01 Lb/MMscf GLYCalc 3.11 0.18 Form Revised March 2020 Page I 3 of 4 e, ., COLORADO AIRS ID: 123-0277-077 eatthb neo.Ablie Xwt�G b Enviw..mena COLORADO Form OP-306 Air Pollution Control Division Xytene 0.87 0.05 Lb/MMscf GLYCalc 22.89 1.36 n-Hexane 0.47 0.02 Lb/MMscf GLYCalc 12.42 0.43 2,2,4- 0.0003 0.00001 Lb/MMscf GLYCalc 0.01 0.0003 , Trimethylpentane Methanol 0.003 0.0001 Lb/MMscf GLYCalc 0.08 0.003 Enter HAP EF SF EF Units EF Source PTE Limit 9. Compliance and Monitoring I have fitted out and attached Form OP-400 Compliance and Monitoring with all known applicable requirements for this emission unit: F.Z, Yes ❑ No 10. Required Attachments The following must be attached in order for the application to be considered administratively complete (unless previously submitted): ❑ GRI-GLYCalc 4.0 Input Report Ee Aggregate Report (or equivalent simulation report/test results) ❑ Extended gas analysis • Must include BTEX, n-Hexane, 2,2,4-Trimethylpentane, sample temperature and sample pressure ❑ Emission Calculations ❑ Manufacturer Specifications or Contract Guarantee for Control Equipment (if applicable) Form Revised March 2020 Page I 4 of 4 COLORADO AIRS ID: 123-0277-077 Depxrtmene°truher Heakt,bE,v o ern Attachment E Title V Operating Permit Form—OP-400 Series Forms OP-400 Compliance and Monitoring—Tanks OP-400 Compliance and Monitoring - Dehydrator OP-400 Compliance and Monitoring—Liquid Loadout Enterprise Compressor Station I COLORADO Form OP-400 Air Pollution Control Division DerArtmM C. PlAD4C,kcalr^, Ermror-.ytt Compliance and Monitoring Title V Operating 95OPWE103 AIRS ID Number: 123 - 0277 - 063 Permit Number: 1. Instructions Complete this form and attach it to the completed corresponding OP-300 series form for the applicable emission unit. Each OP-300 series form must be accompanied by a Compliance and Monitoring form (OP-400). Refer to the instruction sheet or contact the Division with questions. Any form with missing information may be determined administratively incomplete and may result in inability to grant the application shield of Regulation No. 3, Part C, Section II.B. Renewal and modification applications for equipment already included in the Title V permit are allowed to only complete portions of the form affected by the modification. Note that if using copy and paste; the applicant must paste as plain text. See "General Instructions" document for more details. 2. Emission Unit Information Facility Identifier P013 (example: S001) 3. Applicable Requirements Identify each applicable requirement for the emission unit, any associated compliance monitoring, recordkeeping, and reporting requirements, and the basis for the requirement. If more space is needed, attach additional descriptions. Emission Limitations (tpy, lb/hr, lb/MMBtu, gr/dscf, etc.) VOC - 1.7 tpy, Basis: Construction Permit 19WE0492 Monthly recordkeeping and twelve month rolling total calculations Opacity These requirements apply specifically to the enclosed combustor used for emissions control. Not to exceed 30% for a period or periods aggregating more than six (6) minutes in any sixty (60) consecutive minutes, Basis: Construction Permit 19WE0492 Compliance will be presumed in the absence of credible evidence to the contrary. Form Revised March 2020 Page 11 of 3 ; COLORADO AIRS ID: 123-0277-063 • Department al Public Health 6 Environment COLORADO Form OP-400 Air Pollution Control Division an+ ,.'g�yeT.v^ea v"4 Put:4 400 ft ,trpnrcoymmt Operational Limitation(s) (hrs/yr, MMscf/yr, lb/yr, etc.) Condensate Throughput - 202,848 bbl/yr, Basis: Construction Permit 19WE0492 Monthly recordkeeping and twelve month rolling total calculations. Monthly throughput determined from sales or haul tickets. Other Requirements List all other applicable requirements for this emission point. Extended Liquids Analysis - Every 5 Years - Used for verification of VOC lb/bbl emission factor using AP-42 Chapter 7 calculation methodologies. Control Device Requirements - pilot light shall be present at all times and monitored through either a thermocouple or backup daily visual inspection. Daily visible emission observations required, with follow up Method 22's or Method 9's as required. Statewide Controls for Oil and Gas Operations - This source is subject to the emission control, recordkeeping, and reporting requirements detailed under Regulation 7, Part D, Sections I.I. and II.C. Annual Method 9 Opacity Test - combustor used for emissions control 4. Monitoring Requirements Complete the following monitoring questions about the emission unit. Continuous Emission Monitoring Requirements? ❑ Yes No Pollutant(s) or Parameter(s): - . Requirement(s): zr,L _. ❑ Continuous Emission Monitoring System (CEMS) ❑ Predictive Emission Monitoring System (PEMS) • Continuous Emission Rate Monitoring System (CERMS) El Other (describe): Lc, e,_t c Periodic Compliance Testing? ❑ Yes El No Pollutant(s): t . Frequency: Date of last Division-approved test -. Other? E Yes E No Describe: Extended Liquids Analysis Frequency: Every 5 Years Form Revised March 2020 Page 1 2 of 3 COLORADO AIRS ID: 123-0277-063 ptit of Rrdtc -_Health b Enment vuonmml Sincerely, ES) Elie Chavez Engineer, Operating Permit Unit Stationary Sources Program Air Pollution Control Division x., COLORADO 4. �„,rte Department of Public �� Health&Environment June 12, 2020 Roshini Shankaran Senior Environmental Engineer DCP Operating Company, LP 370 17th Street, Suite 2500 Denver, CO 80202 RE: DCP Operating Company, LP - Enterprise Compressor Station, FID: 123-0277, OP: 95OPWE103 SUBJECT: Draft Renewal Operating Permit Dear Ms.Shankaran: Enclosed please find a draft of the renewal operating permit for your facility as well as a copy of the technical review summary document. Please review and submit any comments you may have concerning the modified draft operating permit. Following our review of your comments, we will send the draft permit out for a 30-day Public Comment period and then to EPA for their 45-day review period. The regulations also require that the applicant receive written notice of their right to a formal hearing before the Colorado Air Quality Control Commission at the same time that the Public Comment packet goes out. You will receive a separate letter containing that information. This draft renewal permit contains the modifications that you requested in your renewal application received July 26, 2016, the requirements contained in Colorado Construction Permit 19WE0094 and 19WE0492, and the additional information received April 26, 2016, November 20, 2018 and June 1, 2020. The permit was also revised to be more consistent with recently issued permits, correct errors, omissions and discrepancies identified during inspections and/or review of the renewal application and incorporate EPA comments made on other operating permits for similar sources. The changes are summarized in the technical review document for the renewal permit. Upon conclusion of source review, please provide the following: 1. A cover letter requesting the cancellation of the modification application submitted January 26, 2018. This application was not incorporated into the operating permit, as requested in source correspondence received February 28, 2020. We would like you to review this permit by Friday, September 11, 2020. We suggest that in the interest of expediency you call or arrange to meet with your review engineer concerning any questions or concerns you may have, although you may submit written comments if you like. Please do not hesitate to contact me if you have any questions at (303) 692-6332 or elie.chavez@state.co.us. j.-at COtaN;. 4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303-692-2000 www.cotorado.gov/cdphe !F4 , ,t ',?; Jared Potts, Governor I Jill Hunsaker Ryan,MPH, Executive Director r* r f* 11/30/2020 State.co.us Executive Branch Mail-DCP Enterprise Source Review de-7p Midstream From:Chavez-CDPHE,Elie<ehe.chavezf@state.co us> Sent:Thursday,November 12,2020 7:15 AM To:Shankaran,Roshini<RShankaran©dcpmidstream.com> Subject:Re:[EXTERNAL]Re:DCP Enterprise Source Review • ix*Vi.. : originated f.o.. )l' r t i .. �. ., sender. .� a.ax. WARNING:This email t ibmat�il from outside r t DCP Midstream,D f not click links r I open attachments unless you recognize rol,nizc Nx al ride r and Lnula the content is sale.Safety and security start's with each ans. That perfect-thank you so much;I super appreciate it.I know you guys are all extremely busy with the new T5s and ROPE stuff,plus it's about to be the holidays and I know how that goes.Our supervisors are leaning on us to get what we can off of our desks this year in preparation for next,hence the poke.But thank you again-I really appreciate it. Elie Chavez Permit Engineer Title V Operating Permit Unit Stationary Sources Program Air Pollution Control Division ;COLORADO • e l Air Pollution Control Division i Department of Pusic HCWth s£nwonment P 303.692.6332 4300 Cherry Creek Drive South,Denver CO 80246-1530 elie.chavezipstate_co us I w,color,,9„do c3 !c6pihetehccf Are you curious about ground-level ozone in Colorado?Visit our ozone webpage to learn more. On Wed,Nov 11,2020 at 1:16 PM Shankaran,Roshini<RShankaren@dcpmidstream.com>wrote: Hi Elie—We will have comments over to you by the end of the week. Sorry it took so long to gather the troops. 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 dcpp Midstream From:Chavez-CDPHE,Elie<elie.chavez testate.co os> Sent:Monday,November 9,2020 12:07 PM https://mail.google.com/mail/u/0?ik=85031f40e8&view=pt&search=all&permmsgid=msg-f%3A1683283273839694185&simpl=msg-f%3A1683283273839694185 6/18 11/30/2020 State.co.us Executive Branch Mail-DCP Enterprise Source Review Appendix C- Required Format for Annual Compliance Certification Report No Comments f [, Appendix D- Notification Addresses. j c ! i No Comments Ii Appendix E- I Permit '',Acronyms No Comments !Appendix F- I Permit Modifications Appendix G- CAM Plans Appendix G 26 i CAM D-2 Please update the control technology description to the following:"Enclosed combustion device(COMB-1)for still vent emission control and flash tank emissions during VRU downtime. and the VRU:3 expencwr,,;ng d..;. ,..ea flash Updated Appendix G 29 CAM D-3 Please update the control technology description to the following:"Enclosed combustion device(COMB-1)for still vent emission control and flash tank emissions during VRU downtime.-aa - "Updated_ Appendix H- Applicability Reports No Comments Thanks, Roshini Roshini Shankaran Environmental Engineer—Weld County DCP Midstream 370 1 7tt'Street.Suite 2500 Denver.CO 80202 Office 303-605-2039 Cell:720-391-7005 https://mail.google.com/mail/u/0?ik=85031f40e8&view=pt&search=all&permmsgid=msg-f%3A1683283273839694185&simpl=msg-f%3A1683283273839694185 5/18 11/30/2020 State.co.us Executive Branch Mail-DCP Enterprise Source Review mod,but I wouldn't be able to process the minor mod prior to the OP issuance,since the CP Isn't technically"Incorporated"irito the OP until it's issued.Since you have 80 days,I believe the application would be due prior to OP issuance,so I don't think we can go the minor mod route.Let me know if you'd like to discuss further.Handled sepaaretoi,y MACTHH-HAP limitations II 127 9.1,9.2 MACT HH HAPs Are both condition 9.1 and 9.2 required?The only difference is that 9.2 includes the monthly limits,but the language is clear that these are only required for the first year.Condition 9.1 addresses currently operating Th,G dehydration unit O-2 and Condition 9.2 addresses D-3.i had meant that Condition 9.1 apply until D-3 commences operation and Condition 9.2 to apply thereafter I added the following language to Condition 9.1 and 9.2 to clarify this point-let me know if this helps:ibis Condition 9.1 only.shall apply to the Stabilized(:nndr'irs:ate Storage Ranks(AIRS O63).Produced Water Storage'Ranks(AIRS 0'5)and'TR11)r/(ydratinrr('nil 1)-2 OW 068)areal 17/(/Dail/mr/on(hsit D-3(,'AILS 07;) commences operation,tiller ru/trch compliance a r1/t this C'onilition 9.1 i.e tint linger required and I'otubtian 9.2 only shall apply.AND This Condition 9.2 only shall aplrl)' to the Stabilized Condensate Storage:kinks(AIRS 063),Produced Water Storage Rinks(:-(IRS 0;5)and''/'1.21 Dehydration Unit 1.)-3(AIRS 0'7)agaon commencement of r ;operation of 1'6i';Dehydration f but l)-3(AIRS(177).Compliance with this('nndttrnn 9.2 is not rcytnred until?/2;1)ehydratton Ifni(I)-3(AIRS t']77)commences operation,afterrehichCondition9.1s/raflnolongerupply.i,>>,.t.,r Facilitywide No Comments ! i Portable Monitoring No Comments Compliance Assurance Monitoring (CAM) i f II • 150 12.1.8.3 CAM The formatting is off for this condition,please adjust the indentation Done.Thank,you for catching that Permit Shield • I � ---"—'------I-- — -------- No Comments General Permit Conditions Appendix A- Inspection Information N/A 3 4 List of Insignificant Please add facilitywide fugitive emissions to the list of insignificant activities at this facility. Because these fugitive emissions are subject to Reg 7.Part D,Section I.L and II.E.,requirements, Activities we don't consider them to be an"insignificant activity"pursuant to Reg 3,Part C.Section ILE..since"(n)one of the exerr'ntpions below...shall apply fl'by taking such exemption a source would avoid any secific federal or state applicable requirement..."Although the fugitive emissions are w de minimis.Title V interprets Reg 3,Part C,Section IL E.to preclude an insignificant activity exemption from being taken(and listed in Appendix A)if the emissions source is subject to any Reg 7 requrlement. •err, ans^make,sec ns,v N/A 3 4 I List of Insignificant Sump 1 and Sump 2(Two(2)80 bbl Produced Water Sumps)have been added to this permit as a non-insignificant source,and should be removed from this list.Done.Thank you for Activities catching this! Appendix B- Reporting Requirements and Definitions I 1 No Comments t _I hops://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1683283273839694185&simpl=msg-f%3A1683283273839694185 4/18 11/30/2020 State.co.us Executive Branch Mail-DCP Enterprise Source Review II 82 4,6 D-3 The parametric monitoring for unit D-3 includes weekly monitoring of the condenser outlet temperature.DCP requests that this condition be removed,as the condenser is no longer used to claim emissions control for this source.As with D-2,I'd included this because in the application for 19WE0492,the heat content of the still vent stream exiting the condenser was used to calculate combustion emissions for 0-3.Since the condenser temperature is used to calculate emissions,I'd kept the condenser outlet temp monitoring from the CP Same c<amma nt as D-2 • II 83 4.7.2 D-3/COMB-1' COMB-1 runtime status is used to determine hours of operation,rather than pilot light indication.Please revise this condition to reflect this method of monitoring.See 3.7.2 comment above. • • II 83 4.7.4 D-3/COMB-1 COMB-1 runtime status AND D-3 runtime status will be used to determine combustor downtime,rather than pilot light indication.Downtime is defined as periods where COMB-1 is offline but • D-3 is online.Please revise this condition to reflect this method of monitoring.Again.this might change a little depending on your 3.7.2 answer.but for now,does this sound ok?Hours pf: downtime.shall fin determined using the rbtferr'n,,r between the 1)-3 nun tililtvlt,crsrequiredlit'I.'nnefiru,et-i_;".I,rand C f 1,51/3—I burl shutss,as required 1),,IL .; ./.7.I. t 2/iI!' /pilot light uldinrtina 6-2 II 84 4.9.2.3 0-3/COMB-1 This requirement,to monitor liquid levels in the knockout vessel prior to COMB-1,comes from Colorado Regulation 7,Section II,Part II.C.1.d.(vii).,and the applicability is specific to"storage tanks subject to Section II.C.1."per Condition II.C.1.d.Because COMB-1 is not being used to control a storage vessel subject to these requirements,DCP suggests that this knockout vessel monitoring is NOT applicable to COMB-1 and requests deleting this requirement.See 3.9.2.3 comment.Would monthly monitoring be ok?Sarre comment as Li-2 P-016 II 98 5.1.1.1 Truck Loadout- The compliance calculation detailed in this condition has a minor error."CE(%)"should be updated to"(1-CE(%))"to accurately reflect the emission calculation methodology for this source.Done.Thank you for catching this! II 99 5.3 I Truck Loadout DCP suggests that liquid parameters will not change enough year over year to merit annual liquid sampling.This loadout rack will only be handling stabilized condensate with consistent properties.DCP requests that compliance continue to be demonstrated using the existing HAP emission factors detailed in condition 5.1.2.I would prefer to keep some kind of periodic monitoring in to ensure the emission factors are still valid.Would a once every 5 year sample be or-fhb,maids quad to us 104 5.8.1.2(e) Truck Loadout DCP suggests this condition should include"...must retain records for(2)two years"For Title V,we streamline these 2 year records retention requirements in Rag 7(and federal regs,like NSPS Dc)out of the operating permit in favor of the 5 year Title V record retention requirement of Reg 3,Part C.Section V.C.6.,just because it's more stringent.The Reg 7,Part D,Section II.C.5.a.(v)2 year requirement is therefore listed in the streamlining table in Section III of the permit. P-013 II 98 6.1,1.1 Condensate Tanks The compliance calculation detailed in this condition has a minor error."CE(%)"should be updated to"(1-CE(%))"to accurately reflect the emission calculation methodology for this source. Done.Thank you for catching this! II 99 6.3 Condensate Tanks DCP suggests that liquid parameters will not change enough year over year to merit annual liquid sampling.The storage tanks will only be storing stabilized condensate with consistent properties.DCP requests that compliance continue to be demonstrated using the existing HAP emission factors detailed in condition 6.1.2.I would prefer to keep some kind of periodic monitoring in to ensure the emission factors are still valid.Would a once every 5 year sample be ok?This sounds good to us II 111 6.6.2.2 Condensate Tanks It appears this condition is missing the last sentence,based on a comparison to the underlying Colorado Regulation 7 requirement.Is this referring to Condition 6.6.2.3?I think 6.62.2 looks ok,but I did leave off the pail of Reg'7 in 6.6.2.;'that requires combustion devices to have a ORE of 96%,except where the device was authorized by permit prior to 5/1/2014.I'd originally done this because this combustor was permitted prior to 2014,but I can absolutely put that last sentence back in for clarity-just let me know!I crari I tall v"I at was nvswi04 here.I rhaik thm sounds good as'`- SUMP-1/2 II 121 7.1 PW Sumps DCP is requesting minor updates to the emission calculations for this source.In order to account for variability in the annual Flash Liberation analysis,DCP is adding a 30%buffer to the flash emission factors for both VOC and HAP pollutants.There is no proposed changes to either the working/breathing emission talcs,or to the underlying regulatory applicability to this source. DCP has provided revised emission calculations alongside these comments,reflecting this update. Please update the emission limit and corresponding emission factors.Done-I updated the emission limit to 1.9,VOC EF to 0.28 and n-Hexane EF to 0.026.Let me know if those limits and factors look ok to you.To prevent a massive email being attached to the redlined APEN, I'm sending you a separate email with the draft APEN for you to review.Handled separately • COMB-BD • II 124 8,5 COMB-BD The self-certification for this permit was submitted to the Division on 8/31/2020.DCP was unable to successfully self certify based on the updated EGA sampling performed.The underlying CP requires that an application be submitted within 60 days to modify the permit to adjust the permitted lb/event emission factors when self-certification is not possible.DCP wanted to see • how you'd like us to approach this application,considering the existing CP has already been incorporated into the TV permit DCP will retain the existing VOC limit for this source by decreasing the limit on#of events per year.Please let us know if it would be possible to address this update in the Title V permit without modifying the underlying CP and if this would be a • • minor modification or significant modification and we will provide this within the 60 day deadline outline in the underlying CP.I believe this can be done as a significant modification to the OR • • I'd like to have this in the permit before it goes to public notice.if that's ok with you,or else it would probably be easier/faster to get a CP mod.I think it would technically qualify as a-minor • • https://ma il.g oog le.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%341683283273839694185&simpl=msg-f%341683283273839694185 3/18 11/30/2020 State.co.us Executive Branch Mail-DCP Enterprise Source Review upplir'u/11x'1 /'or any period dorm Mhte'/i fin'lean g/t'tiif circulation rich i•at11'1O1 t1.'of/alile'r1/ruin/he,'g/1i,i1.11,1win.'ti'r the maximum permitted g/?'(rail(•irt'ril,trlort • rate(wed In,s unruw:f /iuh/e-/uGot•c'shall he rise',.!Pei ordt of the,Girt'burr glrcol circulation rate shall be maintained anti ankle available to the 1)tt'is'inri upon request. i .And then I deleted subcondition 3 4.'I which had the pump stroke requirements Let me know if thus looks ok to you ''•'• . • II 60 3.6 D-2 .The parametric monitoring for unit D-2 includes weekly monitoring of the condenser outlet temperature.DCP requests that this condition be removed,as the condenser is no longer used to 'claim emissions control for this source.I'd included this because in the 11/2018 calculations in the D-2 mod.the heat content of the still vent stream exiting the condenser was used to calculate combustion emissions for 0-2 Since the condenser temperature is used to calculate emissions,I'd added the condenser temperature monitoring to the OP I'd prefer to maintain this monitoring • II 60. 3.7.2 D-2 I COMB-1 COMB-1 runtime status is used to determine hours of operation,rather than pilot light indication.Please revise this condition to reflect this method of monitoring.How is combustor run-time status determined-basically,what is it looking at to determine if the combustor is running or not?Is it looking at the pilot light or does it depend on something else'?Is it a local indication or does it teed back through the DOS'?I think this change is probably tine,t lust want to understand now the runtime status works and why it's a better indication of operation as opposed to the punt light My only concern is in instances where the pilot light is off but run status indicates the combustor is on so it would appear that downtime is not occunng.however.emissions would . not be getting destructed . • 'II 60 3.7.2 D-2 COMB-1 hours of operation are determined using combustor run status indication,rather than pilot light indication.Is this comment about the same issue as the previous comment'?It looks • like they're both referencing Condition 3 7.2,but I want to make sure I'm not missing something • .II 61: 3.7.4 D-2/COMB-1 .COMB-1 runtime status AND D-2 runtime status are used to determine combustor downtime,rather than pilot light indication.Downtime is defined as periods where COMB-1 is o fine but D- 2 is online.Please revise this condition to reflect this method of monitoring.This might change a little depending on your 3 7 2 answer,but for now,does this sound ok?/lours nl drncrillntt' shall he determined uring the(Gliel-enc.,'between lilt 1)-2 rim rtutt,r.in required it(•,ui,Surer 1-1,and r'!).111t-1 run s/u/us.a r,'.lt ui ?h/•un,fiuu,t i-.? ('11.1//t / G',1 if lralu unliriiar,ir II 62 j 3.9.2.3 D-2/COMB-1 This requirement,to monitor liquid levels in the knockout vessel prior to COMB-1,comes from Colorado Regulation 7,Section II,Pert II.C.1.d.(vii).,and the applicability is specific to"storage ' •tanks subject to Section II.C.1."per Condition II.C.1.d.Because COMB-1 is not being used to control a storage vessel subject to these requirements,DCP suggests that this knockout vessel monitoring is NOT applicable to COMB-1 and requests deleting this requirement.We've started including this in T5 permits as a standard condition for anything that has a combustor as • liquid carryover from any knokout drum would cause smoking at the combustor However,I do think liquid carryover at a combustor dedicated to a dehy would have less potential for liquid buildup than to a combustor dedicated to tanks-would it he ok if I backed true frequency down to monthly'? TEG Dehy Unit D-3 i 'II 76 I 4.1.2.D-3/COMB-1 Ratio of Actual FHV to AP-42 FHV- DCP requests that this portion of the calculation be removed,to keep this Title V permit consistent with similar requirement in DCP's other active TV permits.Removed and updated EGA Conditions 4.5 2 and 4 10 4 3 to refer to only the assist gas.for clarity II 78 4.2.2 D-3/COMB-1 Ratio of Actual FHV to AP-42 FHV- DCP requests that this portion of the calculation be removed,to keep this Title V permit consistent with similar requirement in DCP's other active TV . permits.Removed and updated EGA Conditions 4 5 2 and 4 10 4.3 to refer to only the assist gas for clarity. II 81 4.3.2.2 D-3/COMB-1 DCP requests an alternative method of compliance tracking for the assist gas volume throughput to COMB-1.Rather than metering this value,DCP will assume the entire potential flowrate of 3,200 scf/hr is being directed to COMB-1 during ANY use of assist gas at this facility.See 3 3 2 2 comment above. II 81: 4.4.1.D-3 Unit D-3 will be equipped with an electric glycol pump.Pump strokes per minute cannot be used as a method of monitoring for an electric pump.DCP suggests that this condition be modified i I I to allow the use of the maximum permitted glycol circulation rate when a value cannot be obtained from the glycol flowmeter.Updated to the following: "l ire lean,If/y,vi!jloura/e quail be I ii't tinted&Illi'tisiri,,It r;ll'rrilllutvlrra'lc'r•The ric•urtlyd Jlnurcttt sl1ir11 be the sent of the lint,•rutc'IMin(kWh pump unit all other glycol tpletvini points(II u/luluuh/e) 1'uur ant.period during,re/ia/i the leuu gft'col,•lrr ulutunlr MIL'cuililiu/he obtained burr the glycol 1lem mr'i,'i;the nuernnuut pdr77111101Iran glyiz,l t'In 1r/aili'n rare/tu<<1 in "ruumary lable 4 a/rou'shrill he trail 1/sr aids u//ht tidily WW1 e/i tab,'irctilutron nut shin/he nrcruu,une,l iunl nrudir urar/uhl'n,the 1)icisinrt a/run reyue.u.,end then I deleted subcondition 4 4.1 which had the pump stroke requirements.Let me know if this looks ok to you https://mail.google.com/mail/u/0?ik=85031f40e8&view=pt&search=all&permmsgid=msg-f%3A16832832738396941858,simpl=msg-f%3A1683283273839694185 2/18 11/30/2020 State.co.us Executive Branch Mail-DCP Enterprise Source Review err" •, STATE OF Chavez-CDPHE,Elie<elie.chavez@state.co.us> coLOSADO • DCP Enterprise Source Review • Shankaran,Roshini<RShankaran@dcpmidstream.com> Fri,Nov 13,2020 at 2:44 PM To:"Chavez-CDPHE,Elie"<elie.chavez@state.co.us> • Hi Elie, I am copy/pasting the table from below with your comments and adding my comments in green, Also attached is the minor mod cancellation letter.I hope this resolves this list,but please let me know if you have any further questions. Permit Section Draft Page# Condition# Process Unit DCP Requested Corrections/Comments 1 1 1.1 Process Description DCP is requesting slight revisions to the control equipment descriptions in Paragraph 4 of the Process Description for this facility: "...one(1)enclosed combustion device(COMB-1)permitted 1%downtime to control the dehydration unit still vent emissions and permitted to control flash tank emissions during VRU downtime(permitted 5%),o,td,;f the YRU ix cuper;cncing doe,,t;,nc,flash tonic crniaaiona,and one(1)enclosed combustion device to control the stabilized condensate storage tank and loadout emissions."Updated as requested. 3 2.1 Glycol Pump ADS DCP requests that the Glycol Pump AOS provisions be updated to include the existing TEG Dehy unit,D-2.Done.I copied the D-3 AOS condition exactly for D-2 and updated Section 1, Condition 2,1 to refer to both D-2 and D-3. C-238,C-235,C- • 236,C-234 • No Comments C-237 • II 28 2.1,2.2 C-237 DCP is preparing a TV significant modification application to drop the NOx and VOC emission limits for this engine to below 25 tpy each,allowing continued use of the permanent AOS provisions in this permit.This decreased emission limit will be the only change for this engine.There will be no change in regulatory applicability,or other requirements.DCP will aim to submit this application next week.Sounds good-I will incorporate once I receive the mod and update the TRD accordingly.To close its,= d'is no longer submitting a sig mod applical≥on and will retain the currently permitted Iirnd t I'or this,,algae TEG Dehy Unit D-2 • II 54 3.1.2 D-2/COMB-1 Ratio of Actual FHV to AP-42 FHV- DCP requests that this portion of the calculation be removed,to keep this Title V permit consistent with similar requirement in DCP's other active TV permits.Removed and updated EGA Condition 3.5.2 to refer to only the assist gas,for clarity. II 56 3.2.2 D-2/COMB-1 Ratio of Actual FHV to AP-42 FHV- DCP requests that this portion of the calculation be removed,to keep this Title V permit consistent with similar requirement in DCP's other active TV permits.Removed and updated EGA Condition 3.5.2 to refer to only the assist gas,for clarity. II 59 3.3.2.2 D-2/COMB-1 There is no meter on the assist gas at the combustor,therefore DCP will assume the entire potential flowrate of 3,200 scf/hr is being directed to COMB-1 during operation of the combustor.What is this 3,200 scfh based on?Is that the absolute maximum assist gas rate that could flow through an orifice?My hesitation with not installing an assist gas meter is that flowrates over 3,200 scfh could be achieved if not limited by something physical,or otherwise metered.Additionally,this is a new assist gas line(if I'm remembering this right from the 2019 inspection),so it could be designed to be equipped with a meter or orifice to measure or restrict flow. DCP operations has confirmed that at present.assist gas isri t piped to the ECD The representation of assist was to allow us to add it in the future without seeking a perm morlihcation Would It be acceptable to add a statement that DCP will install a now mate'measuring assist gas throughput IF assist gas is hooked up at Inc facility.Thu,:Aims us to continue Operating without assist gas of a corresponding meter for now while ensuring that DCP can install the assist gas and corresponding meter in the future v Iti,ont an additixi.l permit modification • II 59 3.4.1 D-2 Unit D-2 is equipped with an electric glycol pump.Pump strokes per minute cannot be used as a method of monitoring for an electric pump.DCP suggests that this condition be modified to allow the use of the maximum permitted glycol circulation rate when a value cannot be obtained from the glycol flowmeter.Updated to the following:The lean glycol,flotcrate shall he recorded daily using the existing glycol flowineuer.The recorded.11mvrale.dna/1 he the stun of dye/lmvraleJront each pump and all other glycol ln/ection points(/f hops://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1683283273839694185&simpl=msg-f%3A1683283273839694185 1/18 11/30/2020 State.co.us Executive Branch Mail-Enterprise Questions From:Schuchardt-CDPHE, Elie [mailto:elie.schuchardt@state.co.us] Sent:Thursday, May 24, 2018 1:19 PM To: Hayes,Branden S<BSHayes@dcpmidstream.com> Subject: Enterprise Questions Hi Branden, I'm working through the Enterprise renewal right now, and I think you are the correct contact for this site-definitely let me know if I've got the wrong person! These are the questions I've got so far on Enterprise: • Pneumatic Controllers- Do you have any at Enterprise that are natural gas driven? Or are they all air-driven? • Pneumatic Pumps- Do you have any natural gas driven pneumatic pumps at Enterprise? • Gas routing-Where does the gas go when it leaves Enterprise? Does it end up at Roggen? • Section XII.J - How are you guys complying with the Section XII.J stuff?Are you guys doing the rod packing replacements, or do you have emissions routed to a closed vent? I can definitely put both in the permit if you'd like, or I can just put the requirements in for whichever compliance method you are using- might be easier for you guys and our inspectors. • Condensate Stabilization Unit- Is this unit equipped with a reboiler? Is that the 0.75 MMBtu/hr NG Fired Separator on the insignificant activities list? Or is it something different? If it's different, can I get the Btu rating on that thing so I can update the insignificant activities list in the permit? • Condensate Throughput- How is this measured? Do you guys have a meter, or are you using sales tickets? I think that's all I've got for now-let me know if you've got any questions on this! Thanks so much and enjoy the holiday weekend!! Elie Schuchardt Permit Engineer Title V Operating Permit Unit Stationary Sources Program Air Pollution Control Division P 303.692.6332 4300 Cherry Creek Drive South. Denver, CO 80246-1530 etie.schuchardt@state.co.us I www.colorado.gov/cdphe/apcd 1 [Quoted text hidden] https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1601829872187422138&simpl=msg-f%3A16018298721... 2/2 11/30/2020 State.co.us Executive Branch Mail-Enterprise Questions STATE OF Chavez-CDPHE, Elie<elie.chavez@state.co.us> COLORADO Enterprise Questions Hayes, Branden S <BSHayes@dcpmidstream.com> Tue, May 29, 2018 at 2:00 PM To: "Schuchardt-CDPHE, Elie" <elie.schuchardt@state.co.us> Cc: "Shankaran, Roshini" <RShankaran@dcpmidstream.com> Good afternoon Elie!I have some answers for you. I hope you have a good weekend. • Pneumatic Controllers - Do you have any at Enterprise that are natural gas driven?Or are they all air- driven? o All pneumatics at Enterprise are air-driven. • Pneumatic Pumps- Do you have any natural gas driven pneumatic pumps at Enterprise? o All pumps at Enterprise are electric driven. • Gas routing-Where does the gas go when it leaves Enterprise?Does it end up at Roggen? o Correct, discharge gas is sent to Roggen for processing. • Section XII.J -How are you guys complying with the Section XII.J stuff?Are you guys doing the rod packing replacements, or do you have emissions routed to a closed vent?I can definitely put both in the permit if you'd like, or I can just put the requirements in for whichever compliance method you are using- might be easier for you guys and our inspectors. o I know we are monitoring hours of operation of rod-packing as part of our general maintenance plan.I am not 100% on the closed vent, so please put both in the permit, I like the idea of flexibility. • Condensate Stabilization Unit - Is this unit equipped with a reboiler?Is that the 0.75 MMBtu/hr NG Fired Separator on the insignificant activities list?Or is it something different?If it's different, can I get the Btu rating on that thing so I can update the insignificant activities list in the permit? o Yes, the .75 MMBTU/hr heater is the Condensate Stabilization heater. Roshini is currently working on a permit mod and will be submitting an updated insignificant activities list with that.The new insig list should be a little more detailed on the equipment. • Condensate Throughput -How is this measured?Do you guys have a meter, or are you using sales tickets? o Condensate throughput is tracked via sales tickets. Branden Hayes Environmental Specialist DCP Midstream, LP 3026 4th Avenue Greeley, CO 80631 Email: BSHayes@dcpmidstream.com; Cell: 970-373-8905 ; Office: 970-378-6389 2041O Midstream; --- °. https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permmsgid=msg-f%3A1601829872187422138&simpl=msg-f%3A16018298721... 1/2 INFO TO SUPPORT Operator Correspondence 11/23/2020 State.co.us Executive Branch Mail-Completeness Letter for 19WE0492 CP Roll-In '°" STATE O F ,' COl ORADO Chavez-CDPHE, Elie<elie.chavez@state.co.us> Completeness Letter for 19WE0492 CP Roll - In 1 message Chavez-CDPHE, Elie <elie.chavez@state.co.us> Mon, Nov 23, 2020 at 3:57 PM To: "Shankaran, Roshini" <RShankaran@dcpmidstream.com> Cc: "Chris Platt(chrisplatt@windriverenvironmental.com)" <chrisplatt@windriverenvironmental.com> Hi Roshini, Please find attached the completeness letter for the significant modification application for the Enterprise Compressor Station requesting the incorporation of 19WE0492. Please let me know if you have any questions or need anything else! Thanks so much, Elie Chavez Permit Engineer Title V Operating Permit Unit Stationary Sources Program Air Pollution Control Division C -,..-•»- COLORADO Air Pollution Control Division Department of Public Health&Environment P 303.692.6332 4300 Cherry Creek Drive South, Denver, CO 80246-1530 elie.chavez@state.co.us I www.colorado.gov/cdphe/apcd Are you curious about ground-level ozone in Colorado?Visit our ozone webpage to learn more. - 123-0277 Sig Mod Completeness Letter 11-23-2020.pdf 67K https://mail.google.com/mail/u/0?ik=85031 f40e8&view=pt&search=all&permthid=thread-a%3Ar4766825500444408552&simpl=msg-a%3Ar435903809... 1/1 Please note that the Division utilizes a quarterly billing system for all operating permits. The bills you receive will reflect chargeable time for the previous quarter. The Colorado Legislature has directed the Division to inform sources if the time spent processing an application will exceed 30 hours. The Division has determined that the time required to process your application for renewal of the operating permit will exceed 30 hours. Based on our experience in processing operating permits, we estimate that the total time required to process your application will be between 25 and 100 hours. This letter fulfills the Division's obligation to inform you that the processing time for your operating permit renewal will exceed 30 hours and to provide you with an estimate of the processing time. Timeline Significant modifications are processed under the same time lines and procedures as new operating permits, including Public Comment and EPA review. Within sixty (60) days of receiving an application for a significant modification the Division must determine if the application is administratively complete. Under the provisions of Regulation No. 3, Part C, Section IV.C, the Division has 18 months from the receipt of a complete application in order to approve or disapprove the application. The 18 month clock starts on the date a complete application is submitted. Please note that you must operate under the conditions of construction permit 19WE0492 until the revised operating permit has been issued. Required Additional Information The Division has determined that the November 19, 2020 application is administratively complete. If during the technical review of your application, the Division determines that additional information is necessary to evaluate or take final action on this application, a request will be made in writing for the information and a reasonable deadline for response set. If you fail to provide the requested information or do not meet the deadline, the Division will be unable to continue with the processing and issuance of the modified permits (Regulation No. 3, Part C, Section IV.D). Please do not hesitate to contact me if you have any questions at 303-692-6332 or elie.chavez@state.co.us. Sincerely, rao Elie Chavez, P.E. Engineer, Operating Permit Unit Stationary Sources Program Air Pollution Control Division C. ....:•! COLORADO Ntwor Department of Public Health Et Environment November 23, 2020 Roshini Shankaran Senior Environmental Engineer DCP Operating Company, LP 370 17th Street, Suite 2500 Denver, CO 80202 REF: DCP Operating Company, LP - Enterprise Compressor Station, OP #95OPWE103, FID# 123-0277 SUBJECT: Administrative Completeness Determination for Significant Modification Dear Ms. Shankaran: The application for the revision to the operating permit for the Enterprise Compressor Station (received November 19, 2020) to incorporate the applicable requirements from the construction permit issued for the installation of TEG Dehydration Unit D-3 and increased throughput for the condensate storage tanks and condensate truck loading (19WE0492) has been determined to constitute a significant modification as defined in Regulation No. 3, Part C, Section I.A.7. As stated in that section, significant modifications will be processed using the procedures set forth in Part C of Regulation No. 3, for combined Construction/Operating Permit issuance. Regulation No. 3, Part C, Section 111.8.1 and 2 requires that facilities submit an application for a revised operating permit within twelve (12) months of construction permit issuance on standard application forms supplied by the Division. The Division issued Colorado Construction Permit 19WE0492 on November 19, 2019 and therefore the Division considers that your application was submitted on time. Fees Colorado Regulation No. 3, Part A Section VI.A.1 requires the division to charge fees to "...recover the direct and indirect costs incurred by the Division in processing permit applications, issuing permits, and in conducting a compliance monitoring and enforcement program. Such fees shall apply without regards to whether a permit is issued, denied, withdrawn, or revoked." With respect to processing applications and issuing permits, fees will be charged for time spent reviewing the application and drafting the permit and associated basis document, including researching regulatory and technical issues related to the application and permit draft as applicable. Chargeable time also includes peer and supervisor review of drafts, as well as time spent by permit engineers and division management in meetings, phone calls, and responding to emails. The hourly permit processing fee is $108.12 beginning on July 1, 2020. Please see https://www.colorado.gov/pacific/cdphe/emissions-and-permitting-fees for additional information about fees. ,Ka_.,-.'N-0\ \ , 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe I H� �G\; Jared Polls, Governor ( Jill Hunsaker Ryan,MPH, Executive Director ; 4 J.,) \t',A16 INFO TO SUPPORT 11/19/2020 Modification Colorado Department of Public Health and Environment Form APCD-102 C D P H E Air Pollution Control Division ,y Facility Wide Emissions Inventory Form Ver.April,2015 3 Company Name:DCP Operating Company,LP Source Name:Enterprise Compressor Station • Source AIRS ID:123/(1277 Uncontrolled Potential to Emit(POE) Controlled Pdeutial to Emit(PTE) Criteria(Toy) I HAP00h0Yr) Criteria(TPY) I HAN)Ibulye) AIRS ID Equipment Dmcripaan TSP P5110 PM25 502 NOx VOC CO 1 H(110 Metal Acru BZ Tut EH X51 n-Hex Meth 224-TMP TSP P5410 P512.5 502 NO9 00C CO 444110 Metal Aem RT. To, MI Xyl o-Ilex Meth 224-Th/P (153 Engine C-238 1.05 1.05 I 05 11.06 24.1%1 2111.X2 85.70 I 27,424 1757 1.11%1 925 86 9 30 -- 526 -- (05 105 1.05 0.06 24,00 24.0(1 27.42 I 5.405 1179 5411 462 43 5 19 -- 263 -- 055 Engine C-235 I05 1.05 1.05 11.06 24.01 210.X2 85.70 I 27,424 1,757 1,081 925 46 9 39 - 526 -- (.05 1.05 1.1(5 ((.06 2400 2400 27.42 5,405 579 5411 462 43 5 19 -- 263 -- 056 Engine C-236 105 1.05 1.05 0.(16 24.1%1 2111.X2 85.70 I 27,424 1,757 1,010 (25 86 9 39 -- 526 v -- 1.05 105 1.05 0,06 2400 24.011 27.42 5,405 1179 5411 462 43 5 19 -- 263 -- 063 P_013 Stabilized Condensate Tanks -- -- -- — 0.05 33.07 0.25 I -- -- — 811 3,1(43 203 2,231 6,491 -- -- -- -- -- -- 11.115 1.6% 0.25 -- -- — 41 152 10 112 325 -- 066 P-016 Stabilized Conde..Truck Loadom -- -- -- -- 0(0 I0.X3 014 I -- -- — 105 129 4 20 734 -- -- -- -- -- -- 003 OYJ 0.14 -- - -- 5 6 0 1 37 -- — 068 11-2.110 1919.19efd TED Dehy -- -- -- — 1.42 664.%7 6.42 1 -- -- -- 152,729 250,259 8,2(11 59.996 28.186 -- _ 21 -- -- -- -- 1.42 26.%2 6.42 -- -- -- 0.794 14,6119 482 1,591 911 -- 070 Engine C-234/P-015 1.05 1.05 1.115 11.06 24.110 2(0,12 45.70 I 27,424 1,757 1,1181 925 86 9 39 -- 526 -- 1315 1.05 1.05 0.06 241%1 24.00 2742 5,485 %79 5411 462 43 5 19 -- 263 -- 1171 Engine C-237 1.55 155 155 11119 31111 2%1,19 125.741 96,572 2,594 1.595 1165 127 14 37 -- 776 -- 1.55 1.55 1.55 11.119 32.01 32.01 36.58 7,316 1,297 797 683 63 7 29 - 3%0 -- 077 COMP-BD -- -- -- — -- 9.X0 -- -- -- -- 35 31 2 111 248 21 11 -- -- -- -- -- Y.%11 -- -- — -- 35 31 2 10 248 21 0 073 D-3 145 MINsefd TEO Deity .. .. .. _ (.49 644.91 6.72 -- -- — 133,283 199,612 6,227 45,786 26,739 159 17 -- -- -- -- 1.49 23.95 6.72 -- -- -- 7,773 11,751 369 2,725 946 5 1 075 Produced Water mirage -- -- -- — -- I k5 — 1 -- -- — 45 35 1 7 343 -- U -- -- -- -- -- 1 45 — -- — -- 45 35 1 7 343 -- 11 Permitted Sources Subtotal— 5.75 5.75 5.75 11.34 129.57 1,833.54 47164 I 146,274 9,624 5,517 139,343 21(3318 6,487 48,266 34,518 3,1(58 17 175 5.75 175 0.34 129.57 16621 111.31 29,215' 4,811 2,959 1%431 12,210 4m 2,961 9,099 1,466 1 APEN Only-Permit Exempt Sources I I I J APEN Only Subtotal— 11.11 110 0.0 0.0 (64 0.11 0.0 I II II (I II II II II 0 II II 0.0 911 0.0 0.11 1111 80 11.0 11 11 11 11 11 II 11 11 11 11 OPEN Exempt/Imlgol0cant sources N.1 Insignificant Activities I -- -- -- -- 1 - 1 Insignificant Subtotal= HU 0.11 0.0 110 1.0 5.1 0.8 I U 0 0 44 0 II II 3711 0 0 11.11 110 0.0 0.0 1.0 51 0.0 0 U 0 44 0 0 0 370 u II Tuts.,All Sources-I 57 I 5.7 I 5.7 I 0.3 I 1305 I 183%6 I 476.5: 146,274 1 9,624 I 1917 1139388 12113,310 16,417 141,266 1 34,919 I.3,1158 I 17 157 I 17 I 5.7 10.3 11311.5 1171.3 I 1542 i 29,255 I 4,812 I 2,959 I 10,475 112,210 1408 12,'561 I 2.268 I 1,466 I 1 Uncontrolled HIAPN Summary(TP1)4 73.1 I 4.8 I 3.0 I 69.7 I 101.7 I 3.2 I 241 I 17.5 I 1.5 I too I Controlled 11APN Summary(TPY)'1 14.6 I 2.4 I 1.5 I 5.2 I 61 I 0.2 I 1.5 I 1.1 I 1.7 I 0.0 Uneantro0ed 74400,All HAP,(TPY)4 299.6 I Controlled Total,A0 NAPN(TPY)1 33.4 I Footnotes: I.This form should he completed to include bath existing.sources and all proposed new or modifications to existing cmissions.sources 2.If the emissions source is new then enter"proposed"under the Permit Ni,.and AIRS ID data columns 3.HAP abbreviations include: BZ=Benzene 22-i-TMP=2,2,4-Trimethylpentane Tool=Toluene Aeetal=Acetaldehyde EB=Ethylbenzene Aeon=Acrulem Xyl=Xylene n-Hex=n-Hexane HCHO=Formaldehyde Meth=Methanol 4 APEN Exempt/Insignificant Sources should he included when warranted. • DCP Operating Company,LP 11/1712020 Page 1 of 1 Attachment F Form APCD-102 Enterprise Compressor Station COLORADO Form OP-400 Air Pollution Control Division t,OlotAf 0 The emission point will continue to comply with these requirements For applicable requirements that will become effective during this permit term: The emission point will comply with these requirements in a timely basis 6. Schedule of Compliance Complete this section if "Not in compliance" was answered in Section 5 and a schedule of compliance is required. Also, complete this section if the applicant is required to submit a schedule of compliance by an applicable requirement. Attach copies of any judicial consent decrees, compliance orders on consent, or administrative orders, etc. for this requirement. Applicable Requirement (Description and Citation) k r Reason for Noncompliance Click here e Lc enter __-._. Narrative Description How Compliance Will be Achieved Provide a schedule of corrective action(s), including an enforceable sequence of actions with milestones, leading to compliance, including a date for final compliance. Corrective Action Date to be Achieved ;'lick here _,. ehter text. :'lick here ':)en) enter t te. click here entier Click here ro enter t. fLitik here tc enter Cr ek here enter :ext. hert hi) enter Creek here tc enter text. i_ rek here enter zt.. -__Ck here tc enter text. C.-Lek nere to e _ el -. Cel ik here Le enter text. Ti r< e tc enter e i,__L here e r First Progress Report will be Submitted on: N/A Frequency of Submittals Thereafter: N/A Form Revised March 2020 Page 14 of 4 'COLORADO AIRS ID: 123-0277-077 flBpB""i0"`°` ` Frith&Ea»xontnertt COLORADO Form OP-400 Air Pollution Control Division vow €risz.,me.^.: ?ut c 1.c7lth Z;Er.ovpr>rrr_nz Final Approval Requirement - Submit NOS with make/model/serial number of dehy unit and glycol pumps within 15 days of startup. Submit self-ceritifcation within 180 days of startup including initial Method 22 opacity observation, and initial extended gas analysis of both inlet wet gas and fuel gas used as pilot / assist gas at the combustor. AOS - The glycol pumps may be replaced under AOS provisions CAM- This unit is subject to CAM requirements, which have already been detailed in draft renewal permit 95OPWE103 Statewide Control for Oil and Gas Operations - This source is subject to the emission control, recordkeeping, and reporting requirements detailed under Regulation 7, Part D, Sections I.H. and II.D. 40 CFR 63 Subpart HH MACT - D-3 is subject to the area source provisions under MACT Subpart HH, including a determination of L-Opt and associated recordkeeping and reporting. 40 CFR 63 Subpart A - D-3 is subject to the notification, recordkeeping, and reporting requirements under the MACT General Provisions. 4. Monitoring Requirements Complete the following monitoring questions about the emission unit. Continuous Emission Monitoring Requirements? ❑ Yes i' No Pollutant(s) or Parameter(s): . Requirement(s): -. ❑ Continuous Emission Monitoring System (CEMS) EI Predictive Emission Monitoring System (PEMS) ❑ Continuous Emission Rate Monitoring System (CERMS) El Other (describe): r Periodic Compliance Testing? ❑ Yes Z No Pollutant(s): 1 Frequency: c L. ; n _ t._ ct . Date of last Division-approved test: Other? E Yes El No Describe: Extended Gas Analysis Frequency: Annual 5. Compliance Status and Commitment Indicate the compliance status of the emission point as of the date of submittal: C In compliance with all applicable requirements ❑ Not in compliance (fill out Section 6 below if schedule of compliance is required) For applicable requirements this emission point is currently in compliance with: Form Revised March 2020 Page I 3 of 4 5 COLORADO AIRS ID: 123-0277-077 Departmentxe Health „o , COLORADO Form OP-400 l "iglibow Air Pollution Control Division tank"L<rener`.t Pat(Health�T fll Vlf(}[',•fMY1E Opacity These requirements apply specifically to the enclosed combustor used for emissions control. Not to exceed 30% for a period or periods aggregating more than six (6) minutes in any sixty (60) consecutive minutes, Basis: Construction Permit 19WE0492 Compliance will be presumed in the absence of credible evidence to the contrary. Operational Limitation(s) (hrs/yr, MMscf/yr, lb/yr, etc.) Wet Gas Throughput - 52,925 MMscf/yr, 4,495 MMscf/mo, Basis: Construction Permit 19WE0492 VRU Downtime - Not to exceed 5% of total actual dry gas processed COMB-1 Downtime - Not to exceed 1% of total actual dry gas processed Monthly recordkeeping and twelve month rolling total calculations. Monthly throughput determined from outlet meters. Downtime determined by tracking COMB-1 and VRU hours of operation. Combustor Pilot Gas Throughput - 0.44 MMscf/yr, 0.04 MMscf/mo, Basis: Construction Permit 19WE0492 Combustor Assist Gas Throughput - 28.03 MMscf/yr, 2.38 MMscf/mo, Basis: Construction Permit 19WE0492 Monthly recordkeeping and twelve month rolling total calculations. Monthly pilot throughput based on constant rate of 150 scf/hr. Assist throughput determined from meter. Lean Glycol Circulation Rate - 25 gpm, Basis: Construction Permit 19WE0492 Daily recordkeeping. Throughput determined from meter. Other Requirements List all other applicable requirements for this emission point. Annual Extended Gas Analysis (Inlet Gas) - Used for monthly GLYCaIc compliance modeling Annual Extended Gas Analysis (Fuel Gas) - Used for monthly ECD combustion emission calculations Parametric Monitoring - Weekly monitoring of inlet wet gas temp / pressure, flash tank temp / pressure. Used for monthly GLYCaIc compliance modeling Hours of Operation - Track COMB-1 hours of operation, VRU downtime, COMB-1 downtime, and overall. Downtime values shall be used to calculate dry gas throughput during standard operation, VRU downtime, and COMB-1 downtime. Control Device Requirements - VRU: daily inspection, recordkeeping, reporting COMB-1: daily inspection, constant pilot light, knockout vessel liquid level monitoring, daily visual emissions observations with Method 22 / 9 followups as required. Form Revised March 2020 Page I 2 of 4 COLORADO AIRS ID: 123-0277-077 • Department of Public Health b Environment COLORADO Form OP-400 Air Pollution Control Division C. ;t-vrx v+ N =kept#,h Lr:wr,rfirrs Compliance and Monitoring Title V Operating 95OPWE103 AIRS ID Number: 123 - 0277 - 077 Permit Number: 1. Instructions Complete this form and attach it to the completed corresponding OP-300 series form for the applicable emission unit. Each OP-300 series form must be accompanied by a Compliance and Monitoring form (OP-400). Refer to the instruction sheet or contact the Division with questions. Any form with missing information may be determined administratively incomplete and may result in inability to grant the application shield of Regulation No. 3, Part C, Section II.B. Renewal and modification applications for equipment already included in the Title V permit are allowed to only complete portions of the form affected by the modification. Note that if using copy and paste; the applicant must paste as plain text. See "General Instructions" document for more details. 2. Emission Unit Information Facility Identifier D-3 (example: 5001) 3. Applicable Requirements Identify each applicable requirement for the emission unit, any associated compliance monitoring, recordkeeping, and reporting requirements, and the basis for the requirement. If more space is needed, attach additional descriptions. Emission Limitations (tpy, lb/hr, lb/MMBtu, gr/dscf, etc.) VOC Scenario 1 (Standard Operation) - 22.1 tpy, Basis: Construction Permit 19WE0492 Scenario 2 (Enclosed Combustor Pilot Gas Combustion) - 0.001 tpy, Basis: Construction Permit 19WE0492 Scenario 3 (Enclosed Combustor Assist Gas Combustion) - 1.9 tpy, Basis: Construction Permit 19WE0492 Monthly GLYCaIc modeling runs to determine emissions. Monthly recordkeeping and twelve month rolling total calculations using emissions provided by GLYCaIc. NOx Scenario 1 (Standard Operation) - 0.5 tpy, Basis: Construction Permit 19WE0492 Scenario 2 (Enclosed Combustor Pilot Gas Combustion) - 0.02 tpy, Basis: Construction Permit 19WE0492 Scenario 3 (Enclosed Combustor Assist Gas Combustion) - 1.0 tpy, Basis: Construction Permit 19WE0492 Monthly recordkeeping and twelve month rolling total calculations CO Scenario 1 (Standard Operation) - 2.3 tpy, Basis: Construction Permit 19WE0492 Scenario 2 (Enclosed Combustor Pilot Gas Combustion) - 0.02 tpy, Basis: Construction Permit 19WE0492 Scenario 3 (Enclosed Combustor Assist Gas Combustion) - 4.4 tpy, Basis: Construction Permit 19WE0492 Monthly recordkeeping and twelve month rolling total calculations Form Revised March 2020 Page 1 1 of 4 ,-. ?COLORADO AIRS ID: 123-0277-077 °ep"""er:°"61 Health b Envftonment COLORADO Form OP-400 Air Pollution Control Division Crhser xere tc erter tenet. here te enter text. chtiek nere th enter text. Cn2hhe, here to enter eet<e. th er texe . tc< here 7C exterytt. _....ie, re.. E- o ,._._ter tent. Ci_ here er enter text . First Progress Report will be Submitted on: N/A Frequency of Submittals Thereafter: N/A Form Revised March 2020 Page I 4 of 4 COLORADO AIRS ID: 123-0277-066 '°iSa1P°1t` FleattMbenriroRmsnt _1171 ICOLORADO Form OP-400 Air Pollution Control Division Pollutant(s) or Parameter(s): _ . . Requirement(s): -__ ❑ Continuous Emission Monitoring System (CEMS) ❑ Predictive Emission Monitoring System (PEMS) • Continuous Emission Rate Monitoring System (CERMS) ❑ Other (describe): c Periodic Compliance Testing? Ei Yes No Pollutant(s): Frequency: k . _ e t , Date of last Division-approved test: Other? Z Yes ❑ No Describe: Extended Liquids Analysis Frequency: Every 5-years 5. Compliance Status and Commitment Indicate the compliance status of the emission point as of the date of submittal: Z In compliance with all applicable requirements ❑ Not in compliance (fill out Section 6 below if schedule of compliance is required) For applicable requirements this emission point is currently in compliance with: Z The emission point will continue to comply with these requirements For applicable requirements that will become effective during this permit term: The emission point will comply with these requirements in a timely basis 6. Schedule of Compliance Complete this section if "Not in compliance" was answered in Section 5 and a schedule of compliance is required. Also, complete this section if the applicant is required to submit a schedule of compliance by an applicable requirement. Attach copies of any judicial consent decrees, compliance orders on consent, or administrative orders, etc. for this requirement. Applicable Requirement _ (Description and Citation) Reason for Noncompliance Narrative Description How Compliance Will be enz-ct �za. Achieved Provide a schedule of corrective action(s), including an enforceable sequence of actions with milestones, leading to compliance, including a date for final compliance. Corrective Action Date to be Achieved Form Revised March 2020 Page I 3 of 4 COLORADO nof AIRS ID: 123-0277-066 Depa�?me Pul ern • � ' COLORADO Form OP-400 Air Pollution Control Division DnINI=Pfier4 Plarbc µcart,&fn,nrOrmr_r=, Operational Limitation(s)(hrs/yr, MMscf/yr, lb/yr, etc.) Condensate Throughput - 202,848 bbl/yr, Basis: Construction Permit 19WE0492 Monthly recordkeeping and twelve month rolling total calculations. Monthly throughput determined from sales or haul tickets. Other Requirements List all other applicable requirements for this emission point. Extended Liquids Analysis - Every 5 Years - Used for verification of VOC lb/bbl emission factor using AP-42 Chapter 7 calculation methodologies. Operational Requirements - Liquid loading operations shall be designed, operated, and maintained so as to minimize leakage of VOCs to the atmosphere. The following procedures shall be utilized: 1 All compartment hatches at the facility (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. 2 Thief hatch seals shall be inspected annually for integrity and replaced as necessary. Thief hatch covers shall be weighted and properly seated. 3 Pressure relief devices (PRD) shall be inspected annually for proper operation and replaced as necessary. PRDs shall be set to release at a pressure that will ensure flashing, working and breathing losses are not vented through the PRD under normal operating conditions. 4 The equipment design requirements, loading procedures and monthly onsite loading equipment inspections set forth in Condition 5.8.1.2c for controlled loading operations shall be utilized to minimize the leakage of VOC to atmosphere. This requirement shall apply at all times, regardless of actual loadout throughput. Control Device Requirements - pilot light shall be present at all times and monitored through either a thermocouple or backup daily visual inspection. Daily visible emission observations required, with follow up Method 22's or Method 9's as required. RACT - Reasonably Available Control Technology as been determined to be loading the tank trucks using submerged fill at all times Statewide Controls for Oil and Gas Operations - This source is subject to the emission control, recordkeeping, and reporting requirements detailed under Regulation 7, Part D, Section II.C.5. 4. Monitoring Requirements Complete the following monitoring questions about the emission unit. Continuous Emission Monitoring Requirements? ❑ Yes F., No Form Revised March 2020 Page I 2 of 4 h; COLORADO AIRS ID: 123-0277-066 Deyutment of Public Health&Envhonment ti COLORADO Form OP-400 Air Pollution Control Division Compliance and Monitoring Title V Operating 95OPWE103 AIRS ID Number: 123 - 0277 - 066 Permit Number: 1. Instructions Complete this form and attach it to the completed corresponding OP-300 series form for the applicable emission unit. Each OP-300 series form must be accompanied by a Compliance and Monitoring form (OP-400). Refer to the instruction sheet or contact the Division with questions. Any form with missing information may be determined administratively incomplete and may result in inability to grant the application shield of Regulation No. 3, Part C, Section II.B. Renewal and modification applications for equipment already included in the Title V permit are allowed to only complete portions of the form affected by the modification. Note that if using copy and paste; the applicant must paste as plain text. See "General Instructions" document for more details. 2. Emission Unit Information Facility Identifier P016 (example: S001) 3. Applicable Requirements Identify each applicable requirement for the emission unit, any associated compliance monitoring, recordkeeping, and reporting requirements, and the basis for the requirement. If more space is needed, attach additional descriptions. Emission Limitations (tpy, lb/hr, lb/MMBtu, gr/dscf, etc.) VOC - 0.94 tpy, Basis: Construction Permit 19WE0492 Monthly recordkeeping and twelve month rolling total calculations Opacity These requirements apply specifically to the enclosed combustor used for emissions control. Not to exceed 30% for a period or periods aggregating more than six (6) minutes in any sixty (60) consecutive minutes, Basis: Construction Permit 19WE0492 Compliance will be presumed in the absence of credible evidence to the contrary. Form Revised March 2020 Page 11 of 4 COLORADO AIRS ID: 123-0277-066 "°°'"ne to""bt !Hcalthb6nvi[onmen[ �» COLORADO Form OP-400 Air Pollution Contort Division o,70,1arlm,of wt Mth Enotoert 5. Compliance Status and Commitment Indicate the compliance status of the emission point as of the date of submittal: © In compliance with all applicable requirements ❑ Not in compliance (fill out Section 6 below if schedule of compliance is required) For applicable requirements this emission point is currently in compliance with: Z The emission point will continue to comply with these requirements For applicable requirements that will become effective during this permit term: O The emission point will comply with these requirements in a timely basis 6. Schedule of Compliance Complete this section if "Not in compliance" was answered in Section 5 and a schedule of compliance is required. Also, complete this section if the applicant is required to submit a schedule of compliance by an applicable requirement. Attach copies of any judicial consent decrees, compliance orders on consent, or administrative orders, etc. for this requirement. Applicable Requirement e t > t xt . (Description and Citation) Reason for Noncompliance _, to t. r Narrative Description How Compliance Will be neljeoX thtine to -.nt. _-. Achieved Provide a schedule of corrective action(s), including an enforceable sequence of actions with milestones, leading to compliance, including a date for final compliance. Corrective Action Date to be Achieved C±tott onre to enttx text. . 1_i here Clitk Ilene __ enter text . nere enter' text. hthet'_ It _ t: entet text . ;tick here to _.rto _O enter text . _l1 , _ he Le to enLenI teext . 'n ere ehter text . Click here to eolter text.. Click here nett ten-ft. Cli _ _ _-__ _ to _ _ext. Click here to enter text. .'hLittn here totet exter ten=t. First Progress Report wilt be Submitted on: N/A Frequency of Submittals Thereafter: N/A Form Revised March 2020 e o L o R s D�D Page I 3 of 3 i ,,, AIRS ID: 123-0277-063 Put ., Tiailtb b Rnvimnmemt Hello