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Home My WebLink About20182376.tiffCOLORADO Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150 O St PO Box 758 Greeley, CO 80632 July 18, 2018 Dear Sir or Madam: RECEIVED JUL 2 3 2018 WEONTY COMMISSIO E S On July 19, 2018, the Air Pollution Control Division will begin a 30 -day public notice period for Taproot Rockies Midstream - Radicle Gas Plant Phase 1. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure RevteW CC• p' pW ( 10-0-I* OK) p7 —3p—I4 o -7-a,3 —l8 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer 2018-2376 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Taproot Rockies Midstream - Radicle Gas Plant Phase 1 - Weld County Notice Period Begins: July 19, 2018 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Taproot Rockies Midstream Facility: Radicle Gas Plant Phase 1 Natural gas processing plant Section 11, T8N R61W Weld County The proposed project or activity is as follows: New natural gas processing plant in the ozone non - attainment area of Weld County. The applicant intends to construct and operate the facility in two "phases". This application is for "Phase 1" which is temporary and includes some rental equipment and some permanent equipment. "Phase 2" application has been submitted and describes the full permanent buildout of the facility. Phase 1 and Phase 2 shall not operate concurrently. Phase 1 equipment includes five (5) compressor engines, amine sweetening unit, TEG dehydration, two (2) heaters, condensate storage tanks, loadout of liquids to trucks, compressor blowdowns, rod packing emissions, plant flare, and fugitive. APEN-exempt equipment associated with Phase 1 are the reboiler for the TEG dehydration, slop storage tank, produced water storage tank, and plant blowdowns. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 18WE0444 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Andy Gruel Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Andy Gruel Package #: 378690'. Received Date: 4/25/2018 Review Start Date: 4/30/2018 Section 01- Facility Information Company Name: County AIRS ID: Plant AIRS ID: Facility Name: Physical Location: County: Type of Facility: ',Natural Gas Processing Plant What industry segment? Oil & Natural Gas Production & Processing Is this facility located in a NAAQS non -attainment area? , ' Yes If yes, for what pollutant? ❑ carbon Monoxide (CO) Section 02 - Emissions Units In Permit Application Taproot Rockies Midstream 123 9F87 Radicle Gas Plant Section 11, Township SN, Range 61W Weld County ❑ Particulate Matter (PM) ❑ Quadrant Section Township Range 1 8N 61 Ozone (NOx & VOC) AIRS Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks 001 Natural Gas RICE Inlet Compressor 1 Yes 18WE0444 CP1 Yes Permit Initial Issuance 002 Natural Gas RICE Inlet Compressor 2 Yes 003 Natural Gas RICE Inlet Compressor 3 Yes 004 Natural Gas RICE Residue Compressor 4 Yes 005 Natural Gas RICE Residue Compressor 5 No 006 Amine Sweetening Unit Rental Amine Yes 007 Dehydrator RentalTEG Yes 008 NG Heater Rental Amine Heater No 009 NG Heater Hot Oil Heater A No -410 Process Flare 20 MMscfd Flare Yes 411 Condensate Tank Gunbarrel Yes 012 Condensate Tank Condensate Yes -.013 € quid Loading NGE Loadout - Na 014 -Liquid Loading Condensate Loadout015 Fugitive Component Leaks Fugitive Emissions Yes 016 Other (Explain) Phase 1 Ca Na Compressor Blowdowns 017 Other (Explain); Phase 1 RP: No Compressor Rod Packing Section 03 - Description of Project New natural gas processing plant in the ozone non -attainment area of Weld County. The applicant intends to construct and operate the facility in two '"phases". This application is for' Phase 1" which is temporary and includes some rental equipment and some permanent equipment. Phase 2 application is expected to be received in summer 2018 and will describe the full permanent buildout of the facility. Phase 1 and Phase 2 shall not operate concurrently. APEN-exempt equipment associated wit Phase 1 project are reboiler for TEG dehy, slop storage tank, produced water tank, and MSS blowdowns. Section 04 - Public Comment Requirements Is Public Comment Required? If yes, why? RequestingSynthetie Minor Permit Section 05 - Ambient Air Impact Analysis Requirement: Was a quantitative modeling analysis required? No If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Yes Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) No SO2 NOx CO VOC PM2.5 PM10 TSP HAPs Is this stationary source a major source? If yes, explain what programs and which pollutants here SO2 Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) .1 No NOx CO VOC PM2.5 PM10 TSP ❑ ❑J HAPs ❑ ❑ Summary of Preliminary Analysis - NG RICE Company Name Facility Name Facility Location Facility Equipment ID Taproot Rockies Midstream Radicle Gas Plant Section 26 T8N R60W Inlet Compressor 1 Permit No. AIRS Review Date Permit Engineer 18W E0444 123/9FB7/001 05/09/2018 Andy Gruel Requested Action Issuance No. New permit/newly reported emission 1 Emission Point Description One (1) Caterpillar, Model G3516J, Serial Number To Be Determined, natural gas -fired, naturally aspirated, 4SLB reciprocating internal combustion engine, site rated at 1350 horsepower. This engine shall be equipped with an oxidation catalyst and air -fuel ratio control. This emission unit is used for inlet compression. Natural Gas Consumation Requested (mmscf/yr) 89.34 Requested (mmscf/m) 7.59 Fuel Heat Value (btu/scf) 1089 BSCF (Btu/hp-hr) 8227 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Uncontrolled Controlled NOx EMIT spec sheet. No control for NOx. VOC Applicant requested. EMIT spec sheet has uncontrolled VOC at 0.65 g/hp-hr, so I accepted the more conservative 1.07 g/hp- hr. EMIT spec sheet specifies 0.46 g/hp-hr; I accepted the applicants requested rate of 0.49 g/hp-hr. CO EMIT spec sheet. EMIT spec sheet specifies a 97.2% reduction in CO, but I accept the applicant's requested reduction of 63.2%. Formaldehyde EMIT spec sheet. EMIT spec sheet. SOX AP -42; Table 3.2-2 (7/2000); Natural Gas No Control TSP AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM10 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM2.5 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control Other Pollutants AP -42; Table 3.2-2 (7/2000); Natural Gas No Control Point Summary of Criteria Emissions ttpvl Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 6.52 6.518 6.52 0.0% VOC 13.95 6.388 13.95 54.2% CO 37.15 13.688 37.15 63.2% SOx 0.03 0.029 0.0 0.0% TSP 0.49 0.486 0.5 0.0% PM10 0.49 0.486 0.5 0.0% PM2.5 0.49 0.486 0.5 0.0% Total HAPs* 0.0 0.0 6.4 79.2% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (lb/ HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 10950 782 10950 92.9% Acetaldehyde 813 813 813 0.0% Acrolein 500 500 500 0.0% Methanol * 243 0.0% n -Hexane * 108 0.0% Benzene * * 43 0.0% Toluene * 4Q 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines/ Public Comment Public Comment Required MACT 7777 New/Recon 4SLB over 500 HP located at a(n) Area Source Reg 7 XVII.E Standards (g/hp-hr) NOx: 1.0 CO: 2.0 VOC: 0.7 Reg 7 XVI.B (Ozone NM requirements) applies? Yes MACT 7777 (area Is this engine subject to MACT 7777 area Yes source) source requirements? NSPS JJJJ Is this engine subject to NSPS JJJJ? Yes Note: JJJJ requirements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes No engine manufacture date is available, so I assumed 7/1/2018. Summary of Preliminary Analysis - NG RICE Company Name Facility Name Facility Location Facility Equipment ID Taproot Rockies Midstream Radicle Gas Plant Section 26 T8N R60W Inlet Compressor 2 Permit No. AIRS Review Date Permit Engineer 18W E0444 123/9FB7/002 05/09/2018 Andy Gruel Requested Action. , New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) Caterpillar, Model G3516J, Serial Number To Be Determined, natural gas -fired, naturally aspirated, 4SLB reciprocating internal combustion engine, site rated at 1350 horsepower. This engine shall be equipped with an oxidation catalyst and air -fuel ratio control. This emission unit is used for inlet compression. Natural Gas Consumption Hours of Operation Requested (mmscf/yr) 89.34 Requested (mmscf/m) 7.59 Fuel Heat Value (btu/scf) 1089 BSCF (Btu/hp-hr) 8227 Emission Factor Sources PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Uncontrolled Controlled- NOx EMIT spec sheet. No control for NOx. VOC Applicant requested. EMIT spec sheet has uncontrolled VOC at 0.65 g/hp-hr, so I accepted the more conservative 1.07 g/hp- hr. EMIT spec sheet specifies 0.46 g/hp-hr; I accepted the applicant's requested rate of 0.49 g/hp-hr. CO EMIT spec sheet. EMIT spec sheet specifies a 97.2% reduction in CO, but I accept the applicant's requested reduction of 63.2%. Formaldehyde EMIT spec sheet. EMIT spec sheet. SOX AP -42; Table 3.2-2 (7/2000); Natural Gas No Control TSP AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM 10 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM2.5 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control Other Pollutants AP -42; Table 3.2-2 (7/2000); Natural Gas No Control Point Summary of Criteria Emissions (t Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 6.52 6.518 6.52 0.0% VOC 13.95 6.388 13.95 54.2% CO 37.15 13.688 37.15 63.2% SOx 0.03 0.029 0.0 0.0% TSP 0.49 0.486 0.5 0.0% PM 10 0.49 0.486 0.5 0.0% PM2.5 0.49 0.486 0.5 0.0% Total HAPs* 0.0 0.0 6.4 79.2% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (lb/yr HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 10950 782 10950 92.9% Acetaldehyde 813 813 813 0.0% Acrolein 500 500 500 0.0% Methanol * 243 0.0% n -Hexane * 108 0.0% Benzene * * 43 0.0% Toluene * * 40 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minim us Permitting Reouirements Ambient Air Impacts Source is not required to model based on Division Guidelines/ Public Comment Public Comment Required MACT 7777 New/Recon 4SLB over 500 HP located at a(n) Area Source Reg 7 XVILE Standards (g/hp-hr) NOx: 1.0 CO: 2.0 VOC: 0.7 Reg 7 XVI.B (Ozone NAA requirements) applies? Yes MACT ZZZZ (area source) Is this engine subject to MACT ZZZZ area source requirements? Yes NSPS JJJJ Is this engine subject to NSPS JJJJ? Yes Note: JJJJ requirements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes No engine manufacture date is available, so I assumed 7/1/2018. Summary of Preliminary Analysis - NG RICE Company Name Facility Name Facility Location Facility Equipment ID Taproot Rockies Midstream Radicle Gas Plant Section 26 T8N R60W Inlet Compressor 3 Permit No. AIRS Review Date Permit Engineer 18W E0444 123/9FB7/003 05/09/2018 Andy Gruel Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) Caterpillar, Model G3516J, Serial Number To Be Determined, natural gas -fired, naturally aspirated, 4SLB reciprocating internal combustion engine, site rated at 1350 horsepower. This engine shall be equipped with an oxidation catalyst and air -fuel ratio control. This emission unit is used for inlet compression. Natural Gas Consumption Hours of Operation Requested (mmscf/yr) 89.34 Requested (mmscf/m) 7.59 Fuel Heat Value (btu/scf) 1089 BSCF (Btu/hp-hr) 8227 Emission Factor Sources PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Uncontrolled Controlled NOx EMIT spec sheet. ' No control for NOx. VOC Applicant requested. EMIT spec sheet has uncontrolled VOC at 0.65 g/hp-hr, so I accepted the more conservative 1.07 g/hp- hr. EMIT spec sheet specifies 0.46 g/hp-hr; I accepted the applicant's requested rate of 0.49 g/hp-hr. CO EMIT spec sheet. EMIT spec sheet specifies a 97.2% reduction in CO, but I accept the applicant's requested reduction of 63.2%. Formaldehyde EMIT spec sheet. EMIT spec sheet. SOX AP -42; Table 3.2-2 (7/2000); Natural Gas No Control TSP AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM10 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM2.5 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control Other Pollutants AP -42; Table 3.2-2 (7/2000); Natural Gas No Control Point Summary of Criteria Emissions (t Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 6.52 6.518 6.52 0.0% VOC 13.95 6.388 13.95 54.2% CO 37.15 13.688 37.15 63.2% SOx 0.03 0.029 0.0 0.0% TSP 0.49 0.486 0.5 0.0% PM 10 0.49 0.486 0.5 0.0% PM2.5 0.49 0.486 0.5 0.0% Total HAPs* 0.0 0.0 6.4 79.2% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants tlb/yr HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 10950 782 10950 92.9% Acetaldehyde 813 813 813 0.0% Acrolein 500 500 500 0.0% Methanol * * 243 0.0% n -Hexane * * 108 0.0% Benzene * 43 0.0% Toluene * * 40 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines/ Public Comment Public Comment Required MACT 7777 New/Recon 4SLB over 500 HP located at a(n) Area Source Reg 7 XVII.E Standards (g/hp-hr) NOx: 1.0 CO: 2.0 VOC: 0.7 Reg 7 XVI.B (Ozone NAA requirements) applies? Yes MACT ZZZZ (area source) Is this engine subject to MACT 7777 area Yes source requirements? NSPS JJJJ Is this engine subject to NSPS JJJJ? Yes Note: JJJJ requirements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes No engine manufacture date is available, so I assumed 7/1/2018. Summary of Preliminary Analysis - NG RICE Company Name Facility Name Facility Location Facility Equipment ID Taproot Rockies Midstream Radicle Gas Plant Section 26 T8N R60W Residue Compressor 4 Permit No. AIRS Review Date Permit Engineer 18WE0444 123/9FB7/004 05/09/2018 Andy Gruel Requested Action Issuance No. New permit/newly reported emission 1 Emission Point Description • One (1) Caterpillar, Model G3516J, Serial Number To Be Determined, natural gas -fired, naturally aspirated, 4SLB reciprocating internal combustion engine, site rated at 1350 horsepower. This engine shall be equipped with an oxidation catalyst and air -fuel ratio control. This emission unit is used for residue compression. Natural Gas Consumption Requested (mmscf/yr) 89.34 Requested (mmscf/m) 7.59 Fuel Heat Value (btu/scf) 1089 BSCF (Btu/hp-hr) 8227 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Uncontrolled Controlled NOx EMIT spec sheet. No control for NOx. VOC Applicant requested. EMIT spec sheet has uncontrolled VOC at 0.65 g/hp-hr, so I accepted the more conservative 1.07 g/hp- hr. EMIT spec sheet specifies 0.46 g/hp-hr; I accepted the applicant's requested rate of 0.49 g/hp-hr. CO EMIT spec sheet. EMIT spec sheet specifies a 97.2% reduction in CO, but I accept the applicant's requested reduction of 63.2%. Formaldehyde EMIT spec sheet. EMIT spec sheet. SOX AP -42; Table 3.2-2 (7/2000); Natural Gas No Control TSP AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM10 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control PM2.5 AP -42; Table 3.2-2 (7/2000); Natural Gas No Control Other Pollutants AP -42; Table 3.2-2 (7/2000); Natural Gas No Control Point Summary of Criteria Emissions (t Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 6.52 6.518 6.52 0.0% VOC 13.95 6.388 13.95 54.2% CO 37.15 13.688 37.15 63.2% SOx 0.03 0.029 0.0 0.0% TSP 0.49 0.486 0.5 0.0% PM 10 0.49 0.486 0.5 0.0% PM2.5 0.49 0.486 0.5 0.0% Total HAPs* 0.0 0.0 6.4 79.2% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (lb/yr HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 10950 782 10950 92.9% Acetaldehyde 813 813 813 0.0% Acrolein 500 500 500 0.0% Methanol * 243 0.0% n -Hexane * * 108 0.0% Benzene * * 43 0.0% Toluene * * 40 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines/ Public Comment Public Comment Required MACT ZZZZ New/Recon 4SLB over 500 HP located at a(n) Area Source Reg 7 XVII.E Standards (g/hp-hr) NOx: 1.0 CO: 2.0 VOC: 0.7 Reg 7 XVI.B (Ozone NAA requirements) applies? Yes MACT 777Z (area source) Is this engine subject to MACT ZZZZ area source requirements? Yes NSPS JJJJ Is this engine subject to NSPS JJJJ? Yes Note: JJJJ requirements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes No engine manufacture date is available, so I assumed 7/1/2018. Summary of Preliminary Analysis - NG RICE Company Name Facility Name Facility Location Section 26 T8N R60W Facility Equipment ID Residue Compressor 5 Taproot Rockies Midstream Radicle Gas Plant Permit No. AIRS Review Date Permit Engineer 18WE0444 123/9FB7/005 07/02/2018 Andy Gruel Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) Caterpillar, Model CG127-12, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 600 horsepower. This engine shall be equipped with a three-way catalyst system and air -fuel ratio control. This emission unit is used for csidue compression. Natural Gas Consumption Requested (mmscf/yr) 35.72 Requested (mmscf/m) 3.033 Fuel Heat Value (btu/scf) 1089 BSCF (Btu/hp-hr) 7400 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Uncontrolled Controlled NOx AP -42; Table 3.2-3 (7/2000); Natural Gas Manufacturer's spec sheet VOC AP -42; Table 3.2-3 (7/2000); Natural Gas No control. CO AP -42; Table 3.2-3 (7/2000); Natural Gas Manufacturer's spec sheet Formaldehyde AP -42; Table 3.2-3 (7/2000); Natural Gas No control. SOX AP -42; Table 3.2-3 (7/2000); Natural Gas No Control TSP AP -42; Table 3.2-3 (7/2000); Natural Gas No Control PM10 AP -42; Table 3.2-3 (7/2000); Natural Gas No Control PM2.5 AP -42; Table 3.2-3 (7/2000); Natural Gas No Control Other Pollutants AP -42; Table 3.2-3 (7/2000); Natural Gas No Control Point Summary of Criteria Emissions (tpy) Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 42.98 2.897 43.0 93.3% VOC 1.33 1.333 1.3 0.0% CO 72.34 11.587 72.3 84.0% SOx 0.01 0.011 0.0 0.0% TSP 0.38 0.38 0.4 0.0% PM10 0.38 0.38 0.4 0.0% PM2.5 0.38 0.38 0.4 0.0% Total HAPs* 0.00 0.00 0.6 0.0% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point summary of Hazardous Air Pollutants (lb/yr) 123-9FB7-005 18WE0444 Cp1 HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 797 797 797 0.0% Methanol * * 119 0.0% Acetaldehyde * * 109 0.0% Acrolein * * 102 0.0% Benzene * * 61 0.0% 1,3 -Butadiene * * 26 0.0% Toluene * * 22 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT 777Z New/Recon 4SRB over 500 HP located at a(n) Area Source Reg 7 XVII.E Standards (g/hp-hr) NOx: 1.0 CO: 2.0 VOC: 0.7 Reg 7 XVI.B (Ozone NAA requirements) applies? Yes MACT 7777 (area source) Is this engine subject to MACT 7777 area Yes source requirements? NSPS JJJJ Is this engine subject to NSPS JJJJ? Yes Note: JJJJ requirements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes Engine manufacture date is not available, so I assumed 7/1/18. Construction Permit Application Preliminary Analysis Summary Section 1 — Applicant Information Company Name: Taproot Rockies Midstream Permit Number: 18WE0444 Source Location: Radicle Gas Plant Equipment Description: Amine Sweetening Unit AIRS ID: 123/9FB7/006 Date: Original rec'd 4/25/2018; revision rec'd 6/8/18 Review Engineer: Andy Gruel Control Engineer: Section 2 — Action Completed Grandfathered Modification APEN Required/Permit Exempt x CP1 Transfer of Ownership APEN Exempt/Permit Exempt Section 3 —Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no" to any of the above, when did you mail an Information Request letter to the source? On what date was this application complete? 6/8/18 Section 4 - Source Description AIRS Point Equipment Description 006 Methyldiethanolamine (MDEA) natural gas sweetening system for acid gas removal with a design capacity of 20 MMSCF per day (make, model, serial number: TBD). This emissions unit is equipped with one (1) electric amine recirculation pump (make/model TBD) with a total design capacity of 60 gallons per minute. This system includes a natural gas/amine contactor, a flash tank, and a natural gas fired amine regeneration reboiler. All emissions are routed to point 010 (thermal oxidizer). Is this a portable source? Yes X No Is this location in a non -attainment area for any criteria pollutant? X Yes No If "yes", for what pollutant? PMio CO X Ozone Is this location in an attainment maintenance area for any criteria pollutant? Yes X No If "yes", for what pollutant? (Note: These pollutants are subject to minor source RACT per Regulation 3, Part B, Section III.D.2) PMio CO Ozone Page 1 Is this source located in the 8 -hour ozone non - attainment region? (Note: If "yes" the provisions of X Yes No Regulation 7, Sections XII and XVII.C may apply) Section 5 — Emission Estimate Information AIRS Point Emission Factor Source 006 Site-specfic using Promax Simulation Model (refer to Section 14 for calculations) Did the applicant provide actual process data for the emission inventory? Yes X No Basis for Potential to Emit (PTE) AIRS Point Process Consumption/Throughput/Production 006 7300 MMscf per year, natural gas throughput, 60 gallons per minute lean amine circulation rate Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year N/A — not constructed yet Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 006 7300 MMscf peryear natural gas throughput, 60 gallons per minute lean amine circulation rate Does this source use a control device? X Yes No AIRS Point Process Control Device Description % Reduction Granted 006 Thermal oxidizer and condenser 95 Section 6 — Emission Summary (tons per year) Point NO. VOC CO Single HAP Total HAP PTE: 006 --- 58.51 --- 1.058 (n -hexane) 1.529 Uncontrolled point source emission rate: 006 --- 58.51 --- 1.058 (n -hexane) 1.529 Controlled point source emission rate: 006 --- 2.93 --- 0.053 (n -hexane) 0.076 Section 7 — Non -Criteria / Hazardous Air Pollutants Pollutant CAS # Uncontrolled Emission Rate (Ib/yr) Are the emissions reportable? Controlled Emission Ibl r Rate ( Y ) Benzene 71432 496.9 Yes 24.8 Toluene 110543 360.4 Yes 18.0 Ethylbenzene 100414 21.7 No 1.1 Xylenes 1330207 63.7 No 3.2 n -Hexane 110543 2115.4 Yes 105.8 224-Trimethylpentane 540841 0.3 No 0.02 Note: Regulation 3, Part A, Section II.B.3.b APEN emission reporting requirements for non -criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Page 2 Section 8 —Testing Requirements Will testing be required toshow compliance with any emission rate or regulatory standard? X Yes No If "yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method 006 01 RAPS Regulation No. 3, Part B., Section III.G.3 Stack Test Section 9 — Source Classification Is this a new previously un-permitted source? X Yes No What is this facility classification? True Minor X Synthetic Minor Major Classification relates to what programs? X Title V PSD X NA NSR X MACT Is this a modification to an existing permit? Yes X No If "yes" what kind of modification? Minor Synthetic Minor Major Section 10 — Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If "yes", for which pollutants? Why? CO, VOC, HAPs For Reg. 3, Part B, III.C.1.a (emissions increase > 25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? Yes No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 — Modeling Is modeling required to demonstrate compliance with National Ambient Air Quality Standards (NAAQS)? Yes X No If "yes", for which pollutants? Why? AIRS Point Section 12 — Regulatory Review Regulation 1 - Particulate.. Smoke, Carbon Monoxide and Sulfur Dioxide Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2 — Odor Section LA - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation: 3 - APENs;- Construction Permits, Operating Permits, PSD Part B — Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY threshold (Reg. 3, Part B, Section II.D.3.a) 006 006 006 Page 3 006 006 006 Regulation 6 - Nei NSPS LLL: Each sweetening (amine) unit and each sweetening unit followed by a sulfur recovery unit; manufacturer date after January 24, 1984. So ce Performance Standards - Applicant is subject to NSPS LLL. This source will have a design capacity less than 2 long tons/day H2S in the acid gas based on the information submitted in the application. This source will be required by 60.647(c) to keep for the life of the equipment an analysis demonstrating that the facility's design capacity is less than 2 LT/D of H2S expressed as sulfur. No other requirements apply. NSPS OOOOa: Each sweetening (amine) unit and each sweetening unit followed by a sulfur recovery unit at a natural gas processing plant; manufacturer date after September 2015. Applicant is subject to NSPS 0000a because • The facility is a natural gas processing plant and the manufacturer date is after September 2015, therefore, source is subject to this subpart. Rep ulation 7 — Volatile <3rpanic Compounds None Reuulation 8 — Hazardous Air Pollutants 006 None Section 13 — Aerometric Information Retrieval System Coding Information Point Process Process Description Emission Factor Pollutant / CAS # Fugitive (Y/N) Emission Factor Source Control (%) 006 01 Amine Unit 16.03 lbs/MMscf VOC No Process Simulator 95 0.06807 lbs/MMscf 0.04937 lbs/MMscf 0.00297 lbs/MMscf 0.00873 lbs/MMscf 0.28978 lbs/MMscf 0.00005 lbs/MMscf Benzene / 71432 No Process Simulator 95 Toluene/ 108883 No Process Simulator 95 Ethylbenzene / 10O414 No Process Simulator 95 Xylenes / 13301207 No Process Simulator 95 n -Hexane / 110543 No Process Simulator 95 224TMP / 540841 No Process Simulator 95 SCC 31000305 — Gas Sweetening; Amine process Emission factors include flash tank and still vent and that factors are based on natural gas processing of 7300 MMScf/yr. Page 4 Section 14 — Miscellaneous Application Notes AIRS Point 006 Amine Unit The table below summarizes the inputs to the process simulation used to calculate the PTE for this equipment. Type of Amine Methyldiethanolamine Control Factor 95% Inlet Gas Pressure (psig) 940 Inlet Gas Temperature ('F) 114 Inlet Gas Volumetric Flowrate (MMSCFD) 20.000 Absorber Tray Number 21 _ __ Flash Tank Pressure (psia) 72.3 Lean Amine Stream to Absorber Pressure (psia) 987.30 Lean Amine Stream to Absorber Temperature ('F) 120 Lean Amine Stream to Absorber Volumetric Flowrate (gpm) 60 Weight % Amine (wt%) 50 Mole Loading H2S (ppm) 4.00E+00 Mole Loading CO2 (moljmol) 0.0287 Annual Operating Hours (hr/yr) 8,760 Uncontrolled emissions were calculated using Promax based on a non -site -specific sour gas sample. Inlet gas H2S concentration was assumed to be 4 ppm. Flash tank and regenerator emissions streams (lb/hr) were summed to calculated VOC and HAP emissions and emission factors. Does this amine unit have a reboiler? Yes, 6.0 MMBtu/hr, accounted for at point 008 (permit -exempt due to less than 10 MMBtu/hr) If Yes, what is the reboiler rated? 6.0 mmbtu/hr Page 5 Glycol Dehydrator Emissions Inventory 007 Dehydrator IFecility Al Rs ID: Plan Section 02 - Equipment Description Details Dehydrator Information Dehydrator Type: Make: Model: Serial Number: Design Capacity: Recirculation Pump Information Number of Pumps Pump Type Make: Model: Design/Max Recirculation Rate: Dehydrator Equipment Flash Tank Reboiler Burner Stripping Gas Dehydrator Equipment Description Emission Control Device Description: MMsct/day , flash tank, and reboiler burner One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: TOD, Model: TBD, Serial Number: TBD) with a design capacity of 20 MMscf per day. This emissions unit is equipped with TBD (Make: TOO, Model: TOO) electric driven glycol pump with a design capacity of 4 gallons par minute. This dehydration unit is equipped with a still vent, flash tank, and reboiler burner. Emissions from the still vent are routed to an air-cooled condenser, and then to the Thermal Oxidizer: Emissions from the flash tank are routed directly to the Thermal Oxidizer. Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions- Dehydrator Still Vent and Flash Tank (0 present) Requested Permit Limit Throughput 7000.0 MMscfper year Potential to Emit (PTE) Throughput = 7,300 MMscf per year Secondary Emissions - Combustion Devlce(s) for Pie Pollution Control Still Vent Control Condenser: Condenser emission reduction claimed: Primary control device: Primary control device operation: Secondary control device: Secondary control device operation: Still Vent Ges Heating Value: Still Vent Waste Gas Vent Rate: Flash tank Control Primary control device: Primary control device operation: Secondary control device: Secondary control device operation: Flash Tank Gas Heating Value Flash Tank Waste Gas Vent Rate: Section 04- Emissions Factors & Methodologies Dehydrator I-GLTCalc 3.Gto estimate.69 rature: ......_ 31 45%C trolEfficiency% Requested TO Tamp Control Efficiency % :Control Efficiency% Control Efficiency % Input Parameters Inlet Gas Pressure Inlet Gas Temperature Requested Glycol Recirculate Rate STILL VENT Control Scenario Primary Secondary Pollutant Uncontrolled (lb/hr) Controlled (lb/hr) Controlled (lb/hr) VOC ;;;;,7.814 0.3807 = 9 Benzene ;,. 0.0831 0.004156 0 Toluene 3 ll" '4,07u3 0.003015 d Ethylbenzene .0082 0,00041 0 XYlenes n -Hexane 4.9833 4 0,043165 0 224-TMP 0.6002 -; 0.00005 _ 0 FLASH TANK Control Scenario Primary Secondary Pollutant Uncontrolled (lb/hr) Controlled (Ib/hrl Controlled (lb/hr) VOC ::!13,113& •• 055558 0 Benzene (70020;`C ,,,,:,0:-0001 0 Toluene ,,,3390053 ':': %.4:00006s 0 Ethylbenzene XYlenes l. 0,0062. .. .. 0:00001 0 n -Hexane 0,8282 = 0.69141 0 • 224 -IMP ;' .',,, ; 9,6002 0.0000'+ 0• ••,,•••• ':i'". Emission Factors Glycol Dehydrator Pollutant Uncontrolled (Ib/MMscf) (Ib/MMscf) (Dry Gas Throughput) Controlled (Dry Gas Throughput) VOC 24.87 1.24 Benzene Toluene 0.10212 0.09312 0.00996 0.02928 1.9338 0.00048 0.005106 0.004606 0.000498 0.001464 0.09669 0.000024 Ethylbenzene Xylene n -Hexane 224 IMP Emission Factor Source Dry Gas Throuehput: Still Vent Primary Control: 7,300.0 MMscf/yr Still Vent Secondary Control: 0.0MMscf/yr Waste Gas Combusted: Still Vent Primary Control: 0.0 MMscf/yr Still Vent Secondary Control: 0.0 MMscf/yr Dry Gas Throuahput: Flash Tank Primary Control: 7,300.0 MMscf/yr Flash Tank Secondary Control: 0.0 MMscf/yr Waste Gas Combusted: Flash Tank Primary Control: 0.0 MMscf/yr Flash Tank Secondary Control: 0.0 MMscf/yr 620.0 0.0 Glycol Dehydrator Emissions Inventory Section 05 - Emissions Inventory Did operator request a buffer? Requested Buffer (%): Criteria Pollutants Potential to Ernie Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) PM10 PM2.5 500 NOx CO VOC 90.8 90.8 4.5 90.78 4.54 771 Hazardous Air Pollutants Potential to Emit Uncontrolled (ibs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (Ibs/year) Requested Pe mit Limits Uncontrolled Controlled (Ibs/year) (Ibs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224TMP 745 745 37 745 37 680 680 34 680 34 73 73 4 73 4 214 214 01 214 11 14117 14117 706 14117 706 4 4 0 4 0 Section O6- Regulatory Summary Analysis _ Regulation 3, Parts A, B Regulation 7, Section XVII.0,0 Regulation 7, Section XVII.B.2.e Regulation 7, Section XII.H Regulation 8, Part E, MACT Subpart HH (Area) Regulation 8, Part y, MACT Subpart HH (Major) Regulation 8, Part E, MACT Subpart HHH (See regulatory applicability worksheet for detailed analysts) Source requires a permit Dehydrator is subject to Regulation 7, Section XVII, B, D.3 The control device for this dehydrator is not subject to Regulation 7, Section XVII.B.2.e Dehydrator is subject to Regulation 7, Section XII.R The dehy unit meets the benzene exemption You have indicated that this facility Is not subject to Major Source requirements of MACT HH. You have indicated that this facility is not subject to MAR HHH. Section 07 - Initial and Periodic Sampling and Testing Requirements Was the extended wet gas sample used in the GlyCalc model/Process model site -specific and collected within a year of application submittal? ta;. If no, the permit will contain an "Initial Compliance" testing requirement to demonstrate compliance with emission limi Does the company request a control device efficiency greater than 95%for a Rare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling If the company has requested a control device efficiency greater than 95%, is a thermal oxidizer or regenerative thermal oxidizer being used to achieve it? If yes,the permit will contain a condition specifying the minimum combustion chambertempereture for the thermal oxidizer No Is the company using a thermal oxidizer AND requesting a minimum combustion chamber temperature lower than 1,400 degrees F? Na1u,%d If yes, the permit will contain an "Initial Compliance" testing requirement AND a permit condition specifying the minimum combustion chamber temperature for the thermal oxidizer. Sectl 00 T h l I Am ty l Notes counted fort econdarY,:erds Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # NI coattah Gritial arid':-: Process # SCC Code ''�..,�""[[ 007 01Ag..are'" ,p Uncontrolled Pollutant Emissions Factor Control % PM10*see below" PM2.5 ee below" 300*see below" NOx *see below" VOC s 24.9 CO "'see below" Benzene s 0.102 Toluene 0.093 Ethylbenzene 0.010 Xylene 0.029 n -Hexane 1.934 224 IMP 0.000 0.0 0.0 0.0 0.0 95.0 0.0 95.0 95,0 05.0 95.0 95.0 95.0 Units b/MMscf b/MMscf b/MMscf b/MMscf b/MMscf b/MMscf b/MMscf b/MMscf b/MMscf b/MMscf b/MMscf b/MMsct i's• Secondary emissions are accounted for in Point 010.'•* Natural Gas Heater Emissions Inventory DOS NG Heater Facility AIRS ID: 123 County Plant Point Section 02- Equipment Description Details Heater Information Fuel Type Number of Heaters Purpose Make: Model: Serial Number: Design Heat Input Rate: Equipped with Low -NOR burners: Equipped with Add -On Control Equipment: PERMIT EXEMPT 18WE0456.XP One (1) natural gas heater(s) (Make: TBD, Model: TBD, Serial Number: TBD) each with a design heat input rate of 6 MMBtu/hr. This unit is an amine regeneration neater. Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Section 03- Processing Rate Information for Emissions Estimates Design Heat Input Rate= Heat content of waste gas= Actual Hours of Operation = Requested Hours of Operation = Requested heat input rate = Actual Fuel Consumption = No add-on control equipment 6 MMBtu/hr Btu/scf hrs/year hrs/year 52,560.00 MMBTU per year 48.26 MMscf/year Requested Fuel Consumption = 48.26 MMscf/year Requested Monthly Throughput = 4 MMscf per month Potential to Emit (PTE) Fuel Consumption = Section 04- Emissions Factors & Methodologies Emission Factors Natural Gas Heaters Pollutant Uncontrolled Uncontrolled Ib/MM Btu Ib/MMscf (Fuel Heat Combusted) (Fuel Consumption) 8.114117647 8.114117647 0.640588235 106.7647059 89.68235294 5.872058824 0.080073529 0.002242059 PM10 PM2.5 0.007 6098 0.000588235 SOx NOR CO VOC ,- 0;0980 0♦ 7.352940.0-` Formaldehyde Benzene Toluene n -Hexane 0.00363 764706 1.921764706 Section 05 - Emissions Inventory 48.26 MMscf/year Emission Factor Source Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tans/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled inns/month) PM10 PM2.5 50x NOR CO VOC 0.20 0.20 0.20 0.20 0.20 33 0.20 0.20 0.20 0.20 0.20 33 0.02 0.02 0.02 0.02 0.02 3 2.58 2.58 2.50 2.58 2.58 438 2.16 2.16 2.16- 2.16 2.16 368 0.14 0.14 0.14 0.14 0.14 24 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled llbs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Formaldehyde 4 4 4 4 4 Benzene 0 0 0 Si 0.1 Toluene 0 0 0 0.2 0.2 n -Hexane 93 93 93 93 93 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 1, Section VI Regulation 1, Section III & Regubtion 6, Part B, Section II Regulation 6, Part A, Subpart lb, 502 Standards Regulation 6, Part A, Subpart Db, NOx Standards Based on the requested emissions and emission factor, compliance is presumed. Based on the design heat input rate, the source is subject to Regulation 1 Section III.A.1.c. and Regulation 6, Part A, Section II.C.3. Based on the requested e Source is not subject to NSPS Db. Source is not subject to NSPS Db. Regulation 6, Part A, Subpart Dr Regulation7, Section XVI.D Source is not subject to NSPS Dr_ Source is not subject to Regulation 7, Section XVI.D. Regulation 8, Part E, MAR Subpart DDDDD Source is not subject to MAC DIODE. 3 of 16 K:\PA\2018\18 W E0444.CP1.xlsm Natural Gas Heater Emissions Inventory (See regulatory applicability worksheet far detailed analysis) Section 07- Initial and Periodic Sampling and Testing Requirements Is the project close to the 40 tpy modeling / NANSR threshold for NOx? If yes, stack -testing should be required for NOx, as well as for CO. Is the operator limiting their heat input rate below the design rate? If yes, stack -testing should be required for NOx, as well as for CO. Is the project close to the 5 tpy modeling threshold for PM 2.5? If yes, stack -testing should be required for PM 2.5 Does the company use AP -42 emission factors (or more conservative factors)? WESIM If no and testing hasn't already been required due to proximity to modeling thresholds, testing should be required for any pollutants for which alternative emission factors have been used. If testing is being done for only NOx or only CO, the other should be included as well. Section 08 - Technica Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 008 Process # SCC Code Uncontrolled Emissions Pollutant Factor Control% Units 01 13-10-004-04: Industrial Process; Oil & Gas Production; Process Heaters; Natural Gas (MMscf) P6410 8.11 0 Ib/MMscf Burned PM2.5 8.11 0 lb/MMscf Burned 5Ox 0.64 0 lb/MMscf Burned NOx 106.76 0 lb/MMscf Burned CO 89.68 0 Ib/MMscf Burned VOC 5.87 0 lb/MMscf Burned Formaldehyde 8.01E-02 0 Ib/MMscf Burned Benzene 2.24E-03 0 lb/MMscf Burned Toluene 3.63E-03 0 lb/MMscf Burned n -Hexane 1.9 0 Ib/MMscf Burned 4 of 16 K:\PA\2018\ 18WE0444.CP1.xlsm Natural Gas Heater Emissions Inventory 009 NG Heater 'Facility AIRs ID: County 9007 3 1 illl :009,;.''. Plant Point Section 02 - Equipment Description Details Heater Information Fuel Type Number of Heaters Purpose Make: Model: Serial Number: Design Heat Input Rate: Equipped with Low-NOx burners: Equipped with Add -On Control Equipment: Natural Gas One (1) MMBtu/hr One (1) natural gas heater(s) (Make: Fulton, Model: 12005-LF, Serial Number: TBD) each with a design heat input rate of 12 MMBtu/hr. Each unit is a hot oil heater. Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Design Heat Input Rate = Heat content of waste gas= Actual Hours of Operation = Requested Hours of Operation = Requested heat input rate = Actual Fuel Consumption = No add-on control equipment 12 MMBtu/hr Btu/set hrs/year hrs/year 105,120.00 MMBTU per year 96.53 MMscf/year Requested Fuel Consumption = 96.53 MMscf/year Requested Monthly Throughput = MMscf per month Potential to Emit (PTE) Fuel Consumption = 0.011019284 11019.28375 Section 04- Emissions Factors & Methodologies 96.53 MMscf/year Emission Factors Natural Gas Heaters Pollutant Uncontrolled Uncontrolled lb/MMBtu Ib/MMscf (Fuel Heat (Fuel Combusted) Consumption) glOV7450.98MA 8.114117647 p98, yl: 8.114117647 0.640588235 Emission Factor Source PM10 PM2.5 50x NOx CO VOC Formaldehyde Benzene Toluene n -Hexane 31.737 89.68235294 5.872058824 0.080073529 0.002242059 0.00363 1921764706 Section OS - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) PM10 PM2.5 5Ox NOx CO VOC 0.39 0.39 0.39 0.39 0.39 67 0.39 0.39 0.39 0.39 0.39 67 0.03 0.03 0.03 0.03 0.03 5 1.53 1.53 1.53 1.53 1.53 260 4.33 4.33 4.33 4.35 4.33 735 -.-_ 0.28 0.28 0.28 0.28 0.28 48 Hazardous Air Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled (Ibs/year) (Ibs/year) Formaldehyde 8 8 8 8 8 Benzene 0 0 0 0.2 0.2 Toluene 0 0 0 0.4 0.4 n -Hexane 186 186 186 186 186 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, R Source requires a permit Regulation 1, Section VI Based on the requested emissions and emission factor, compliance is presumed. Regulation 1, Section III & Regulation 6, Part B, Section II Based on the design heat input rate, the source is subject to Regulation 1 Section III.A.1.c. and Regulation 6, Part B, Section II.C.3. Based on the requested e Regulation 6, Part A, Subpart Db, SO2 Standards Not enough information. Regulation 6, Part A, Subpart Dh, 900 Standards Source is not subject to NSPS Db. Regulation 6, Part A, Subpart Sc Source is subject to NSPS Dc. Regulation 7, Section XVI.D Source is not subject to Regulation 7, Section XVI.D. Regulation 8, Part E, MACC Subpart DODDD Source is not subject to MACT 00000. 5 of 16 K:\PA\2018\18W E0444.CP1.xlsm Natural Gas Heater Emissions Inventory (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Is the project close to the 40 tpy modeling/ NANSR threshold for NOx? If yes, stack -testing should be required for NOx, as well as for CO. Is the operator limiting their heat input rate below the design rate? If yes, stack -testing should be required for NOx, as well as for CO. Is the project close to the 5 tpy modeling threshold for PM 2.5? If yes, stack -testing should he required for PM 2.5 Section 00-1echaicol Analysis Notes RppE000F r h na,oun c-' rersspe hook ...................... e Tollbeoegouedfor-NOx ono CO inn do eg Manu€actdrer's spec sheet Ita4 NOx omission concegtra,;iu ?-Factor. 0719 DSCPjMNIBtu( malnle 18,Zo1;f 3A0102: 3% ' Corvertl ppm Noy -> 1'.194E 071bfDSG¢3GG1 f Cx ernO5i00 lEctorflb/MMBW]: E a Cd x Fd;+. E (2ay 194E-07) ° (8710)= (20,5/P9'0,4 TE;is ItEtlEANIBEE was multiplied by:tholsae( 41.. Section 09 - Inventory SCC Coding and Enissions Factors order to use this emisstun'factor [and not Ap-42)the perm' Uncontrolled Emissions AIRS Point # Process # SCC Code Pollutant Factor Control % Units 009 01 3-10-004-4: Industrial Process; Oil & Gas Production; Process Heaters; Natural Gas (MMscf) PM10 8.11 0 lb/MMscf Burned PM2.5 8.11 0 lb/MMscf Burned SOx 0.64 0 Ih/MMscf Burned 500 31.74 0 Ib/MMscf Burned CO 89.68 0 Ib/MMscf Burned VOC 5.87 0 lb/MMscf Burned Formaldehyde 8.01E-02 0 lb/MMscf Burned Benzene 2.24E-03 0 lb/MMscf Burned Toluene 3.63E-03 0 lb/MMscf Burned n -Hexane 1.9 0 lb/MMscf Burned 6 of 16 K:\PA\2018\18W E0444.CP1.xlsm Separator Venting Emissions Inventory 010 Separator Venting 1 Facility AIRs ID: County 9FB7. Plant Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency % Limited Process Parameter Gas meter Section 03 - Processing Rate Information far Emissions Estimates Pilot Natural Gas Usage (scfh) Assist Gas Usage (scfh) Natural Gas Fuel (Btu/scf) Waste Gas Heat Value Calculation Amine Flash Amine Regen TEG Dehy Flash TEG Dehy Regen Gunbarrel tank Slop tank Condensate tanks Produced water tank Condensate loadout Slop/PW loadout 20 scfh 1010 scfh 1089 Btu/scf Flowrate (Mscfh) Heat value (Btu/scf) 0.75 15.272 1.42 0.0831 0.02495 0.007029 0.02391 0.007029 0.0504 0.005968 Total 17.64 Weighted Average, waste gas [Stream Sent to Flare Heat Value of Stream (Btu/scf) Annual Heat Input (MMBtu/yr) Total Heat Input Total Volumetric Flow Rate 1188.98 from Promax 9.21852 from Promax 1700 Assumed typical 280 Assumed typical 3926.99 from E&P TANKS 3928.18 from E&P TANKS 3926.99 from E&P TANKS 3928.18 from E&P TANKS 3926.99 assumed to be equal to tank vapors 3928.18 assumed to be equal to tank vapors 223.20 Btu/scf re I PiWtawwdltsaisXsas 223.20 1089 17644.386 1030 154564821.4 3.938246998 34499.0437 9022800 1.12167 9825.8292 44324.87 MMBtu/yr 163.59 MMscf/yr 270.955 Btu/scf VOC and HAP control are accounted for at each individual point. This point only accounts for secondary emissions from control of the above -listed points. I accepted the applicant's proposed use of NOx and CO emission factors from TCEQ Technical Guidance for Flares and Vapor Oxidizers, RG-109. I accepted the applicant's proposed use of AP -42 Section 1.4 (Tables 1.4-1 and 1.4-2) emission factors for PM and 5O2. Emission Factor, lb/MMSCF Emission Factor, Ib/MMBtu NOX - 0.138 CO - 0.2755 PM10 7.6 0.0075 PM2.5 5.7 0.0056 5O2 0.6 0.0006 Emission Factors Flare Pollutant Uncontrolled (Ib/MMscf) (Gas Throughput) Emission Factor Source VOC 5.5000 0.0021 0.0034 1.8000 Benzene Toluene n -Hexane AP -42 Table 1.4-2 AP -42 Table 1.4-3 AP -42 Table 1.4-3 AP -42 Table 1.4-3 Pollutant Flare Uncontrolled (Ib/MMBtu) (Waste Heat Combusted) Emission Factor Source PM10 PM2.5 SOx NOx CO O138O 0.2755 7 of 16 K:\PA\2018\18W E0444.CP1.xlsm Separator Venting Emissions inventory Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year). Actual Emissions Uncontrolled Controlled (tans/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) PM10 PM2.5 SOx NOx VOC CO 0.17 0.17 0.17 28 0.12 0.12 0.12 21 0.01 0.013 0.013 2 3.06 3.058 3.068 520 0.45 0.450 0.450 76 6.11 6,106 6.106 1037 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (Ibs/year) (Ibs/year) Benzene Toluene n -Hexane 0 0.3 0.3 1 0.6 0.6 294.46 294.5. 294.5 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XVII.8.2.e (Subject to XV11.B.2.e. (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Using Gas Throughput to Monitor Compliance Does the company use site specific emission factors based on a gas sample to estimate emissions? This sample should represent the gas outlet of the equipment covered under this AIRS ID, and should have been collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. Will the operator have a meter installed and operational upon startup of this point? Yes If no, the permit will contain a condition that requires the operator to calculate gas throughput using the liquid throughput until the meter is installed and operational (not to exceed 180 days). This condition will use the "Volume of waste gas emitted per BBL of liquids throughput" (scf/bbl) value in section 03. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling You have indicated above that the monitored process parameter is natural gas vented. The following questions do not require an answe Section 08 - Technical Analysis Notes no additional notes Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point It Process # SCC Code 010 01 3-10-001-60 Flares Uncontrolled Emissions Pollutant Factor Control % Units PM10 2.0189 0 Ib/MMSCF PM2.5 1.5142 0 Ib/MMSCF SOx 0.1594 0 Ib/MMSCF NOx 37.3918 0 lb/MMSCF VOC 5.5000 0 Ib/MMSCF CO 74.6481 0 Ib/MMSCF Benzene 0.0021 0 lb/MMSCF Toluene 0.0034 0 lb/MMSCF n -Hexane 1.8000 0 lb/MMSCF 8 of 16 K:\PA\2018\ 18WE0444.CP1.xlsm Condensate Storage Tank(s) Emissions Inventory 011 Condensate Tank (Facility AIRs ID: County Plan 011 11i H5 Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: orre(X) SOB -hi k tar the Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions- Storage Tank(s) Actual Condensate Throughput = Requested Permit Limit Throughput = 0 Barrels (bbl) per year Buedwat Actual Condensate Throughput While Emissions Controls Operating = Requested Monthly Throughput = 31384 Barrels (bbl) per month .80 Barrels (bbl) per year Potential to Emit (PTE) Condensate Throughpu Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per BBL of liquids produced = ' scf/bbl Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = Barrels (bbl) per year 31384.4 Btu/scf Secondary emissions are accounted for in Point 010 (TO). 0 MMBTU per year 0 MMBTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 0 MM BTU per year Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Emission Factors Condensate Tank Pollutant Uncontrolled • Controlled (Ib/bbl) (Ib/bbl) (Condensate Throughput) (Condensate Throughput) VOC ......x;;,,0.1121# 0.0056 0.00004 0.00002 0.000002 0.000003 Benzene Toluene Ethylbenzene 0.00003 Xylene 01 n -Hexane 224 TMP 0.0006 0.0001104___:': 0.0000002 Emission Factor Source Emission Factor Source Pollutant Control Device Uncontrolled Uncontrolled (Ib/MMBtu) (Ih/bbl) (waste heat combusted) (Condensate Throughput) • PM10 0.0000 0.0000 0.0000 0.0000 PM2.5 NOx CO Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) VOC PM10 PM2.5 NOx CO 20.7 20.72 1.04 176 Hazardous Air Pollutants Potential to Emit Uncontrolled fibs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled (Ibs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 275 275 14 150 - 150 7 12 12 1 24 24 1 4412 4412 • 221 1 1 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XII.C, D, E, F Storage Tank is not subject to Regulation 7, Section XII.C-F Regulation 7, Section XII.G, C Storage Tank is not subject to Regulation 7, Section XII.G Regulation 7, Section XVI I.B, C.1, C.3 Storage tank is subject to Regulation 7, Section XVII, B, C.1 & C.3 Regulation 7, Section XVI I.C.2 Storage Tank is not subject to Regulation 7, Section XVII.C.2 Regulation 6, Part A, NSPS Subpart Kb Storage Tank is not subject to NSPS Kb Regulation 6, Part A, NSPS Subpart 0000a Storage Tank is not subject to NSPS 0000a Regulation 8, Part E, MACT Subpart OH Storage. Tank is not subject to MACT HH (See regulatory applicability worksheet for detailed analysis) 175.9610959 Barrels (bbl) per year 9 of 16 K:\PA\2018\ 18WE0444.CP1.xlsm Condensate Storage Tank(s) Emissions Inventory Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use the state default emissions factors to estimate emissions? If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company use a site specific emissions factor to estimate emissions? if yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 0S-01. Does the company request a control device efficiency greater than 95% for a flare or combustion device? ihv ri%aii.,v If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08- Technical Analysis Notes Pracessuesselfor stabilized li% H sepa_f moRtpiytng:the vapor weigh₹ %HAP cd AIRS Point Section 09 - Inventory SCC Coding and Emissions Factors Process# SCC Code 011 01 Uncontrolled Emissions Pollutant Factor Control % Units PM10 see below* PM2.5 *see below* NOx *see below* VOC 2.7 95 lb/1,000 gallons condensate throughput CO *see below* Benzene 0.0177 95 lb/1,000 gallons condensate throughput Toluene 0.0097 95 lb/1,000 gallons condensate throughput Ethylbenzene 0.0008 95 lb/1,000 gallons condensate throughput Xylene 0.0016 95 lb/1,000 gallons condensate throughput n -Hexane 0.2843 95 lb/1,000 gallons condensate throughput 224 TMP 0.0001 95 lb/1,000 gallons condensate throughput ***PM, NOx, and CO emissions are accounted for in point 010**** 10 of 16 K:\PA\2018\18W E0444.CP1.xlsm Condensate Storage Tank(s) Emissions Inventory 012 Condensate Tank 'Facility AIRS ID: County Plant Section 02- Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Condensate Throughput = Requested Permit Limit Throughput = Barrels (bbl) per year Barrels (bbl) per year Requested Monthly Throughput = Actual Condensate Throughput While Emissions Controls Operating = 31384 Barrels (bbl) per month Potential to Emit (PTE) Condensate Throughpu Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per BBL of liquid produced = scf/bbl Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = f26; Barrels (bbl) per year Btu/scf Secondary emissions are accounted for in Point 010 (TO). 0 MM BTU per year 0 MMBTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 0 MMBTU per year Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Emission Factors Condensate Tank Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) (Condensate (Condensate Throughput) Throughput) Emission Factor Source VOC 0.005373 0.000036 0.000019 0.000002 0.000003 0.000572 0.0000002 Benzene Toluene 0:0004;', 3I IjIJ Ethylbenzene 224 TMP 0.000004"/, Emission Factor Source Pollutant Control Device Uncontrolled Uncontrolled (Ib/MMBtu) (lb/bbl) (waste heat (Condensate combusted) Throughput) PM10 PM2.5 NOx CO Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (Ibs/month) VOC PM10 PM2.5 NOx CO 19.9 0.0 0.0 19.85 0.99 169 Hazardous Air Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled (Ibs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 263 263 13 144 144 7 12 12 1 23 23 1 4228 4228 211 1 1 0 Section 06 - Regulatory Summary AnaNsis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XII.C, D, E, F Storage Tank is not subject to Regulation 7, Section XII.C-F Regulation 7, Section XII.G, C Storage Tank is not subject to Regulation 7, Section XILG Regulation 7, Section XVII.B, C.1, C.3 Storage tank is subject to Regulation 7, Section XVII, B, C.1 & C.3 Regulation 7, Section XVII.C.2 Storage Tank is not subject to Regulation 7, Section XVII.C.2 Regulation 6, Part A, MPS Subpart Kb Storage Tank is not subject to NIPS Kb Regulation 6, Part A, NIPS Subpart 0000a Storage Tank is not subject to MPS 0000a Regulation 8, Part E, MACT Subpart HH Storage Tank is not subject to MACT HH (See regulatory applicability worksheet for detailed analysis) 168.6230137 Barrels (bbl) per year 11 of 16 K: \ P A\2018\ 18 W E0444. C P 1. x l sm Condensate Storage Tank(s) Emissions Inventory Section 07- Initial and Periodic Sampling and Testing Requirements Does the company use the state default emissions factors to estimate emissions? If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? tifk If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. jj Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the faciity has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company request a control device efficiency ./.14 , q greater than 95% far a flare or combustion device?,�, /j If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 -Technical Analysis Notes Storage ueysel far stuiatllzed condensate. storage. Appicantosed m from doe coadensategasesas.madeled by E&PTAP. ed fnf?nP9lotD1S (t'iarel, Section 09 - Inventory 5CC Coding and Emissions Factors AIRS Point S Process 0 5CC Code 012 - 01 Imed irj<aming IiquSdco VOC emission €actor.; Permitwiil requSre sanfpSit Uncontrolled Emissions Pollutant Factor Control % Units PM10 'see below" PM2.5 ..see below' NOx esee below° VOC 2.6 95 lb/1,000 gallons condensate throughput CO .see below" Benzene 0.02 95 lb/1,000 gallons condensate throughput Toluene 0.01 95 lb/1,000 gallons condensate throughput Ethylbenzene 0.00 95 Ib/1,000 gallons condensate throughput Xylene 0.00 95 lb/1,000 gallons condensate throughput n -Hexane 0.27 95 lb/1,000 gallons condensate throughput 224 TMP 0.00 95 lb/1,000 gallons condensate throughput NOx, and CO emissions are accounted for in point 010°an0 12 of 16 K:\PA\2018\18WE0444.CP1.xlsm Hydrocarbon Loadout Emissions Inventory 013 Liquid Loading Facility AIRs ID: County 9F07 Plant 013:: Point Section 02- Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Is this loadout controlled? 0.00 ressurier} natural: gas liquid Requested Overall VOC & HAP Control Efficiency %: Section 03- Processing Rate Information for Emissions Estimates Primary Emissions- Hydrocarbon Loadout Actual Volume Loaded = Requested Permit Limit Throughput Potential to Emit (PTE) Volume Loaded = Barrels (bbl) per year Actual Volume Loaded While Emissions Controls Operating = 3919,320;„ Barrels (bbl) per year Requested Monthly Throughput = 290408 Barrels (bbl) per month Secondary Emissions - Combustion Device(s) Section 04 - Emissions Factors & Methodologies NGL requested throughput Capacity of truck Number of trucks Load Line: NGL V0C content by wt NGL benzene content by wt NGL toluene content by wt NGL ethylbenzene content by wt NGL xylenes content by wt NGL n -hexane content by wt NGL 2,2,4 -IMP content by wt NGL methanol content by wt Connection diameter Length between valves: Connection volume: Number of hoses Volume per load Loadout temperature Molecular weight Vapor Pressure @ avg liq surface temp Vapor Density Vapor emission rate, per load VOC emission rate, per load VOC emission rate, per barrel 3,419,320 Barrels (bbl) per year 3,419,320 bbl/yr 214.286 bbl/load 15956.83 loads / year 0.972525 0.001264 0.003100 0.000992 0.002807 0.110378 0.001538 0.000000 MM BTU per year MMBTU per year MMBTU per year assumed by applicant (9000 gal/truck) assumed by applicant from a similar gas plant assumed by applicant from a similar gas plant assumed by applicant from a similar gas plant assumed by applicant from a similar gas plant assumed by applicant from a similar gas plant assumed by applicant from a similar gas plant assumed by applicant from a similar gas plant not included in NGL speciation 0.167 ft 25 ft 0.545 ft° 2 1.091 ftt/load 115 F 574.67 R 57.48425 Ib/Ibmol 20.28 psia 0.189 lb/f0 0.20621 lb/load 0.20055 lb VOC / load 0.000935886 lb VOC / bbl assumed value assumed value calculated geometry reported by applicant reported by applicant assumed from ProMax modeller condensate RVP calculated by Ideal Gas Law with R =10.731 ft3"psi/Ibmol/degR 1.30333E-07 Component Mass Fraction Emission Factor Units Source Benzene 0.001264068 1.21645E-06 lb/bbl -assumed by applicant from a similar gas plant Toluene _..:0.003099864 2.98308E-06 lb/bbl -assumed by applicant from a similar gas plant Ethylbenzene -'0.000992282 9.54899E-07 lb/bhl -assumed byapplicantfrom a -Si lac gas plant Xylene .. 0.002806709 2.70097E-06 lb/bbl assn mod by applicant from a similar gas plant n -Hexane 0.110377Or; '8, : 0.000106219 lb/bbl assumed by-applicaotfrom a:simliar gas plant 224TMP 3,00153761... 1.47968E-06 lb/bbl assumed by amslicant{romusimeilargas plant Methanol i 0 0 lb/bbl assumed by applicant Barrels (bbl) per year 13 of 16 K:\PA\2018\18 W E0444.CP1.xlsm Hydrocarbon Loadout Emissions Inventory Emission Factors Hydrocarbon Loadout Pollutant Uncontrolled Controlled (Ib/bbl) (Ib/bbl) (Volume Loaded) (Volume Loaded) 9.36E-04 1.22E-06 2.98E-06 9.55E-07 2.70E-06 1.06E-04 1.48E-06 0.00E+00 Emission Factor Source VOC 0.000936., = 0.000001 _ 00000031''! 0.000001 0.000003 0.000100 .0.000001 Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP Methanol Engineering calculation Engineering calculation Engineering calculation Engineering calculation Engineering calculation Engineering calculation Engineering calculation Engineering calculation Pollutant Control Device Uncontrolled Uncontrolled (IbJMMBtu) - (lb/bbl) (waste heat combusted) (Volume Loaded) PM10 PM2.5 SOx NOx CO Emission Factor Source Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (Ibs/month) PM10 PM2.5 SOx NOx VOC CO 1.60 1.60 1.60 272 Hazardous Air Pollutants Potential to Emit Uncontrolled )Ibs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (Has/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (Ibs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP Methanol 4 4 4 10 10 10 3 3 3 9 9 9 363 363 363 5 0 5 0 5 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, 0 Source requires a permit RACT- Regulation 3, Part 3, Section III.D.2.a (See regulatory applicability worksheet for detailed analysis) N/A — Submerged fill and RAcT not required because this is a pressurized liquid loadout operation. Section 07 - Initial and Periodic Sampling and Testing Requirements You have indicated above the source is not controlled. The following question does not require an answer. Section 08 - Technical Analysis Notes - Permiteewill be required3o develop sit Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 013 Process# 01 bvil ry and asampte of the NOL liquid,: SCC Code 40600171: DisOllate Oil - Loaded with Vapor Uncontrolled Emissions Pollutant Factor Control % Units PM10 PM2.5 5Ox NOx VOC 0.02228 0 lb/1,000 gallons transferred CO Benzene 0.00003 0 lb/1,000 gallons transferred Toluene 0.00007 0 lb/1,000 gallons transferred Ethylbenzene 0.00002 0 lb/1,000 gallons transferred Xylene 0.00006 0 lb/1,000 gallons transferred n -Hexane 0.00253 0 lb/1,000 gallons transferred 224 TMP 0.00004 0 lb/1,000 gallons transferred 14 of 16 K:\PA\2018\18WE0444.CP1.xlsm Hydrocarbon Loadout Emissions Inventory 014 Liquid Loading Facility AIRs ID: 123 County 9FB7 014 Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Is this loadout controlled? Collection Efficiency: Control Efficiency: TrudC[oadbut.ofcnndensateys)op msd produced;wBto Requested Overall VOC & HAP Control Efficiency %: Section 03- Processing Rate Information for Emissions Estimates Primary Emissions - Hydrocarbon Loadout Actual Volume Loaded = IRequested Permit Limit Throughput = Potential to Emit (PTE) Volume Loaded = 95.00 Barrels (bbl) per year Actual Volume Loaded While Emissions Controls Operating = 413,262 Barrels (bbl) per year Requested Monthly Throughput = 413,262 Barrels (bbl) per year 35099 Barrels (bbl) per month Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per year= Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = Btu/scf 568674 scf/year Potential to Emit (PTE) heat content of waste gas routed to combustion device = Section 04- Emissions Factors & Methodologies Does the company use the state default emissions factors to estimate emissions? Does the hydrocarbon liquid loading operation utilize submerged fill? Emission Factors Hydrocarbon Loadout Secondary emissions are accounted for in Point 010 (TO). 0 MMBTU per year 0 MMBTU per year 0 MMBTU per year The state default emissions factors may be used to estimate emissions. Pollutant Uncontrolled Controlled (Ib/bbl) (Ib/bbl) (Volume Loaded) (Volume Loaded) Emission Factor Source VOC Benzene Toluene 0.00041 Ethylbenzene Xylene n -Hexane 224 TMP 0.00360 Pollutant Control Device Uncontrolled (Ib/MMBtu) (waste heat combusted) Uncontrolled (lb/bbl) (Volume Loaded) Emission Factor Source PM10 PM2.5 500 NOx CO 15 of 16 K:\PA\2018\18 W E0444.CP1.xlsm Hydrocarbon Loadout Emissions Inventory Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) PM10 PM2.5 SOx NOx VOC CO 48.76 0.00 0.00' 48.76 2438 414 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (Has/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 169 169 8 1488 1488 74 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit RACT- Regulation 3, Part B, Section III.D.2.a (See regulatory applicability worksheet for detailed analysis) The loadout must operate with submerged fill and loadout emissions must be routed to flare to satisfy RACT. Section 07 - Initial and Periodc Sampling and Testing Requirements Does the company request a control device efficiency greater than 95%for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes This point iec des(,oadbrrt of ca„nde Section 09 - Inventory SCC Cording and Emissions Factors AIRS Point # 014 Process # O1 SCC Code 4-06-001-32 Crude Oil: Submerged Loading Normal Service (S=0.6) Uncontrolled Emissions Pollutant Factor Control % Units PM10 *see below* 1b/1,000 gallons transferred PM2.5 *see below• lb/1,000 gallons transferred 5Ox 'see below' lb/1,000 gallons transferred NOx esee below' lb/1,000 gallons transferred VOC 5.619 95 lb/1,000 gallons transferred CO 'see below* lb/1,000 gallons transferred Benzene 0.0098 95 lb/1,000 gallons transferred Toluene lb/1,000 gallons transferred Ethylbenzene lb/1,000 gallons transferred Xylene lb/1,000 gallons transferred n -Hexane 0.0857 95 lb/1,000 gallons transferred 224 TMP lb/1,000 gallons transferred *** PM, CO, and NOx emissions are accounted for at point 010 (flare). 16 of 16 K:\PA\2018\ 18WE0444.CP1.xlsm Colorado Department of Public Health Environment Air Pollution Control Division Summary of Preliminary Analysis - Fugitive Components Source Company Name Facility Name Permit No AIRS Permit Engineer Application Date Review Date Taproot Rockies Midstream Radicle Gas Plant 18WE0444 123/9FB7/015 Andy Gruel 4/25/2018 5/11/2018 Summary of Emissions VOC (tpy) Benzene (lb/yr) Toluene (lb/yr) Ethylbenzne (Ib/yr) Xylenes (Ib/yr) n -Hexane (Ib/yr) 224TMP lb/yr Uncontrolled Requested Emissions 129.2 502 1,096 320 838 26,471 314 Controlled Requested Emissions 26.0 83 183 54 143 4,637 56 Reportable? I I Yes Yes Yes Yes Yes Yes Total HAP, Uncontrolled (tpy) 14.8 Total HAP, Controlled (tpy) f 2.6 Highest HAP, Uncontrolled (tpy) 13.2 n -Hexane Emission Factors Emission Factor Source: Controls Stream VOC Fraction: Gas 0.2545 Light Oil (NGL) 0.9725 Light Oil (Condense 1.0000 Heavy Oil 1.0000 Water/Oil 1.0000 EPA -453/R-95-017, Table 2-4, except "Heavy Oil / Pump Seals" where Table 2-2 was used. Monthly monitoring per NSPS 0000a Stream HAP Components (wt frac) HAP Gas Light Oil (A Light Oil (Cont Heavy Oil Water/Oil Benzene 0.00009 0.0013 0.0141 0.0000 0.0000 Toluene 0.00007 0.0031 0.0279 0.0000 0.0000 Ethylbenz€ 0.00001 0.0010 0.0073 0.0000 0.0000 Xylene 0.00002 0.0028 0.0164 0.0000 0.0000 n -Hexane 0.00690 0.1104 0.1997 0.0000 0.0000 2,2,4-TMP 0.00003 0.0015 0.0001 0.0000 0.0000 Comments/Notes: Applicant estimated a number of "PRV (to Flare)" components, which I have grouped with the "Other" equipment type. Applicant specified different compositions for Condensate and NGL (both "light liquids") and so those were calculated separately. As Table 2-4 does not have an emission factor for "Heavy Oil / Pump Seals", I used the Table 2-2 emission factor (for Refineries) with approval of the applicant. Printed 7/11/2018 Page 1 or 1 Separator Venting Emissions Inventory 016 Separator Venting Facility AIRs ID: County 9887 Plant 0 Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Limited Process Parameter AIRtttimS, Veiliekt Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions Requested Permit Limit Throughput events per year Potential to Emit (PTE)Throughput = 120 events per year Secondary Emissions - Combustion Device(s) for Air Pollution Control Separator Gas Heating Value: Volume of waste gas emitted per BBL of liquids throughput: Section 04 - Emissions Factors & Methodologies Description Applicant estimated eosinuPcps"',i Sacred mt eegieeeriog per biowdown anda total S R compres s'. ,'24 •'42 non-site-$peclfic gas seaiysis' Residue gas NAPS are i VOC wt% benzene wt% toluene wt% ethylbenzene wt% xylene wt% n -Hexane wt% 2,2,4-Trimethylpentane wt% MW of gas scf/bbl Inlet Gas Residue Gas 25.4484 0.0091 0.0073 0.0008 0.0020 0.6902 0.0026 22.41885 Number of compressors 3 Slowdown events per year per compr. 24 Gas volume released per event 4200 VOC emissions • Benzene emissions Toluene emissions Ethylbenzene emissions Rylenes emissions n -hexane emissions 2,2,4-TMP emissions 2.276 1.630 1.309 0.152 0.363 123.458 0.471 1.6070 0.0091 0.0073 0.0008 0.0020 0.6902 0.0026 18.5951 No Control Ib/Ibmol 2 24 4200 scf 0.079 tpy 0.902 lb/yr 0.724 lb/yr 0.084 lb/yr 0.200 lb/yr 68.267 lb/yr 0.261 lb/yr Total Number of Events per year 120 Total 2.356 tpy VOC 2.53 lb/yr Benzene 2.03 lb/yr Toluene 0.24 lb/yr Ethylbenzene 0.56 lb/yr Xylenes 191.73 lb/yr n -hexane 0.73 lb/yr 224-TMP Emission Factors Compressor Slowdowns Pollutant Uncontrolled Controlled lb/event lb/event Emission Factor Source VOC 39.2591 39.2591 0.0211 0.0169 0.0020 0.0047 1.5977 0.0061 Benzene 0.0211 Toluene 0.0169 Ethylbenzene 0.0020 xylene 0.0047 n -Hexane 1.5977 224 TMP 0.0061 Engineering calculation Engineering calculation Engineering calculation Engineering calculation Engineering calculation Engineering calculation Engineering calculation Pollutant Primary Control Device Uncontrolled Uncontrolled PM10 PM2.5 SOx NOx CO Emission Factor Source 1 of 4 K:\PA\2018\18W E0444.CP1.xlsm Separator Venting Emissions Inventory Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) PM10 PM2.5 500 NOM VOC CO 236 2.356 2.356 400.12 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene xylene n -Hexane 224 TMP 3 3 3 2 2 2 0 0.2 0.? 1 1 1 192 1.92 192 1 1 1 Section 06 - Regulatory Summary Analysis [Regulation 3, Parts A, B (source requires a permit. (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Using Gas Throughput to Monitor Compliance Does the company use site specific emission factors based on a gas sample to estimate emissions? If no, the permit will contain an "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. Are facility -wide permitted emissions of VOC greater than or equal to 90 tons per year? _„f< If yes, the permit will contain: -An "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. -A "Periodic Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application on an annual basis. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling - Section 08 Technical Analysis Notes Section 09- Inventory SCC Coding and Emissions Factors AIRS Point # 016 Process # SCC Code 01 306004002 - blowdown system without control Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/event PM2.5 0.00 0 lb/event 5Ox 0.00 0 lb/event NOx 0.00 0 lb/event VOC 39259.12 0 lb/event CO 0.00 0 lb/event Benzene 21.10 0 lb/event Toluene 16.94 0 lb/event Ethylbenzene 1.96 0 lb/event Xylene 4.69 0 lb/event n-Hexarm 1597.71 0 lb/event 224 TMP 6.10 0 lb/event . 2 of 4 K:\PA\2018\ 18WE0444.CP1.xlsm Separator Venting Emissions Inventory 016 Separator Venting 'Facility AIRS ID: 123 9F07 , 017 , Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions Requested Permit Limit Throughput ; 2'.13! MMscf/yr Potential to Emit (PTE) Throughput = ' 2.19 events per year Secondary Emissions - Combustion Device(s) for Air Pollution Control Separator Gas Heating Value: Volume of waste gas emitted per BBL o liquids throughput: Section 04 - Emissions Factors & Methodologies VOC wt% benzene wt% toluene wt% ethylbenzene wt% xylene wt% n -Hexane wt% 2,2,4-Trimethylpentane wt% MW of gas Btu/scf cf/bbl engineering estima flee inle₹ gas" and' 35 the fldet 005, 25.4484 0.0091 0.0073 0.0008 0.0020 0.6902 0.0026 22.41885 Number of compressors 3 Leak rate per compressor 50 Gas volume released per year 1314000 VOC emissions Benzene emissions Toluene emissions Ethylbenzene emissions Xylenes emissions n -hexane emissions 2,2,4-TMP emissions 9.890 7.084 5.686 0.659 1.575 536.455 2.048 1.6070 0.0091 0.0073 0.0008 0.0020 0.6902 0.0026 18.5951 No Control Ib/Ibmol 2 50 scf/hr 876000 scf 0.345 ipy 3.917 lb/yr 3.144 lb/yr 0.364 lb/yr 0.871 lb/yr 296.639 lb/yr 1.132 lb/yr Totals 2.19 MMscf/yr 10.235 tpy VOC 11.00 lb/yr Benzene 8.83 lb/yr Toluene 1.02 lb/yr Ethylbenzene 2.45 lb/yr Xylenes 833.09 lb/yr n -hexane 3.18 lb/yr 224-TMP Emission Factors Compressor Blowdowns Pollutant Uncontrolled Controlled Ib/MMscf Ib/MMscf Emission Factor Source VOC 9347.4097 9347.4097 Benzene Toluene 5.0236 4.0322 0.4672 1.1172 5.0236 4.0322 0.4672 1.1172 Ethylbenzene Xylene n -Hexane 224 TMP 380.4082 380.4082 1.4519 1.4519 Engineering calculation Engineering calculation Engineering calculation Engineering calculation Engineering calculation Engineering calculation Engineering calculation Pollutant Primary Control Device Uncontrolled Uncontrolled Emission Factor Source PM10 PM2.5 SOx NOx CO 0.186 3 of 4 K:\PA\2018\18W E0444.CP1.xlsm Separator Venting Emissions Inventory Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (Ibs/month) PM10 PM2.5 SOx NOx VOC CO 10.24 10.24 10.24 1738.62 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 11 11 11 9 9 9 1 1 1 2 2 2 833 833 833 3 3 3 Section 06 - Regulator/ Summary Analysis [Regulation 3, Parts A, B - 'Source requires a permit. (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Using Gas Throughput to Monitor Compliance Does the company use site specific emission factors based on a gas sample to estimate emissions? If no, the permit will contain an "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. Are facility -wide permitted emissions of VOC greater than or equal to 90 tons per year? aTt3 If yes, the permit will contain: - -An "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. -A "Periodic Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application on an annual basis. Will the operator have a meter installed and operational upon startup of this point? Yes If no, the permit will contain a condition that requires the operator to calculate gas throughput using the liquid throughput until the meter is installed and operational (not to exceed 180 days). This condition will use the"Volume of waste gas emitted per BBL of liquids throughput" (scf/bbl) value in section 03. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis N Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 017 Process # SCC Code 01 31000309 - Oil & Gas Production, Natural Gas Processing, Compressor Seals Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 Ib/MMscf PM2.5 0.00 0 Ib/MMscf 5Ox 0.00 0 Ib/MMscf NOx 0.00 0 Ib/MMscf VOC 9347.41 0 Ib/MMscf CO 0,00 0 lb/MMscf Benzene 5.02 0 Ib/MMscf Toluene 4.03 0 Ib/MMscf Ethylbenzene 0.47 0 Ib/MMscf Xylene 1.12 0 Ib/MMscf n -Hexane 300.41 0 Ib/MMscf 224 TMP 1.45 0 Ib/MMscf 4 of 4 K:\PA\2018\18WE0444.CP1.xlsm COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION FACILITY EMISSION SUMMARY Company Name County AIRS ID Plant AIRS ID Facility Name Taproot Rockies Midstream 123 9FB7 Radicle Gas Plant History File Edit Date Ozone Status 5/9/2018 Non -Attainment EMISSIONS - Uncontrolled (tons per year) EMISSIONS With Controls (tons per year) POINT AIRS ID PERMIT Description PM10 PM2.5 H2S S02 NOx VOC Fug VOC CO Total HAPs PM10 PM2.5 H2S SO2 NOx VOC Fug VOC CO Total HAPs REMARKS Previous FACILITY TOTAL 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 New Facility - No Previous Total Previous Permitted Facility total 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 001 18W50444 Cat G3516J, sn: TBD 0.4 0.4 0.0 6.5 14.0 37.2 6.4 0.4 0.4 0.0 6.5 6.4 13.7 1.3 "Inlet Compressor 1" 002 18WE0444 Cat 03516J, sn: TED 0.4 0.4 0.0 6.5 14.0 37.2 6.4 0.4 0.4 0.0 6.5 6.4 13.7 1.3 "Inlet Compressor 2" 003 18WE0444 Cat 03516J, en: TBD 0.4 0.4 0.0 6.5 14.0 37.2 6.4 0.4 0.4 0.0 6.5 6.4 13.7 1.3 "Inlet Compressor 3" 004 18WE0444 Cat 03516J, sn: TBD 0.5 0.5 0.0 6.5 14.0 37.2 6.4 0.5 0.5 0.0 6.5 6.4 13.7 1.3 "Residue Compressor 4" 005 18WE0444 Cat CG137-12, sn: TBD 0.4 0.4 0.0 43.0 1.3 72.3 0.6 0.4 0.4 0.0 2.9 1.3 11.6 0.6 "Residue Compressor 5" 006 18WE0444 MDEA Amine Sweetening 58.5 1.5 2.9 0.1 "Rental Amine" 007 1 ₹WE4444 _ TEu Behv N..ii 7.4 4.0 0.4 "R6oti I TEc" 008 18WE0456.XP 6.0 MMBtu/hr heater for amine unit 0.2 0.2 0.0 2.6 0.1 2.2 0.0 0.2 0.2 0.0 2.6 0.1 2.2 0.0 XP due to less than 10 MMBttdhr 009 18WE0444 Hot Oil Heater- 12.0 MMelu/hr 0.4 0.4 0.0 1.5 0.3 4.3 0.1 0.4 0.4 0.0 1.5 4.3 0.3 0.1 "Hot Oil Heater A" 010 18WE0444 Thermal oxidizer 0.17 0.12 0.01 3.06 0.45 6.11 0.15 0.17 0.12 0.01 3.06 0.45 6.11 0.1 "Phase 120 MMSCFD Flare" 011 18WE0444 One 500 -bbl gunbarrel process lank 20.72 2.4 1.04 0.1 "Gunbarrel" 012 18WE0444 Two 400 -bbl condensate tanks 19.85 2.3 1.0 0.1 "Condensate" 013 18WE0444 NGL loadout to pressurized trucks 1.6 0.2 1.6 0.0 "NGL Loadout" 014 18WE0444 Truck loadout from condensate, slop, and produced water tanks 48.8 0.8 2.4 0.0 "Condensate Loadout" 015 18WE0444 Fugitive component leaks 129.2 14.8 26.0 2.6 016 18WE0444 Compressor.blowdowns 2.4 0.1 2.4 0.1 "CB" 017 18WE0444 Compressor rod packing leaks 10.2 0.4 10.2 0.4 "RP" APEN-Exempt / Insignificants Reboiler for dehy 0.2 0.0 0.2 0.0 0.2 0.0 0.2 0.0 Slop storage tank 0.3 0.0 0.3 .0.0 Produced water lank 0.3 0.0 0.3 0.0 MSS Slowdowns 0.2 0.0 0.2 0,0 0.0 0.0 FACILITY TOTAL 2.8 2.8 0.0 0.2 76.4 311.6 129.2 233.7 57.1 2.8 2.8 0.0 0.2 36.4 58.7 26.0 75.1 10.1 VOC: Syn Minor (NANSR and OP) NOx: Minor (NANSR and OP) CO: Syn Minor (OP), Minor (PSD) HAPS: Syn Minor HCHO, n -hexane, and total HH: Syn Minors affected Area ZZZZ: Syn Minor Permitted Facility Total 2.6 2.6 0.0 0.2 73.6 310.7 129.2 231.4 56.9 2.6 2.6 0.0 0.2 33.6 57.8 26.0 72.7 9.9 Excludes units exempt from permits/APENs (A) Change in Permitted Emissions. 2.6 2.6 0.0 0.2 33.6 57.8 26.0 72.7 Pubcom required based on new syn minor limits. Modeling not required. Note 1 Total VOC Facility Emissions (point and fugitive (A) Change in Total Permitted VOC emissions (poin and fegi inn) 84.7 Facility is eligible for GPO2 because 0 90 tpy Project emissions Tess than 25/50 ipy 83.8 This represents "Phase 1" of the facility design, which is a 'temporary" scenario until permitting is complete for "Phase. 2". Most recent revision received June 2018. Note 2 Page 1 of 3 Printed 7/11/2018 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY - HAPs Company Name Taproot Rockies Midstream County AIRS ID 123 Plant AIRS ID 9FB7 Facility Name Radicle Gas Plant Emissions - uncontrolled (lbs per year) POINT PERMIT Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n -Hexane McOH 224 TMP H2$ ''su1etl1a TOTAL (tpy) Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 18WE0444 Cat G3516J, sn: TBD 10950.2 813.4 500.1 42.8 39.7 3.9 17.9 108 243.2 24.3 26 6.4 002 18WE0444 Cat G3516J, sn: TBD 10950.2 813.4 500.1 42.8 39.7 3.9 17.9 108 243.2 24.3 26 6.4 003 18WE0444 Cat G3516J, sn: TBD 10950.2 813.4 500.1 42.8 39.7 3.9 17.9 108 243.2 24.3 26 6.4 004 18WE0444 Cat G3516J, sn: TBD 10950.2 813.4 500.1 42.8 39.7 3.9 17.9 108 243.2 24.3 26 6.4 005 18WE0444 Cat CG137-12, sn: TBD 797.3 108.5 102.3 61.5 21.7 1 7.6 0 119 0 25,8 0.6 006 18WE0444 MDEA Amine Sweetening 497 360 22 64 2115 0 1.5 007 18WE0444 TEG Dehy 745 680 73 214 14117 4 7.9 008 18WE0456.XP 6.0 MMBtu/hr heater for amine unit 4 0.1 0.2 93 0.0 009 18WE0444 Hot Oil Heater - 12.0 MMBtu/hr 8 0.2 0.4 186 0.1 010 18WE0444 Thermal oxidizer 294.5 0.1 011 18WE0444 One 500 -bbl gunbarrel process tank 275 150 12 24 4412 1 2.4 012 18WE0444 Two 400 -bbl condensate1tanks 263 144 12 23 4228 1 2.3 013 18WE0444 NGL loadout to pressurized trucks 4 10 3 9 363 5 0.2 014 18WE0444 Truck loadout from condensate, slop, and produced water tanks 169 1488 0.8 015 18WE0444 Fugitive component leaks 502 1096 320 838 26471 314 14.8 016 18WE0444 Compressor blowdowns 3 2 1 192 1 0.1 017 18WE0444 Compressor rod packing leaks 11 9 1 2 833 3 0.4 APEN-Exempt / Insignificants Reboiler for dehy 8 0.0 Slop storage tank 4 2 62 0.0 Produced water tank 4 2 62 0.0 MSS Blowdowns 0.0 TOTAL,tpy) 22.3 1.7 1.1 1.4 1.3 0.2 0.6 27.7 0.5 0.2 0.Q 0.1 57.1 `Total Reportable = all HAPs where uncontrolled emissions > de minimus values Red Text: uncontrolled emissions < de minimus 2 1239FB7.xlsx 7/11/2018 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY - HAPs Company Name Taproot Rockies Midstream County AIRS ID 123 Plant AIRS ID 9FB7 Facility Name Radicle Gas Plant Emissions with controls (Ibs per year POINT PERMIT Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n -Hexane McOH 224 TMP H2S ''a"' '° TOTAL (tpy) Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 18WE0444 Cat G3516J, sn: TBD 782.2 813.4 500.1 42.8 39.7 3.9 17.9 108 243.2 24.3 26 1.3 002 18WE0444 Cat G3516J, sn: TBD 782.2 813.4 500.1 42.8 39.7 3.9 17.9 108 243.2 24.3 26 1.3 003 18WE0444 Cat G3516J, sn: TBD 782.2 813.4 500.1 42.8 39.7 3.9 17.9 108 243.2 24.3 26 1.3 004 18WE0444 Cat G3516J, sn: TBD 782.2 813.4 500.1 42.8 39.7 3.9 17.9 108 243.2 24.3 26 1.3 005 18WE0444 Cat CG137-12, sn: TBD 797.3 108.5 102.3 61.5 21.7 1 7.6 0 119 0 25.8 0.6 006 18WE0444 MDEA Amine Sweetening 25 18 1 3 106 0 0.1 007 18WE0444 TEG Dehy 37 34 4 11 706 0 0.4 008 18WE0456.XP 6.0 MMBtu/hr heater for amine unit 4 0.1 0.2 93 0.0 009 18WE0444 Hot Oil Heater - 12.0 MMBtu/hr 8 0.2 0.4 186 0.1 010 18WE0444 Thermal oxidizer 1 1 294.5 0.1 011 18WE0444 One 500 -bbl gunbarrel process tank 14 7 1 1 221 0.1 012 18WE0444 Two 400 -bbl condensate tanks 13 7 1 1 211 0.1 013 18WE0444 NGL loadout to pressurized trucks 0.0 014 18WE0444 Truck loadout from condensate, slop, and produced water tanks 8 74 0.0 015 18WE0444 Fugitive component leaks 83 183 54 143 4637 56 2.6 016 18WE0444 Compressor blowdowns 3 2 1 192 1 0.1 017 18WE0444 Compressor rod packing leaks 11 9 1 2 833 3 — 0.4 APEN-Exempt / Insignificants Reboiler for dehy 8 0.0 Slop storage tank 4 2 62 0.0 Produced water tank 4 2 62 0.0 MSS Blowdowns 0.0 TOTAL,tpy) 2.0 1.7 1.1 0.2 0.2 0.0 0.1 4.1 0.5 0.1 0.0 0.1 10.1 3 1239FB7.xlsx 7/11/2018 CONSTRUCTION PERMIT Permit number: Date issued: Issued to: 18WE0444 Issuance: 1 Taproot Rockies Midstream Facility Name: Radicle Gas Plant Plant AIRS ID: 123/9FB7 Physical Location: Section 11, T8N R61 W County: Weld County General Natural Gas Processing Plant Description: Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description Inlet Compressor 1 001 One (1) Caterpillar, Model G3516J, Serial Number To Be Determined, natural gas - fired, naturally aspirated, 4SLB reciprocating internal combustion engine, site rated at 1350 horsepower. This emission unit is used for inlet compression. Oxidation catalyst and air -fuel ratio control Inlet Compressor 2 002 One (1) Caterpillar, Model G3516J, Serial Number To Be Determined, natural gas - fired, naturally aspirated, 4SLB reciprocating internal combustion engine, site rated at 1350 horsepower. This emission unit is used for inlet compression. Oxidation catalyst and air -fuel ratio control Inlet Compressor 3 003 One (1) Caterpillar, Model G3516J, Serial Number To Be Determined, natural gas - fired, naturally aspirated, 4SLB reciprocating internal combustion engine, site rated at 1350 horsepower. This emission unit is used for inlet compression. Oxidation catalyst and air -fuel ratio control Residue Compressor 4 004 One (1) Caterpillar, Model G3516J, Serial Number To Be Determined, natural gas- fired, naturally aspirated, 4SLB reciprocating internal combustion engine, Oxidation catalyst and air -fuel ratio control COLORADO AirPo€lutiari Control Division Page 1 of 35 Facility Equipment ID AIRS Point Equipment Description Emissions Control Description : r. ,-d at I h• - sower. Ti - ission unit is used for residue compression. Residue Compressor 5 005 One (1) Caterpillar, Model CG137-12, Serial Number To Be Determined, natural gas - fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 600 horsepower. This emission unit is used for residue compression. Three-way catalyst and air -fuel ratio control Rental Amine 006 One (1) Methyldiethanolamine (MDEA) natural gas sweetening system for acid gas removal with a design capacity of 20 MMSCF per day (make, model, serial number: TBD). This emissions unit is equipped with one (1) amine recirculation pump (make/model TBD) with a total design capacity of 60 gallons per minute. This system includes a natural gas/amine contactor, a flash tank, and a natural gas fired amine regeneration reboiler. All emissions are routed to AIRS point 010 (thermal oxidizer). Still Vent and Flash Tank: Thermal Oxidizer (Point 010) Rental TEG 007 One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: TBD, Model: TBD, Serial Number: TBD) with a design capacity of 20 MMscf per day. This emissions unit is equipped with an electric driven glycol pump (Make, Model, Quantity: TBD) with a design capacity of 4 gallons per minute. This dehydration unit is equipped with a still vent, condenser, flash tank, and reboiler burner. Still Vent: routed to air-cooled condenser and then to Thermal Oxidizer (Point 010). Flash Tank: routed to Thermal Oxidizer (Point 010). Hot Oil Heater A 009 One (1) natural gas heater (Make: Fulton, Model: 12005-LF, Serial Number: TBD) with a design heat input rate of 12.0 MMBtu/hr. This emissions unit is a hot oil heater for the stabilizer reboiler, MRU reboiler, and inlet flash heater. None TO 010 One (1) thermal oxidizer to control vapors from the amine vents (Point 006), TEG dehydrator vents (Point 007), storage tanks (Points 011 and 012), and loadout of storage tanks (Point 014). Thermal Oxidizer Gunbarrel 011 One (1) 500 -barrel fixed roof gunbarrel storage vessel for the storage of condensate. Thermal Oxidizer (Point 010) ICOLORADO Air Poilntion Control Division ,'.)-'J&[E'X'.•°[ Lit PubrC HC£d°.^.1 E'tiUhYJ'tCt;C Page 2 of 35 Facility Equipment ID AIRS Point Equipment Description Emissions Control Description Condensate 00- roof st. -` °= essels used to store stabilized condensate. Thermal Oxidizer (Point 010) NGL Loadout 013 Loadout of natural gas liquids from a pressurized line to pressurized storage in trucks. None Condensate Loadout 014 Truck loadout of condensate by submerged fill using vapor balance system. Thermal Oxidizer (Point 010) Fugitive Emissions 015 Equipment leaks (fugitive VOCs) from a natural gas processing plant. LDAR per 40 CFR Part 60, Subpart 0000a Phase I CB 016 Compressor blowdowns, from a total of five (5) compressors. None Phase I RP 017 Leaking of gas from compressor rod packing, from a total of five (5) compressors. None Points 001, 002, 003 and 004: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar G3516J engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. Point 005: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar CG137-12 engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1 YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self- certification. (Regulation Number 3, Part B, Section III.G.2. ) COLORADO Air Pollution Corttrol Division 7 'Oepgrtme ct ,t i i-ef'dth v E r n rrrtent Page 3 of 35 3. of the s rce for which this permit was issued: or op- ° tion of this source within 18 months uancconstructiopermit or the date on which such ion acti` w,' sched -d t• ommence - set forth in the permit application ociated w is 1 ,' ii) '1 .n mu- "" construc i 'or a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit: • Points 001, 002, 003, 004: o Manufacture date; construction date; order date; date of relocation into Colorado; serial number • Point 005: o Manufacture date; construction date; order date; date of relocation into Colorado; serial number • Point 006: o The amine system manufacturer, model number and serial number o The amine circulation pump manufacturer, model number, serial number, quantity and type (i.e., electric or gas -injection) • Point 007: o The dehydrator manufacturer name, model number and serial number o The glycol circulation pump manufacturer name, model number and quantity • Point 009: o Heater serial number • Point 010: o The thermal oxidizer make, model, and serial number This information shall be included with the Notice of Startup submitted for the equipment. (Regulation Number 3, Part B, III.E.) 6. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) COLORADO Air Pollution Control Division .Depa,tment of PubWu3 :?'. s Esvrror,rnem Page 4 of 35 Facility Equipment ID AIRS Point Pounds per Month Emission PM2.5 NO„ V0C CO Type Inlet Compressor 1 001 --- 1,108 1,086 2,326 Point Inlet Compressor 2 002 --- 1,108 1,086 2,326 Point Inlet Compressor 3 003 --- 1,108 1,086 2,326 Point Residue Compressor 4 004 --- 1,108 1,086 2,326 Point Residue Compressor 5 005 --- 493 227 1,969 Point Rental Amine 006 --- --- 498 --- Point Rental TEG 007 --- --- 771 --- Point Hot Oil Heater A 009 --- 261 --- 736 Point TO 010 --- 520 --- 1,038 Point Gunbarrel 011 --- --- 176 --- Point Condensate 012 --- --- 169 --- Point NGL Loadout 013 --- --- 272 --- Point Condensate Loadout 014 --- --- 415 --- Point Fugitive Emissions 015 --- --- 4,419 --- Fugitive Phase I CB 016 --- --- 401 --- Point Phase I RP 017 --- --- 1,739 --- Point Note: Monthly limits are based on a 31 -day month. The owner or operator shall calculate monthly emissions based on the calendar month. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 1,359 pounds per month. Facility -wide emissions of total hazardous air pollutants shall not exceed 3,398 pounds per month. COLORADO Air Pollution Control Division Da.perment of PufbFt Kra..0 l':tiirrn';rRzr,E Page 5 of 35 sions li facility lutants shall apply to all permitted Facility AIRS Tons per Year Emission Equipment ID Point, PM2.5 N0X V0C CO Type Inlet Compressor 1 001 --- 6.52 6.39 13.69 Point Inlet Compressor 2 002 --- 6.52 6.39 13.69 Point Inlet Compressor 3 003 --- 6.52 6.39 13.69 Point Residue Compressor 4 004 --- 6.52 6.39 13.69 Point Residue Compressor 5 005 --- 2.90 1.34 11.59 Point Rental Amine 006 --- --- 2.93 --- Point Rental TEG 007 --- --- 4.54 --- Point Hot Oil Heater A 009 --- 1.54 --- 4.33 Point TO 010 --- 3.06 --- 6.11 Point Gunbarrel 011 --- --- 1.04 --- Point Condensate 012 --- --- 1.00 --- Point NGL Loadout 013 --- --- 1.60 --- Point Condensate Loadout 014 --- --- 2.44 --- Point Fugitive Emissions 015 --- --- 26.01 --- Fugitive Phase I CB 016 --- --- 2.36 --- Point Phase I RP 017 --- --- 10.24 --- Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. COLORADO Air Pollution Control Division Defratment Public Health & evbsrmet t Page 6 of 35 llutants shall apply to all permitted on, complie with both the monthly and annual lim .F= _. s welve ( uµT. nths of operation, compliance with only the annual limitation is required. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 8. Point 006: Compliance with the emission limits in this permit shall be demonstrated by running the ProMax model on a monthly basis using the actual facility configuration and the most recent amine unit inlet extended gas analysis and recorded operational values (including gas throughput, lean amine recirculation rate, and any other operational values required to run the model). Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into ProMax. 9. Point 007: Compliance with the emission limits in this permit shall be demonstrated by running the GRI-GLYCaIc model version 4.0 or higher on a monthly basis using the most recent extended wet gas analysis and recorded operational values, including: dry gas throughput, lean glycol recirculation rate, flash tank temperature and pressure, wet gas inlet temperature, and wet gas inlet pressure. Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into the model and be provided to the Division upon request 10. Point 015: The owner or operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas and liquids analysis, as required in the Compliance Testing and Sampling section of this permit. The owner or operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. 11. Points 016 and 017: The owner or operator shall calculate actual emissions from these emissions points based on the site -specific inlet gas and residue gas analyses required in the "Initial Testing Requirements" of the Compliance Testing and Sampling section of this permit. These records shall be provided to the Division upon request. 12. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled Inlet Compressor 1 001 Oxidation catalyst and air/fuel ratio controller VOC, CO, HCHO Inlet Compressor 2 002 Oxidation catalyst and air/fuel ratio controller VOC, CO, HCHO Inlet Compressor 3 003 Oxidation catalyst and air/fuel ratio controller VOC, CO, HCHO Residue Compressor 4 004 Oxidation catalyst and air/fuel ratio controller VOC, CO, HCHO `COLORADO Air Pollution Control Division °k[€rtmelt of P.itl t Ete�:;nfa Cna$or.rrte tt Page 7 of 35 Facility Equipment ID AIRS Point Control Device Pollutants Controlled sid.;�•-- Compressor 5 . talyst . ' /fuel ratio controller NOx CO ' Rental Amine 006 Still vent and flash tank: Thermal Oxidizer (AIRS Point 010) VOC, HAPs Rental TEG 007 Still vent and flash tank:+Thermal Oxidizer (AIRS Point 010) VOC, HAPs TO 010 Thermal Oxidizer VOC, HAPs Gunbarrel 011 Thermal Oxidizer (AIRS Point 010) VOC, HAPs Condensate 012 Thermal Oxidizer (AIRS Point 010) VOC, HAPs Condensate Loadout 014 Thermal Oxidizer (AIRS Point 010) VOC, HAPs Fugitive Emissions 015 LDAR per 40 CFR Part 60, Subpart 0000a VOC, HAPs PROCESS LIMITATIONS AND RECORDS 13. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Monthly Limit (31 days) Inlet Compressor 1 001 Consumption of natural gas as a fuel 89.34 MMscf 7.59 MMscf Inlet Compressor 2 002 Consumption of natural gas as a fuel 89.34 MMscf 7.59 MMscf Inlet Compressor 3 003 Consumption of natural gas as a fuel 89.34 MMscf 7.59 MMscf Residue Compressor 4 004 Consumption of natural gas as a fuel 89.34 MMscf 7.59 MMscf Residue Compressor 5 005 Consumption of natural gas as a fuel 35.72 MMscf 3.04 MMscf Rental Amine 006 Natural gas throughput 7,300 MMscf 620 MMscf Rental TEG 007 Dry Gas throughput 7,300 MMscf 620 MMscf ICOLORADO Aix Pollution Control Division Deptotme:tur liar€e Health &Emir rrnent Page 8 of 35 Facility Equipment ID AIRS Point Process Parameter .Annual Limit Monthly Limit (31 days) Oil eater ....��.< Con pti l of _: atu =�• el54 MMscf 8.20 MMscf TO 010 Gas sent to thermal oxidizer 163.6 MMscf 13.9 MMscf Gunbarrel 011 Condensate throughput 369,526 barrels 31,385 barrels Condensate 012 Condensate throughput 369,526 barrels 31,385 barrels NGL Loadout 013 Liquids loaded 3,419,320 barrels 290,408 barrels Condensate Loadout 014 Liquids loaded 413,262 barrels 35,099 barrels Phase I CB 016 Blowdown event 120 events 11 events Phase I RP 017 Total gas volume released 2.19 MMscf 0.186 MMscf Points 001, 002, 003, 004, and 005: Fuel consumption shall be measured by one of the following methods: individual engine fuel meter; facility -wide fuel meter attributed to fuel consumption rating and hours of operation; or manufacturer -provided fuel consumption rate. Point 006: The volume of dry gas throughput shall be measured by gas meter or by assuming the maximum design rate of the amine sweetening unit of 20 MMscf/day. Point 007: The volume of dry gas throughput shall be measured by gas meter at the outlet of the dehydrator or by assuming the maximum design rate of the dehydrator unit of 20 MMscf/day. Point 010: The volume of gas sent to the thermal oxidizer shall be measured by gas meter. The owner or operator shall monitor monthly process rates based on the calendar month. During the first twelve (12) months of operation, compliance with both the monthly and annual throughput limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 14. Point 006: This unit shall be limited to the maximum lean amine recirculation pump rate of 60 gallons per minute. The lean amine recirculation rate shall be recorded weekly in a log maintained on site and made available to the Division for inspection upon request. A flow meter or pump stroke correlation may be used to demonstrate compliance with this condition. (Reference: Regulation No. 3, Part B, II.A.4) 15. Point 007: This unit shall be limited to the maximum lean glycol circulation rate of 4 gallons per minute. The lean glycol recirculation rate shall be recorded weekly in a log maintained on site and made available to the Division for inspection upon request. Glycol recirculation rate shall be monitored by one of the following methods: assuming maximum design pump rate, using 'COLORADO } Air Pollution Control Division f Pub€1.c E:.:virZifir3 ent Page 9 of 35 inute a converting to circulation rate. This compl ce with the optimal glycol circulation ence: Reg tion Number 3, Part B, II.A.4) 16. 7: sis, r opera . - ll monitor and record operational values required to run the GRI-GLYCaIc model including: flash tank temperature and pressure, wet gas inlet temperature and pressure. These records shall be maintained for a period of five years. 17. Point 010: The owner or operator shall continuously monitor and record the volumetric flow of gas sent to this point using a flow meter. The owner or operator shall use these flow meter records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 18. Points 001, 002, 003, 004, 005, 006, 007, 009, 010, 011, 012, 013, 014, and 017: The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/9FB7/xx() shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 19. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Regulation Number 1, Section II.A.1. & 4.) 20. No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Regulation Number 1, Section II.A.5.) 21. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 22. Points 001, 002, 003 and 004: This equipment is subject to the control requirements for stationary and portable engines in the 8 -hour ozone control area under Regulation No. 7, Section XVI.B.2. For lean burn reciprocating internal combustion engines, an oxidation catalyst shall be required. 23. Point 005: This equipment is subject to the control requirements for stationary and portable engines in the 8 -hour ozone control area under Regulation No. 7, Section XVI.B.1. For rich burn reciprocating internal combustion engines, a non -selective catalyst reduction system and an air fuel controller shall be required. 24. Point 006: The inlet gas temperature and inlet gas pressure of the inlet stream to this amine sweetening system shall be measured and recorded weekly. 25. Points 006, 007, 010, 011 and 012: The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.B.2. General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. This flare must be equipped with an operational auto -igniter according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device. 26. Point 007: This source is subject to Regulation Number 7, Section XII.H. The operator shall comply with all applicable requirements of Section XII and, specifically, shall: 1COLORADO Air Pollution Control Division uepo 'Y;Yit of PaAt Hetkih &&t Page 10 of 35 ng and emission control requirements ctual ` lssi•rs4 of volatile ganic compounds from the still vent and con (GCG - ;.tor (flash separator or flash tank), if present, shall be reduced by at least 90 percent on a rolling twelve-month basis through the use of a condenser or air pollution control equipment. (Regulation Number 7, Section XII.H.1.) 27. Point 007: The glycol dehydration unit covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.D.3. Beginning May 1, 2015, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas -processing plant subject to control requirements pursuant to Section XVII.D.4., shall reduce uncontrolled actual emissions of hydrocarbons by at least 95% on a rolling twelve-month basis through the use of a condenser or air pollution control equipment. 28. Point 007: The glycol dehydration unit at this facility is subject to National Emissions Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities, Subpart HH. This facility shall be subject to applicable area source provisions of this regulation, as stated in 40 C.F.R Part 63, Subpart A and HH. (Regulation Number 8, Part E, Subpart A and HH) MACT HH Applicable Requirements Area Source: Benzene Emissions Exemption §63.764 (e)(1) - The owner or operator is exempt from the requirements of paragraph (d) of this section if the criteria listed in paragraph (e)(1)(i) or (ii) of this section are §63.764 - met, except that the records of the determination of these criteria must be maintained General as required in §63.774(d)(1). Standards §63.764 (e)(1)(ii) - The actual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere are less than 0.90 megagram per year, as determined by the procedures specified in §63.772(b)(2) of this subpart. §63.772(b) - Determination of glycol dehydration unit flowrate or benzene emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate or benzene emissions to meet the criteria for an exemption from control requirements under §63.764(e)(1). §63.772(b)(2) - The determination of actual average benzene emissions from a glycol dehydration unit shall be made using the procedures of either paragraph (b)(2)(i) or (b)(2)(ii) of this section. Emissions shall be determined either uncontrolled, or with §63.772 - Test federally enforceable controls in place. Methods, §63.772(b)(2)(i) - The owner or operator shall determine actual average benzene Compliance emissions using the model GRI-GLYCalc TM, Version 3.0 or higher, and the procedures Procedures presented in the associated GRI-GLYCalc TM Technical Reference Manual. Inputs to the and model shall be representative of actual operating conditions of the glycol dehydration Compliance unit and may be determined using the procedures documented in the Gas Research Demonstration Institute (GRI) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI-95/0368.1); or $63.772(b)(2)(ii) - The owner or- operator shall determine an average mass rate of benzene emissions in kilograms per hour through direct measurement using the methods in §63.772(a)(1)(i) or (ii), or an alternative method according to §63.7(f). Annual emissions in kilograms per year shall be determined by multiplying the mass rate by the number of hours the unit is operated per year. This result shall be converted to megagrams per year. COLORADO IAir Pollution Control Division Page 11 of 35 §63.7 Reco Re §6 (1) - An or ope • f a glyc ex p criteria 64(e)( 1 • §63.76 spee• parag ph (d y)(i) o .ragraph (d) for at g ' • l de dratio`y nit. ehydration unit that meets the )(1)(ii) shall maintain the records (ii) of this section, as appropriate, §63.774 (d)(1)(ii) - The actual average benzene emissions (in terms of benzene emissions per year) as determined in accordance with §63.772(b)(2). 29. Point 009: This source is subject to the New Source Performance Standards requirements of Regulation No. 6, Part A Subpart Dc, Standards of Performance for Small Industrial -Commercial - Institutional Steam Generating Units including, but not limited to, the following: a) The owner or operator of the facility shall record and maintain records of the amount of fuel combusted during each month (40 CFR Part 60.48c(g)). b) Monthly records of fuel combusted required under the previous condition shall be maintained by the owner or operator of the facility for a period of two years following the date of such record (40 CFR Part 60.48c(i)). In addition, the following requirements of Regulation No. 6, Part A, Subpart A, General Provisions, apply. c) At all times, including periods of start-up, shutdown, and malfunction, the facility and control equipment shall, to the extent practicable, be maintained and operated in a manner consistent with good air pollution control practices for minimizing emissions. Determination of whether or not acceptable operating and maintenance procedures are being used will be based on information available to the Division, which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. (Reference: Regulation No. 6, Part A. General Provisions from 40 CFR 60.11 d) No article, machine, equipment or process shall be used to conceal an emission which would otherwise constitute a violation of an applicable standard. Such concealment includes, but is not limited to, the use of gaseous diluents to achieve compliance with an opacity standard or with a standard which is based on the concentration of a pollutant in the gases discharged to the atmosphere. (5 60.12) e) Written notification of construction and initial startup dates shall be submitted to the Division as required under S 60.7. f) Records of startups, shutdowns, and malfunctions shall be maintained, as required under § 60.7. 30. Points 011 and 012: The storage tanks covered by this permit are subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall install and operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons except where the combustion device has been authorized by permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation Number 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two years, made available to the Division upon request. This control requirement must be met within 90 days of the date that the storage tank commences operation. 31. Point 013: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.D.2): a. The owner or operator shall inpect onsite loading equipment to ensure that hoses, couplings, and valves are maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. COLORADO I Aix Pollution Control Division Rt€ i E' �rtar,rtt�*r Page 12 of 35 (includ thief hatches) shall be closed and ations not active, except for periods of rsonnel an E' quipment. 32. loading_. __ . = tions, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. 33. Point 014: This source is located in an ozone non -attainment or attainment -maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill and emissions shall be controlled by a flare. (Reference: Regulation 3, Part B, III.D.2) 34. Point 014: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.D.2): a. The owner or operator shall inspect onsite loading equipment to ensure that hoses, couplings, and valves are maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. b. 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. c. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. d. Inspect pressure relief devices (PRD) annually for proper operation and replace 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. e. Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. 35. Point 014: For this controlled loading operation, the owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.D.2): a. Install and operate the vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks. b. Include devices to prevent the release of vapor from vapor recovery hoses when not in use. c. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. d. Operate all recovery and disposal equipment at a back -pressure less than the pressure relief valve setting of transport vehicles. 36. Point 015: This source is subject to Regulation Number 7, Section XII.G (State only enforceable). For fugitive VOC emissions from leaking equipment, the leak detection and repair (LDAR) program as provided at 40 CFR Part 60, Subpart 0000a (July 1, 2017) applies. 37. Point 017: This source is subject to Regulation Number 7, Section XII.J.2., for reciprocating compressor sources in the ozone non -attainment area. This includes requirements for rod packing replacement and recordkeeping. OPERATING £t MAINTENANCE REQUIREMENTS 38. Points 001, 002, 003, 004, 005, 006, 007, 010, 011, 012, and 014: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (0EM) COLORADO Air Pollution Control Division pert.T.ent of Public kiets€;h.0 E;;vronrnent Page 13 of 35 in order to demonstrate compliance evisions to the O&M plan are subject umber 3, Part B, Section III.G.7.) COM Initial Testing Requirements 39. Point 006: The owner or operator shall complete an initial inlet sour gas analysis within one hundred and eighty days (180) after commencement of operation or issuance of this permit, whichever comes later, and use that analysis to calculate actual emission rates from this source as prescribed in the Emission Limitation and Records section of this permit to verify initial compliance with emission limits. The owner or operator shall submit the results to the Division as part of the self -certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 40. Point 006: A source initial compliance test shall be conducted on emissions point 006 to measure the emission rates for the pollutants listed below in order to demonstrate compliance with emission limits in this permit. The amine recirculation rate and gas throughput during the test shall be recorded. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Volatile Organic Compounds using EPA approved methods. Hazardous Air Pollutants using EPA approved methods. 41. Point 007: The owner or operator shall complete an initial extended wet gas analysis within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify initial compliance with the emission limits. The owner or operator shall submit the analysis and the emission calculation results to the Division as part of the self -certification process. (Reference: Regulation Number 3, Part B, Section III.E.) 42. Point 009: A source initial compliance test shall be conducted on emissions point 009 to measure the emission rates for the pollutants listed below in order to demonstrate compliance with emission limits in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. 43. Point 010: The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.16. 44. Point 011: The owner or operator shall complete site specific sampling including a compositional analysis of the pre -flash pressurized condensate routed to these storage tanks and, if necessary for emission factor development, a sales oil analysis to determine RVP and API gravity. Testing !COLORADO I Air Pollution Control Division epsrtInt ,t of P fAo. }4eui:' i Environment Page 14 of 35 mo 05-01. Results of testing shall be and Hazardous Air Pollutants using esultf site.ecific sam.'; g and analysis shall be submitted to self c- ficatn and used demonstrate compliance with the e fissions fa "hosen o is e ° i si.n ..i t. 45. Point 012: The owner or operator shall complete site specific sampling including a compositional analysis of the pre -flash pressurized condensate routed to these storage tanks and, if necessary for emission factor development, a sates oil analysis to determine RVP and API gravity. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine site -specific emissions factors for VOC and Hazardous Air Pollutants using Division approved methods. Results of site -specific sampling and analysis shall be submitted to the Division as part of the self -certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 46. Point 013: The owner or operator shall complete an initial site specific extended liquids analysis ("Analysis") within one hundred and eighty days (180) after commencement of operation or issuance of this permit, whichever comes later, of the hydrocarbon liquids loaded out from this emissions unit ("NGL Loadout") in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n -hexane, 2,2,4-trimethylpentane, and methanol content (weight fraction). Results of the Analysis, along with actual as -built geometric dimensions of the loadout equipment, shall be used to calculate site -specific emission factors for the pollutants referenced in this permit (in units of lb/bbl loaded) using the methods from the permit application. Results of the Analysis shalt be submitted to the Division as part of the self -certification and must demonstrate the emissions factors established through the Analysis for VOC and reportable non criteria air pollutants are less than or equal to the emissions factors submitted with the permit application and established herein in the "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this Analysis is greater than the emissions factors submitted with the permit application and established in the "Notes to Permit Holder" the operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this/these inaccuracy(ies). A request for a permit modification need not be submitted if the only pollutants for which the site -specific emission factor exceeds the permit application emission factor are non -criteria reportable air pollutants below the APEN reportable threshold. 47. Point 015: Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, the owner or operator shall complete the initial extended gas analysis of gas samples and extended natural gas liquids analysis that are representative of volatile organic compound (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas and NGL liquids analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. The operator shall submit the results of the gas and NGL liquids analysis and emissions calculations to the Division as part of the self -certification process to ensure compliance with emissions limits. 48. Point 015: Within one hundred and eight days (180) of the latter of commencement of operation or issuance of this permit, the operator shall complete a hard count of components at the facility and establish the number of components that are operated in "heavy oil service", "light oil (NGL) service", "tight oil (condensate) service", "water/oil service", and "gas service". The operator shall submit the results to the Division as part of the self -certification process to ensure compliance with emissions limits. 49. Points 016 and 017: The owner/operator shall complete an initial site specific extended gas analysis ("Analysis") within one hundred and eighty days (180) after commencement of operation or issuance of this permit, whichever comes later, of the "inlet gas" and the "residue gas" vented from these emissions units in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n -hexane, and 2,2,4-trimethylpentane content (weight fraction) of these emission streams. Results of the Analysis shall be used to calculate site -specific emission factors for the 'COLORADO 1 1# Pollution Control Division J gt:rti-tr. :t of 7c i&z.Oeitth&tzrrrnr»lepit Page 15 of 35 /blowdn event for Point 016, and lb/MMSCF ed met ;•s. Results of the Analysis shall be -certificatio and must demonstrate the emissions table ` ed t s u h e Anal s areq ss than or e alto the emissions factors submitted wi the per i . ppli : `' nd -s . is e erein i e "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this Analysis is greater than the emissions factors submitted with the permit application and established in the "Notes to Permit Holder" the operator shall submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this/these inaccuracy(ies). Periodic Testing Requirements 50. Points 001, 002, 003, 004, and 005: This engine is subject to the periodic testing requirements as specified in the operating and maintenance (OEtM) plan as approved by the Division. Revisions to your O&M Plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. 51. Point 006: The owner or operator shall complete an extended sour gas analysis prior to the inlet of the amine unit on an annual basis. Results of the sour gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per this permit. 52. Point 006: The owner or operator shall sample the inlet gas to the amine unit on an annual basis to determine the concentration of hydrogen sulfide (H2S) in the gas stream. The sample results shall be monitored to demonstrate that this amine unit qualifies for the less than 2 long tons per day of hydrogen sulfide in the acid gas exemption from the Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification, or Reconstruction Commenced After September 18, 2015: 40 CFR 560.5365a(g)(3). (NSPS OOOOa) 53. Point 007: The owner or operator shall complete an extended wet gas analysis prior to the inlet of the dehydration unit on an annual basis. Results of the wet gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per this permit and be provided to the Division upon request. 54. Point 015: On an annual basis, the owner or operator shall complete an extended gas analysis of gas samples and an extended natural gas liquids analysis of "light oil (NGL)" liquids that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. Extended liquids analysis of condensate, heavy liquid, and water/oil is not required for this periodic testing. This extended gas and NGL liquids analysis shall be used in the compliance demonstration as required in the Emissions Limits and Records section of this permit. ADDITIONAL REQUIREMENTS 55. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of VOC or NO. per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or OLORADO itPollution Control Division Ne£u'h s E :rrrnrvnrertr Page 16 of 35 the "u iss lnc ease b 0% ox 've (5) tons r year, whichever is less, above the eve :x teast ed to t .- s-sion. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires; or • Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shalt include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine. 56. MACT Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of that Subpart on the date as stated in the rule as published in the Federal Register. (Reference: Regulation No. 8, Part E) 57. Federal regulatory programs (i.e. PSD or NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS 58. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 59. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 60. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information andwith representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. COLORADO Air Pollution Control Division Depvtr ,4 t Pu£tife P§_ 3 "t ff YEYi1'r3nmerlt Page 17 of 35 61. mess s• ifill ed oth ^ ; the g- .nd spec ;'ic conditions contained in this permit re compliance with the provisions of S. 62. d ethis matenhereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 63. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 64. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Andy Gruel, P.E. Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Taproot Rockies Midstream. COLORADO Air Pollution Control Division Page 18 of 35 ssing ti ffr- for this permit. An invoice for these it is i "' ed. T '' permit hole "-r shall pay the invoice within 30 days of t 3•,: =-.rc.,. t, ,f- e t• -_voice -rt!= „ult in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (tb/yr) Controlled Emissions (lb/yr) 001, 002, 003, and 004 each Formaldehyde 50000 10,950 782 Acetaldehyde 75070 813 813 Acrolein 107028 500 500 Methanol 67561 243 243 n -Hexane 110543 108 108 Benzene 71432 43 43 Toluene 108883 40 40 005 Formaldehyde 50000 798 798 Acetaldehyde 75070 109 109 Acrolein 107028 102 102 Methanol 67561 119 119 Benzene 71432 62 62 Toluene 108883 22 22 006 Benzene 71432 497 25 Toluene 108883 361 18 Ethylbenzene 100414 22 1 Xylenes 1330207 64 3 n -Hexane 110543 2116 106 COLORADO Air Pollution Control Division JL'D%.sr'i',lent Fubit_ H, th v EYVir �rr.Irr,[ Page 19 of 35 AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 4 Trime y pen ane .lsy__ 1 1 007 Benzene 71432 745 37 Toluene 108883 680 34 Ethylbenzene 100414 73 4 Xylenes 1330207 214 11 n -Hexane 110543 14117 706 2,2,4- Trimethylpentane 540841 4 1 009 Formaldehyde 50000 8 8 Benzene 71432 0.2 0.2 Toluene 108883 0.4 0.4 n -Hexane 110543 186 186 010 Benzene 71432 0.3 0.3 Toluene 108883 0.6 0.6 n -Hexane 110543 294.5 294.5 011 Benzene 71432 275 14 Toluene 108883 150 7 Ethylbenzene 100414 12 1 Xylenes 1330207 24 1 n -Hexane 110543 4412 221 2,2,4- Trimethylpentane 540841 1 1 012 Benzene 71432 263 13 Toluene 108883 144 7 Ethylbenzene 100414 12 1 Xylenes 1330207 23 1 n -Hexane 110543 4228 211 2,2,4- Trimethylpentane 540841 1 1 013 Benzene 71432 4 4 Toluene 108883 10 10 Ethylbenzene 100414 3 3 Xylenes 1330207 9 9 n -Hexane 110543 363 363 COLORADO Air Pollution Control Division Opzrcretur Vii=Heave 'v E,,:.nr)nrnert Page 20 of 35 AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) Trime pen ane 5 5 Methanol 67561 Initial Testing Required 014 Benzene 71432 K 169 8 n -Hexane 110543 1488 74 015 Benzene 71432 4 502 83 Toluene 108883 1,096 183 Ethylbenzene 100414 320 54 Xylenes 1330207 838 143 n -Hexane 110543 26,471 4,637 2,2,4- Trimethylpentane 540841 314 56 016 Benzene 71432 3 3 Toluene 108883 2 2 Ethylbenzene 100414 0.2 0.2 Xylenes 1330207 1 1 n -Hexane 110543 192 192 2,2,4- Trimethylpentane 540841 1 1 017 Benzene 71432 11 11 Toluene 108883 9 9 Ethylbenzene 100414 1 1 Xylenes 1330207 3 3 n -Hexane 110543 833 833 2,2,4- Trimethylpentane 540841 3 3 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Points 001, 002, 003, and 004: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Factors lb/MMBtu - Controlled g/bhp-hr NOx 0.1340 0.50 0.1340 0.50 CO 0.7637 2.85 0.2814 1.05 VOC 0.2867 1.07 0.1313 0.49 COLORADO Air Pollution Control Division Page 21 of 35 ant ;35 ... 1 t .,,„..,.., MEI 75070 cetal•e y•e 107028 Emission Factors - Controlled lb/MMBtu g/bhp-hr 0.0080 0.03 0.0084 0.03 Acrolein 0.0051 0.02 0.0051 0.02 67561 Methanol 0.0025 0.01 0.0025 0.01 110543 n -Hexane 0.0011 0.00 0.0011 0.00 71432 Benzene 0.0004 0.00 0.0004 0.00 108883 Toluene 0.0004 0.00 0.0004 0.00 Emission factors are based on a Brake -Specific Fuel Consumption Factor of 8227 Btu/hp-hr, a site -rated horsepower value of 1350, and a fuel heat value of 1089 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx EMIT spec sheet. No control for NOx. CO EMIT spec sheet. EMIT spec sheet specifies a 97.2% reduction in CO, but I accept the applicant's requested reduction of 63.2%. VOC Applicant requested. EMIT spec sheet has uncontrolled VOC at 0.65 g/hp-hr, so I accepted the more conservative 1.07 g/hp-hr. EMIT spec sheet specifies 0.46 gihp-hr; I accepted the applicant's requested rate of 0.49 g/hp-hr. 50000 Formaldehyde EMIT spec sheet. EMIT spec sheet. 75070 Acetaldehyde AP 42; Table 3.2 2 (7/2000); Natural Gas No Control 107028 Acrolein AP 42; Table 3.2 2 (7/2000); Natural Gas No Control 67561 Methanol AP -42; Table 3.2-2 (7/2000); Natural Gas No Control 110543 n -Hexane AP 42; Table 3.2 2 (7/2000); Natural Gas No Control 71432 Benzene AP 42; Table 3.2 2 (7/2000); Natural Gas No Control 108883 Toluene AP 42; Table 3.2 2 (7/2000); Natural Gas No Control Point 005: CAS Pollutant Emission Uncontrolled Ib/MMBtu Factors - g/bhp-hr Emission Factors lb/MMBtu - Controlled g/bhp-hr NOx 2.21 7.42 0.1490 0.5 CO 3.72 12.5 0.5958 2.0 VOC 0.0685 0.23 0.0685 0.23 50000 Formaldehyde 0.0205 0.0688 0.0205 0.0688 75070 Acetaldehyde 0.0028 0.0094 0.0028 0.0094 107028 Acrolein 0.0026 0.0088 0.0026 0.0088 67561 Methanol 0.0031 0.0103 0.0031 0.0103 71432 Benzene 0.0016 0.0053 0.0016 0.0053 108883 Toluene 0.0006 0.0019 0.0006 0.0019 Emission factors are based on a Brake -Specific Fuel Consumption Factor of 7400 Btu/hp-hr, a site -rated horsepower value of 600, and a fuel heat value of 1089 Btu/scf. !COLORADO 1 Air Pollution Control Division os Est %ter lvA I ;n v Efmm : um Page 22 of 35 ct. • -''S: nt CO P-4 ; a • le (7/2001 , Natural Gas Controlled EF Source Manufacturer's spec sheet. Manufacturer's spec sheet. VOC Manufacturer's spec sheet. No Control 50000 Formaldehyde Acetaldehyde Acrolein 75070 107028 67561 Methanol 110543 n -Hexane 71432 Benzene 108883 Toluene AP -42; Table 3.2-3 (7/2000); Natural Gas No Control No Control No Control No Control No Control No Control No Control Point 006: The emission levels contained in this permit are based on a ProMax simulation using a typical (non - site -specific) facility inlet gas analysis. CAS # Pollutant Emission Factors Uncontrolled lb/MMscf Natural Gas Throughput Emission Factors Controlled lb/MMscf Natural Gas Throughput Source VOC 16.03 0.80150 ProMax simulation based on a non -site - specific inlet specific gas sample. 71432 Benzene 0.06807 0.00340 108883 Toluene 0.04937 0.00247 100414 Ethylbenzene 0.00297 0.00015 1330207 Xylene 0.00873 0.00044 110543 n -Hexane 0.28978 0.01449 540841 2,2,4-Trimethylpentane 0.00005 0.000003 Note: The controlled emissions factors are based on the thermal oxidizer control efficiency of 95%. NOx, CO and SOx emissions are accounted for in Point 010. Point 007: The emission levels contained in this permit are based on information provided in the application and the GRI-GLYCalc 4.0 model. The permit requires a monthly calculation of actual emissions based on actual operating parameters and the most recent extended wet gas analysis. Controlled emissions are based on the thermal oxidizer (Point 010) control efficiency of 95%. Point 009: CAS # Pollutant Uncontrolled Emission Factors (lb/MMscf) Source NOx 31.737 Manufacturer's Spec Sheet CO 89.683 AP -42 Chapter 1.4, Tables 1.4-1, 1.4-2, and 1.4-3 VOC 5.,872 PMip 8.114 SO2 0.6406 110543 n -Hexane 1.9218 Emission factors for point 009 are based on a design heat rate of 12.0 MMBtu/hr, 8760 hours of operation per year, and fuel heat value of 1089 Btu/scf. COLORADO Air Pollution Control Division .�t htti�i�W �-,e�.P e GtviY�nr3tcxrtt Page 23 of 35 Point This p• `t contr. em l s from th ` auks . s [vents the glycol dehydrator unit (Point 007) a amine eel �ing Fit (Po, 006 :nd al the vapors •m the storage tanks (Points 011 and 012 an exe •t sl• an Nand pro ced Ater tank) a &the vapors from truck loadout (Point 014 a : `a PEN -ex - p loa•ou • slop ��,ti_a " oduced . = ank). VOC and HAPs emissions from those point are accounted for at those points; this Point 010 accounts only for the combustion emissions associated with control of those points. Total actual combustion emissions at Point 010 are based on the following overall emission factors: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Waste Gas Combusted Source PM10 2.0189 AP -42 Table 1.4-2 PM2.5 1.5142 AP -42 Table 1.4-2 SOx 0.1594 AP -42 Table 1.4-2 NOx 37.3918 TNRCC Flare Emissions Guidance CO 74.6481 VOC 5.5 AP -42 Table 1.4-2 71432 Benzene 0.0021 AP -42 Table 1.4-3 108883 Toluene 0.0034 110543 n -Hexane 1.80 Note: The overall emission factors listed above are a proportional blend of the emission factors from pilot gas, assist gas, and the waste gas vapors. Control device operates 8760 hours/year. Gas volumes and assumed heat content are listed below: Pilot Burner: 20 scf/hr, heat value 1089 Btu/scf. Assist gas: 1010 scf/hr, heat value 1089 Btu/scf. Amine flash: 750 scf/hr, heat value 1188.98 Btu/scf (from ProMax model). Amine regen: 15272 scf/hr, heat value 9.21852 Btu/scf (from ProMax model). Dehy flash: 1420 scf/hr, heat value 1700 (volume from GLYCaIc; assumed typical heat value). Dehy regen: 83 scf/hr, heat value 280 (volume from GLYCaIc; assumed typical heat value). Gunbarrel tank:25 scf/hr, heat value 3926.99 Btu/scf (from EEtP TANKS) Condensate tanks: 24 scf/hr, heat value 3926.99 Btu/scf (from EEtP TANKS) Slop tank: 7 scf/hr, heat value 3928.18 Btu/scf (from EEtP TANKS) Produced water tank: 7 scf/hr, heat value 3926.99 Btu/scf (from E&P TANKS) Condensate loadout: 50 scf/hr, heat value 3926.99 Btu/scf (Eng. Calc) Slop/PW loadout: 6 scf/hr, heat value 3928.18 Btu/scf (Eng. Calc) Combining all of these inputs and heat values results in a total heat input of 44324.87 MMBtu/yr, and total flow rate of 163.59 MMscf/yr. Point 011: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 0.121 0.0056 EEtP Tanks with an assumed incoming 71432 Benzene 0.0007 0.00004 108883 Toluene 0.0004 0.00002 100414 Ethylbenzene 0.00003 0.000002 COLORADO Air Pollution Control. Division Page 24 of 35 30207 110543 540841 n -Hexane 2,2,4- Trimethylpentane U. oiled Controlled E ssi n Emission F •. ; ors Factors 1•; bl lb/bbl x..1.1 1.1 0.000003 0.0119 0.0006 0.000004 0.0000002 Source • liquid composition Note: The controlled emissions factors for this point are based on the thermal oxidizer (AIRS Point 010) control efficiency of 95%. NOx, CO, and PM emissions are accounted for under Point 010. Point 012: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 0.107 0.005373 EEtP Tanks with an assumed incoming liquid composition 71432 Benzene 0.0007 0.000036 108883 Toluene 0.0004 0.000019 100414 Ethylbenzene 0.00003 0.000002 1330207 Xylene 0.0001 0.000003 110543 n -Hexane 0.0114 0.000572 540841 2,2,4- Trimethylpentane 0.000004 0.0000002 Note: The controlled emissions factors for this point are based on the thermal oxidizer (AIRS Point 010) control efficiency of 95%. NOx, CO, and PM emissions are accounted for under Point 010. Point 013: Pollutant CAS # Uncontrolled Emission Factors (lb/bbl loaded) Controlled Emission Factors lb/truck loaded Source VOC 0.000936 N/A Not Controlled Engineering Calculation Benzene 71432 0.000001 Toluene 108883 0.000003 Ethylbenzene 100414 0.000001 Xylene 1330207 0.000003 n -Hexane 110543 0.000106 2,2,4- Trimethylpentane 5.40841 0.000001 Methanol 67561 Not Measured - Initial Testing Required The uncontrolled VOC and HAPs emission factors were calculated using weight fractions (assumed from a sample from a similar gas plant) of VOC and HAPs, multiplied by the assumed geometric dimensions of the load lines and assumed liquid/vapor properties as follows: Load Line Assumed Connection Diameter 0.167 ft Assumed Length Between Valves 25 ft Number of hoses 2 Liquid temperature 115 F Liquid molecular weight 57.48425 lb/lbmol Vapor pressure at liquid temp. 20.28 psia Vapor density 0.189 lb/ft3 COLORADO it Pollution Control Division Page 25 of 35 Pollutant CAS # . ncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 0.236 0.0118 CDPHE Default for Condensate Loadout Benzene 71432 0.00041 0.000021 n -Hexane 110543 0.00360 0.000180 The state default uncontrolled emission factors for VOC, benzene, and n -hexane were used. NOx and CO emissions are accounted for at Point 010 (Thermal Oxidizer.) Controlled emission factors are based on a control efficiency of 95% and a collection efficiency of 100%. Point 015: Component Gas Service Heavy Oil Light Oil (NGL) Light Oil (Condensate) Water/Oil Service Connectors 7500 1171 9465 404 0 Flanges 959 335 1437 230 0 Open-ended Lines 1 0 318 0 0 Pump Seals 0 21 4 9 0 Valves 1244 107 2886 235 0 Other* 36 0 69 6 0 VOC Content (wt. fraction) 0.2545 1.0 0.9725 1.0 1.0 Benzene Content (wt. fraction) 9,1E-05 0 0.00126 0.01413 0 Toluene Content (wt. fraction) 7.3E-05 0 0.00310 0.02793 0 Ethylbenzene (wt. fraction) 8,5E-06 0 0.00099 0.00725 0 Xylenes Content (wt. fraction) 2,0E-05 0 0.00281 0.01641 0 n -hexane Content (wt. fraction) 6.9E-03 0 0.11038 0.19972 0 2,2,4- Trimethylpentane content (wt. frac.) 2.6E-05 0 0.00154 0.00014 0 *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents Uncontrolled Emission Factors (kg/hr-component): Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 .... 0.021 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 COLORADO I Air .Pollution Control Division t)e& mer t of Pubti F et h & Envirowne.r t Page 26 of 35 benzenewt% 0.0091 toluene wet%; 0.0073 ethylbenzene wt% 0.0008 xylene wt.6' 0.0020 n -Hexane wt% 0.6902 2,24-Trirnethylpentanewt%' 0.0026 KW of gas 22.41885 COLORADO Air Pollution Control Division Dep;s nent r hobt Component Gas ' Service Heavy Oil Light Oil Water/Oil Service er .8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA -453/R95-017 Table 2-4, except "Heavy Oil / Pump Seals", where Table 2-2 was used. Controlled emission factors are based on required monthly LDAR monitoring per NSPS 0000a. Controlled emissions factors (kg/hr-component): Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 1.62E-04 7.5E-06 1.70E-04 8.91E-05 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 0.021 1.14E-02 2.4E-05 Valves 4.32E-03 8.4E-06 2.38E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Compliance with emissions limits in this permit will be demonstrated by using the controlled emission factors listed in the table above with the most recent representative component count, multiplied by the VOC content from the most recent gas and liquids analyses. Point 016: CAS # Pollutant Uncontrolled Emission Factors (lb / blowdown event) Source VOC 39.2591 Engineering calculation (see below) 71432 Benzene 0.0211 108883 Toluene 0.0169 100414 Ethylbenzene 0.0020 1330207 Xylenes 0.0047 110543 n -Hexane 1.5977 540841 2,2,4- Trimethylpentane 0.0061 Emission factors are calculated as follows: There are a total of five (5) compressors on site, with three (3) holding "inlet gas" and two (2) holding "residue gas", with different VOC and HAP concentrations in each gas type. VOC content was assumed from a non -site -specific gas analysis. HAP concentrations in residue gas were conservatively assumed to be the same as the inlet gas. Assumed concentrations are listed below: Inlet Gas Residue Gas VOC wt%I 25.4484 1.6070 0.0091 0.0073 _...._.... 0.0008 0.0020 0.6902 .............. 0.0025.. 18.5951 Ib/Ibmol Page 27 of 35 wn eves per year at each compressor, with scf/ -nt. = ltiplying th "s eight % listed above by the gas ompre yr ty. and dividin the molar volume of gas (379 -mol) ehe • . ` issio `"' r aollutant:"a result is divided by the total number of events (120 per year) to arrive at the lb/event emission factors listed above. Point 017: CAS # Pollutant Uncontrolled Emission Factors (lb / MMscf) Source VOC 9347.4097 Engineering calculation (see below) 71432 Benzene 5.0236 108883 Toluene 4.0322 100414 Ethylbenzene 0.4672 1330207 Xylenes 1.1172 110543 n -Hexane 380.4082 540841 2'2'4 Trimethylpentane 1.4519 Emission factors are calculated as follows: Assuming emissions of 50 scf/hr/compressor; with five (5) compressors running for 8760 hr/yr this is 2.19 MMscf/yr. There are a total of five (5) compressors on site, with three (3) holding "inlet gas" and two (2) holding "residue gas", with different VOC and HAP concentrations in each gas type. VOC content was assumed from a non -site -specific gas analysis. HAP concentrations in residue gas were conservatively assumed to be the same as the inlet gas. Multiplying the weight % by the gas volume released from each compressor type, and dividing by the molar volume of gas (379 cf/lb-mol) equals the total emissions for that pollutant. That result is divided by the total gas vented (2.19 MMscf/yr) to arrive at the lb/MMscf emission factors listed above. Assumed concentrations are listed below: VOC wt% benzene wt% toluene wt% ethylbenzene wt% xylene wt% n -Hexane wt% 2,2,4-Trimethylpentane wt% MW of gas Inlet Gas Residue Gas 25.4484 0.0091 0.0073 0.0008 0.0020 0.6902 0.0026 22.41885 1.6070 ...................... 0.0091 0.0073 0.0008 0.0020 .................. 0.6902 0.0026 ................. 18.5951 lb/lbrnal 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) Points 001, 002, 003, 004, and 005: This engine is subject to 40 CFR, Part 60, Subpart JJJJ— Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting - effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the COLORADO Air Pollution Control. Division Page 28 of 35 Co htt 8) Po 3 s 001 „ 2, 3, _ 05 s en a is subject 40 CFR, Part 63, Subpart ZZZZ - llutant '<-ciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ja08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html 9) Points 007, 011, and 012: This permit fulfills the requirement to hold a valid permit reflecting the glycol dehydration unit, storage tanks, and associated control devices per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 10) Points 006 and 015: Fugitive equipment leaks and amine sweetening unit are affected facilities subject to 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 (See June 3, 2016 Federal Register posting - effective August 2, 2016.) This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available at the Office of the Federal Register website at: https: / /www.federalregister.gov/documents/2016/06/03/2016-11971 /oil -and -natural -gas - sector -emission -standards -for -new -reconstructed -and -modified -sources 11) This facility is classified as follows: Applicable Requirement Synthetic Minor Source of: VOC, CO, HAPs (formaldehyde, n -hexane, and total) Operating Permit NANSR Synthetic Minor Source of: VOC MACT HH Area Source Requirements: Applicable MACT ZZZZ Area Source Requirements: Applicable NSPS 0000a Applicable 12) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP COLORADO Air Pollution Control Division Page 29 of 35 CT 6 . /&1�� K17 bpart Subpart p C :/36$O 83 \ $prt Z -S bat M . : . 63 -E \ : \ter ± N - S ., XXX ICOLORADO Air ..Pollution Control. Division > »ate H a Page 30 of 35 October 12, 2012 2. Alternative Operating Scenarios NARIOS ION ENGINES The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shalt be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with an engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. COLORADO .Air Pollution Control Division tticyr of Public P(et:ith & EYwir rsrnent Page 31 of 35 2.1.2T a existi same ithout perms t repl me en ' e co lies all • mil limitati to the, xis ,` engi " as l a any n ap able requi Meas from e p emi of n .. ,,.,.. _�,�� - "rmament e •i emission limitations shall be made as set forth in section 2.2. engine with another engine with the odifying this permit so long as the s and other requirements applicable ents for the replacement engine. nd compliance with the applicable An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at https://www.colorado.gov/pacific/cdphe/alternate-operating-scenario-aos- reporting-forms. This submittal shall be accompanied by a certification from the Responsible Official indicating that "based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at: https://www.colorado.gov/pacific/sites/default/files/AP Portable-Analyzer-Monitoring-Protocol.pdf Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. OLORADO Air Pollution Control Division dP rune tgarlu{ He zh 6 e'ZVRorriett Page 32 of 35 For co concen engine in the h a a i• rm lime is eith 8 t based d (, @ 15% the a in unit is ect , t esult •f the �-st sh•, be convert Lion Port . e A l zer :, iton ' Protocol d /mmBtu), output based (g/hp-hr) or rently subject to or the replacement to the appropriate units as described ment. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B S II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC. and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or 5O2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (5 60.331) and 40 CFR Part 72 (S 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State - Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non -selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. COLORADO Air Pollution Control Division apirttn:t-aPutt�whiath&-,varam�x Page 33 of 35 Emission Standards: Section XVII.E - State -only requirements for the engine and shall be operated p'. i °: ility Re .' " `"equired under Condition 2.1.2. Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 500<Hp July 1, 2007 July 1, 2010 2.0 1.0 4.0 2.0 1.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1 /1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, S 1.6 (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting 'COLORADO Air Pollution Control Division • Oubt e hic[ak~4 v t„air6nr ent Page 34 of 35 requir requir AOS. N Condit 2 '"' appr time a specifies t .ndi 2.4 Additional Sources cluded in the Applicability Reports s in addition to that required by this e testing required by this AOS under at such test is conducted within the The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not- "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. COLORADO Air Pollution Control Division Page 35 of 35 Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www colorado.gov/edphe/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: lewEoH 1 f I 4Y23 2/ 08-1 AIRS ID Number: I 2 3 / ?Fi3}'/ D of [Leave blank unless APCD has already assi,:ied a permit # and AIR'S IDi Section 1 - Administrative Information Company Name': Taproot Rockies Midstream Site Name: Radicle Gas Plant Phase I Site Location: SeCf Sec -4', TON, &ow _.....g Address: (Include Zip Code) 518 17th Street, Suite 1800 Denver, CO 80202 Portable Source Home Base: N/A Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Phone Number: E -Mail Address2: Chris Rial (713) 481-1864 crial@taprootep.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-201 - R:eciprocatinci internal Combustion Engine APEN - Revision 1/2017 Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit f and AIRS ID) Section 2 - Requested Action ❑✓ NEW permit OR newly -reported emission source (check one below) ❑r STATIONARY source 0 PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment 0 Change company name 0 Add point to existing permit 0 Change permit limit 0 Transfer of ownership' ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - APEN submittal for permit-exempt/grandfathered source O Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info a Notes: Phase I Inlet Compressor Engine 1 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. Inlet Compressor 1 General description of equipment and purpose: 1,350 HP Caterpillar G3516J used for inlet compression For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://vvww,colorado.gov/cdphe/attamment) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 1/1/2019 Yes ❑ No hours/day 7 days/week 52 weeks/year Mar -May: June -Aug: Sept -Nov: Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 CE7 LCdftAUU Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit_ A and AIRS ID), Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: ❑r Compression What is the maximum number of hours this engine will be used for emergency back-up power? 0 Engine Make: Caterpillar Engine Model: G3516J Serial Number6: TBD What is the maximum designed horsepower rating? 1,350 hp What is the engine displacement? l/cyl What is the maximum manufacturer's site -rating? hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8,227 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ❑✓ 4 -Stroke Combustion: ❑✓ Lean Burn ❑ Rich Burn Ignition Source: ❑✓ Spark ❑ Compression Aspiration: ❑ Natural ❑ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑ Yes ❑ No If yes, what type of AFRC is in use? ❑ O2 Sensor (mV) ❑NOx Sensor (ppm) ❑ Other: Is this engine equipped with a Low-NOx design? ✓❑ Yes ❑ No Engine Dates: What is the manufactured date of this engine? hours/year What date was this engine ordered? What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes El No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLOrekt�u Permit Number: AIRS ID Number: / / [Leave blank unless ARCS has already assigned a permit P` and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) Lat 40.636229, Lon -104.066899 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. (. F) Flow Rate (ACFM) Velocity (ft/sec) Compressor 1 TBD TBD TBD TBD Indicate the direction of the Stack outlet: (check one) ❑ Downward ❑ Other (describe): ❑✓ Upward ❑ Horizontal Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): ❑ Upward with obstructing raincap TBD Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100% Load (SCF/ hour) Actual Annual Fuel Use (MMSCF/year) Requested Annual Permit Limit7 (MMSCF/ year) 19,140"---10111 93,6- 5I.3`(( From what year is the actual annual amount? Indicate the type of fuel used8: 0 Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) 0 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 Natural Gas Heating Value (give units): 1,089 Btu/scf 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. * cOLO)A5+a Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 4 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑r Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.5 SOX NOX VOC Oxidation Catalyst 54.2 CO Oxidation Catalyst 63.2 Other: Formaldehyde - Oxidation Catalyst 92.9 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? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions 9 Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) 9.91E-03 lb/MMBtu AP -42 0.48 0.48 PM10 7.71E-05 Ib/MM6tu AP -42 0.0037 0.0037 PM2.5 7.71E-05 lb/MMBtu AP -42 0.0037 0.0037 SOX 5.68E-04 lb/MMBtu AP -42 0.028 0.028 NOX 0.50 g/bhp-hr Mfg. 6.52 6.52 VOC 1.07 g/bhp-hr Mfg. 13.95 6.39 CO 2.85 g/bhp-hr Mfg. 37.15 13.69 Does the emissions source have any uncontrolled actual emissions of non -criteria Yes pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: ❑ No Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions' Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds/year) Formaldehyde 50000 ' 0.42 g/bhp-hr Mfg. 10,950.2 782.2 Acetaldehyde 75070 6.36E-03 lb/MMBtu AP -42 8I3,f _31•Kr' 5 I 3. Acrolein 107028 5.14E-03 lb/MMBtu AP -42 _49%2 Se • • I 50.2 • I Benzene 71432 4.40E-04 Ib/MMBtu AP -42 42.56 42.56 Other: 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blan FOORDO Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 • 5 9 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit k and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each ce4diikei of general permit GP02. Signature of Legally Ain d Person (not a vendor or consultant) Colin Moe Date Vice President of Commercial Development Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: / /www. colorado, gov/cdphe/apcd Form APCD-201 = Reciprocating Internet Combustion Engine APEN - Revision 112017 c cotoRAMO 6 I _ 4114nhl ti P9 5/25/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application STATE OF COLORADO Gruel - CDPHE, Andrew <andrew.gruel@state.co.0 RE: Taproot Radicle Gas Plant Phase I Construction Permit Application Fri, May 25, 2018 at 2:12 IM Rebecca Martarella <RMartarella@swca.com> To: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Cc: Brad Sohm <bsohm@swca.com> Hi Andy, We based the fuel use rate on the fuel flow from the specification sheet (169 scfm * 60 min/hr = 10,140 scf/hr). However, we are fine with using the more conservative 10,199 scf/hr based on your calculation. Thank you, Rebecca Martarella Air Quality Specialist SWCA Environmental Consultants Email: rmartarella@swca.com Toll Free 800.828.8517 www.swca.com SWCA From: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Sent: Friday, May 25, 2018 12:59 PM [Quoted text hidden] [Quoted text hidden] https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver=FPvd7wOCULs.en. &cbl=g mail _fe_180508.13_p 10&view=pt&msg=16398ee6b70f6520&search=inbo: 5/25/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application STATE OF COLORADO Gruel - CDPHE, Andrew <andrew.gruel@state.co.us> RE: Taproot Radicle Gas Plant Phase I Construction Permit Application Rebecca Martarella <RMartarella@swca.com> To: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Cc: Brad Sohm <bsohm@swca.com> HI Andy, Thu, May 17, 2018 at 3:37 PM We have attached the specification sheet for the 8516) engines to this email, The fuel use rate for points 001 through 004 will be 169 scfm (10,140 scth). Please let us know if you would like us to update the ADEN forms with this new fuel use rate, or if redlining Is acceptable, In addition, we agree with you redlining the engine APENs with the HAP values. Thank you, Rebecca Martarella Air Quality Specialist SWCA Environmental Consultants Email: rmartarella@swca.com Toll Free 800.828.8517 www.swca.com SWCA From: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Sent: Wednesday, May 9, 2018 2:58 PM To: Rebecca Martarella <RMartarella@swca.com> Cc: Brad Sohm <bsohm@swca.com> Subject: Re: Taproot Radicle Gas Plant Phase I Construction Permit Application [Quoted text hidden] CatG3516J.pdf 174K https://mai l.google.com/m ail/u/0/?u i=2&ik=9030c 1528 b&jsver=FPvd7wOW Ls.e n. &cbl=gmai I_fe_180508.13_p 10&view=pt&msg=163700942c570f0f&search=inbox Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/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. RECET' MAY 23 2018 cl PCT) Permit Number: j gtlJE 0 ` '-{ 9 AIRS ID Number: / Z 3 /qF& 7'/ v 01. [Leave blank unless APCD has already assigned a permit # and AIR` ID] Section 1 - Administrative Information Company Name': Taproot Rockies Midstream Site Name: Radicle Gas Plant Phase I Site Location: S , S-eG4,. (I, <e N, R. ow Mailing Address: (Include Zip Code) 518 17th Street, Suite 1800 Denver, CO 80202 Portable Source Home Base: N/A Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Phone Number: Chris Rial (713) 481-1864 E -Mail Address2• crial@taprootep.com Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. • 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 1 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action El NEW permit OR newly -reported emission source (check one below) ✓❑ STATIONARY source ❑ PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. - OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) - OR • APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Et Notes: Phase I Inlet Compressor Engine 2 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. General description of equipment and purpose: compression Inlet Compressor 2 1,350 HP Caterpillar G3516J used for inlet For existing sources, operation began on: 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/attainrnertl) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 1/1/2019 0 Yes ❑ No hours/day 7 days/week 52 weeks/year Mar -May: June -Aug: Sept -Nov: Form APCD-'01 - Reciprocating Internal Combustion Engine APEN - Revision '! r7017 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit. :ti and AIRS ID] Section 4 - Engine Information Engine O Primary and/or Peaking Function: O Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: ❑✓ Compression What is the maximum number of hours this engine will be used for emergency back-up power? 0 Engine Make: Caterpillar Engine Model: G3516J What is the maximum designed horsepower rating?, 1,350 hp What is the engine displacement? l/cyl What is the maximum manufacturer's site -rating? hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8,227 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ❑✓ 4 -Stroke Combustion: ❑✓ Lean Burn O Rich Burn Ignition Source: 0 Spark ❑ Compression Aspiration: ❑ Natural ❑ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑ Yes O No Serial Number': TBD hours/year If yes, what type of AFRC is in use? O OZ Sensor (mV) ❑NOx Sensor (ppm) Is this engine equipped with a Low-NOx design? ❑r Yes ❑ No Engine Dates: What is the manufactured date of this engine? What date was this engine ordered? ❑ Other: What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Inter na[Engine APEN - Revision !2�0 Combustion 1 r L_. I % �7I rt At)G Permit Number: AIRS ID Number: [Leave blank unless APCD has a!ready assigned a perrnis-;a and A.iRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) Lat 40.636238, Lon -104.066809 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. (.F) Flow Rate (ACFM) Velocity (ft/sec) Compressor 2 TBD TBD TBD TBD Indicate the direction of the Stack outlet: (check one) ❑ Downward 0 Other (describe): ❑✓ Upward O Horizontal Indicate the stack opening and size: (check one) ❑✓ Circular 0 Square/Rectangle 0 Other (describe): Interior stack diameter (inches): ❑ Upward with obstructing raincap TBD Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100% Load (SCF/hour) Actual Annual Fuel Use (MMSCF/year) Requested Annual Permit Limit7 (MMSCF/year) 19).41:r %O('161 8pil eq.34I From what year is the actual annual amount? Indicate the type of fuel used8: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑ Field Natural Gas Heating value: BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf jj Other (describe): Residue Natural Gas Heating Value (give units): 1,089 Btu/scf 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. $ If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a. permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? E1 Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.5 SOX NOx VOC Oxidation Catalyst 54.2 CO Oxidation Catalyst 63.2 Other: Formaldehyde - Oxidation Catalyst 92.9 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? Criteria Pollutant Emissions Inventory Emission Factor Actual Annual Emissions9 Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) 9.91E-03 lb/MMBtu AP -42 0.48 0.48 PM10 7.71E-05 lb/MMBtu AP -42 0.0037 0.0037 PM 2.5 7.71E-05 lb/MMBtu AP -42 0.0037 0.0037 SOX 5.88E-04 lb/MMBtu AP -42 0.028 0.028 NOx 0.50 g/bhp-hr Mfg. 6.52 6.52 VOC 1.07 g/bhp-hr Mfg. 13.95 6.39 CO 2.85 g/bhp-hr Mfg. 37.15 13.69 Does the emissions source have any uncontrolled actual emissions of non -criteria ❑✓ Yes pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: ❑ No Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions9 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds/year) Formaldehyde 50000 0.42 g/bhp-hr Mfg. 10,950.2 782.2 Acetaldehyde 75070 8.36E-03 lb/MMBtu AP -42 916- 613.1 yee: 813.4 Acrolein 107028 5.14E-03 lb/MMBtu AP -42 4,47rf srso .I 4t .2 $ 03 •l Benzene 71432 4.40E-04 lb/MMBtu AP -42 42.56 42.56 Other: i 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Reciprocating internal Combustion Engine APEN - Revision 1/2017 5 I Permit Number: AIRS ID Number: (Leave blank unless APCD has already assigned a permit N and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each conditioafof general permit GP02. Signature of Legally Authorized Person (not a vendor or consultant) Colin Moe Date Vice President of Commercial Development Name (please print) Title Check the appropriate box to request a copy of the: O 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 and the General Permit For more information or assistance call: registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 6 AV COlo 5/25/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application STATE OF COLORADO Gruel - CDPHE, Andrew <andrew.gruel@state.co.0 RE: Taproot Radicle Gas Plant Phase I Construction Permit Application Fri, May 25, 2018 at 2:12 F'M Rebecca Martarella <RMartarella@swca.com> To: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Cc: Brad Sohm <bsohm@swca.com> Hi Andy, We based the fuel use rate on the fuel flow from the specification sheet (169 scfm * 60 min/hr = 10,140 scf/hr). However, we are fine with using the more conservative 10,199 scf/hr based on your calculation. Thank you, Rebecca Martarella Air Quality Specialist SWCA Environmental Consultants Email: rmartarella@swca.com Toll Free 800.828.8517 www.swca.com SWCA From: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Sent: Friday, May 25, 2018 12:59 PM [Quoted text hidden] [Quoted text hidden] https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver—FPvd7uxXULs.en. &cbl=gmail_fe_180508.13_p10&view=pt&msg=16398ee6b70f6520&se rch=inbo: 5/25/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application STATE OF COLORADO Gruel - CDPHE, Andrew <andrew.gruel@state.co.us> RE: Taproot Radicle Gas Plant Phase I Construction Permit Application Rebecca Martarella <RMartarella@swca.com> To: Andy Gruel - CDPHE <andrew.gruel@state.eo.us> Cc: Brad Sohm <bsohm@swca.com> Hi Andy, Thu, May 17, 2018 at 3:37 PM We have attached the specification sheet for the 3516J engines to this email. The fuel use rate for points 001 through 004 will be 169 scfm (10,140 scfh). Please let us know if you would like us to update the APEN forms with this new fuel use rate, or if redlining is acceptable. In addition, we agree with you redlining the engine APENs with the HAP values. Thank you, Rebecca Martarella Air Quality Specialist SWCA Environmental Consultants Email: rmartarella@swca.com Toll Free 800.828.8517 www.swca.com SWCA �M1t\:YE�IA •.tL F�%kt Cl..i+tidy .,7t..`; From: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Sent: Wednesday, May 9, 2018 2:58 PM To: Rebecca Martarella <RMartarella@swca.com> Cc: Brad Sohm <bsohm@swca.com> Subject: Re: Taproot Radicle Gas Plant Phase I Construction Permit Application [Quoted text hidden] CatG3516J.pdf 174K https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver=FPvd7uxXULs.en.&cbl=gmail fe_180508.13_p10&view=pt&msg=163700942c570f0f&search=inbox Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. DECEIVED '23 2018 APeJ Statiopan r "- ,S.01-ii e Permit Number: 101J F 0'-(y t AIRS ID Number: j 23 /1 F Q 7/ o 03 [Leave blank unless APCD has already assig=ned a permit # and AIRS 1D] Section 1 - Administrative Information Company Name': Site Name: Site Location: Mailing Address: (Include Zip Code) Taproot Rockies Midstream Radicle Gas Plant Phase I Site Location ,qactiert— 8N, R60W County: Weld Sect►'". li ?$N &WA) 518 17th Street, Suite 1800 Denver, CO 80202 Portable Source Home Base: N/A NAICS or SIC Code: 213112 Permit Contact: Chris Rial Phone Number: (713) 481-1864 E -Mail Address2• • •crlal@taprootep.com Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. QEF k .A Fora') APCD-201 Reciprocating iritima! Combustion Engine APEN - Revision 1 /20'17 3'4-8613 COI- -IAD() Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit r and :111=;5 ID] Section 2 - Requested Action (] NEW permit OR newly -reported emission source (check one below) ✓❑ STATIONARY source 0 PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Et Notes: Phase I Inlet Compressor Engine 3 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. Inlet Compressor 3 General description of equipment and purpose: 1,350 HP Caterpillar G3516J used for inlet compression For existing sources, operation began on: 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) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 1/1/2019 0 Yes ❑ No hours/day 7 days/week 52 weeks/year Mar -May: June -Aug: Sept -Nov: Form APCD-201 - Reciprocating internal Combustion Engine APEN - Revision 1/2017 2 I LoRAc,C) Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit it: and MRS ID) Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: ❑✓ Compression What is the maximum number of hours this engine will be used for emergency back-up power? 0 Engine Make: Caterpillar Engine Model: G3516J Serial Number6: TBD What is the maximum designed horsepower rating? 1,350 hp What is the engine displacement? What is the maximum manufacturer's site -rating? hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8,227 BTU/hp-hr hours/year l/cyl Engine Features: Cycle Type: ❑ 2 -Stroke ❑✓ 4 -Stroke Combustion: ❑r Lean Burn ❑ Rich Burn Ignition Source: r❑ Spark ❑ Compression Aspiration: ❑ Natural ❑ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑ Yes ❑ No If yes, what type of AFRC is in use? 0 O2 Sensor (mV) ONOx Sensor (ppm) Is this engine equipped with a Low-NOx design? ❑✓ Yes ❑ No Engine Dates: What is the manufactured date of this engine? What date was this engine ordered? ❑ Other: What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes ✓❑ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. r c0L0rrr.pa Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 Permit Number: AIRS ID Number: [Leave blank unless , PCCL has already assi,_ned a permft. and !>.;P._ ID; Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) Lat 40.636231, Lon -104.066740 Operator Stack ID No. Discharge Height Above Ground %e)tLevel Temp. (.F) Flow Rate (ACFM) Velocity (ft/sec) Corn pressor 3 TBD TBD TBD TBD Indicate the direction of the Stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward 0 Other (describe): Indicate the stack opening and size: (check one) ❑r Circular Interior stack diameter (inches): ❑ Square/Rectangle Interior stack diameter (inches): 0 Other (describe): 0 Upward with obstructing raincap TBD Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100% Load (SCF/hour) Actual Annual Fuel Use (MMSCF/year) Requested Annual Permit Limit' (MMSCF/ year) 1 poTto 10 q 88/83 61.3`! ( From what year is the actual annual amount? Indicate the type of fuel used8: ❑ Pipeline Natural Gas ❑ Field Natural Gas ❑ Propane ❑ Landfill Gas ❑✓ Other (describe): (assumed fuel heating value Heating value: (assumed fuel heating value Heating Value: of 1,020 BTU/scf) BTU/scf of 2,300 BTU/scf) BTU /scf Residue Natural Gas Heating Value (give units): 1,089 Btu/scf 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/20'17 4 I Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit and AIRS. ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.5 SOX NOx VOC Oxidation Catalyst 54.2 CO Oxidation Catalyst 63.2 Other: Formaldehyde - Oxidation Catalyst 92.9 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? Criteria Pollutant Emissions Inventory Emission Factor Actual Annual Emissions9 Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) 9.91E-03 lb/MMBtu AP -42 0.48 0.48 PM10 7.71E-05 lb/MMBtu AP -42 0.0037 0.0037 PM2.5 7.71E-05 lb/MMBtu AP -42 0.0037 0.0037 SOX 5.88E-04 lb/MMBtu AP -42 0.028 0.028 NOx 0.50 g/bhp-hr Mfg. 6.52 6.52 VOC 1.07 g/bhp-hr Mfg. 13.95 6.39 CO 2.85 g/bhp-hr Mfg. 37.15 13.69 Does the emissions source have any uncontrolled actual emissions of non -criteria Yes pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: D No Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions9 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds year) Formaldehyde 50000 0.42 g/bhp-hr Mfg. 10,950.2 782.2 Acetaldehyde 75070 8.36E-03 lb/MMBtu AP -42 808.7 808.7 Acrolein 107028 5.14E-03 lb/MMBtu AP -42 497.2 497.2 Benzene 71432 4.40E-04 lb/MMBtu AP -42 42.56 42.56 Other: 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. c0LortAC0 Form APCD-20'I - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 5 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit 17 and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condifkm of general permit GP02. Signature of Legally Auiwhoned Person (not a vendor or consultant) Date Colin Moe Vice President of Commercial Development 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 $152.90 and the General Permit For more information or assistance call: registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692.3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Form APCD-201 Reciprocating Internal Combustion Engine APEN a Revision 1/2017 6 PWIiH ftIA*Fd44 de119 A 5/25/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application STATE OF COLORADO Gruel - CDPHE, Andrew <andrew.gruel@state.co.0 RE: Taproot Radicle Gas Plant Phase I Construction Permit Application Rebecca Martarella <RMartarella@swca.com> To: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Cc: Brad Sohm <bsohm@swca.com> Hi Andy, Fri, May 25, 2018 at 2:12 F M We based the fuel use rate on the fuel flow from the specification sheet (169 scfm * 60 min/hr = 10,140 scf/hr). However, we are fine with using the more conservative 10,199 scf/hr based on your calculation. Thank you, Rebecca Martarella Air Quality Specialist SWCA Environmental Consultants Email: rmartarella@swca.com Toll Free 800.828.8517 www.swca.com SWCA From: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Sent: Friday, May 25, 2018 12:59 PM [Quoted text hidden] [Quoted text hidden] https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver=FPvd7uxXULs.en.&cbl=gmail fe_180508.13_p10&view=pt&msg=16398ee6b70f6520&sealrch=inbo: 5/25/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application STATE OF COLORADO Gruel - CDPHE, Andrew <andrew.gruel@state.co.0 RE: Taproot Radicle Gas Plant Phase I Construction Permit Application Rebecca Martarella <RMartarella@swca.com> To: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Cc: Brad Sohm <bsohm@swca.com> Hi Andy, Thu, May 17, 2018 at 3:37 PM We have attached the specification sheet for the 3516J engines to this email. The fuel use rate for points 001 through 004 will be 169 scfrrm (10,140 scfh). Please let us know if you would like us to update the APEN forms with this new fuel use rate, or if redlining is acceptable. In addition, we agree with you redlining the engine APENs with the HAP values. Thank you, Rebecca Martarella Air Quality Specialist SWCA Environmental Consultants Email: rmartarella@swca.com Toll Free 800.828.8517 www.swca.com SWCA From: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Sent: Wednesday, May 9, 2018 2:58 PM To: Rebecca Martarella <RMartarella@swca.com> Cc: Brad Sohm <bsohm@swca.com> Subject: Re: Taproot Radicle Gas Plant Phase I Construction Permit Application [Quoted text hidden] CatG3516J.pdf 174K https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver=FPvd7uxXULs.en.&cbl=gmail fe_180508.13_p10&view=pt&msg=163700942c570f0f&search=inbox Reciprocating Internal Combustion Engine APEI\T - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/cdphe/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: AIRS ID Number: 004 123 I?F&1-/ [L=ave blank unless APCD has already assigned a permit 2 and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Site Location: Section Taproot Rockies Midstream Radicle Gas Plant S.ecANa.. ►I ,761 , X61 W Mailing Address: (Include Zip Code) 518 17th Street, Suite 1800 Denver, CO 80202 Portable Source Home Base: N/A Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Phone Number: Chris Rial (713) 481-1864 E -Mail Addressz• crial@taprootep.com Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. A4 EY ' Lt;6��iA1,?e'2 FormAPCD-201 - Reciprocating APEN Internal Combustion Engine PEN - Re -vision 1'2017 i 1 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit A and AIRS ID] Section 2 - Requested Action ❑✓ NEW permit OR newly -reported emission source (check one below) ❑r STATIONARY source ❑ PORTABLE source ❑ Request coverage under a Construction Permit O Request coverage under General Permit GPO23 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment ❑ Change company name 0 Add point to existing permit O Change permit limit 0 Transfer of ownership' ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ▪ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info a Notes: Phase I and Phase II - Residue Compressor Engine 4 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. Residue Compressor 4 General description of equipment and purpose: compression 1,350 HP Caterpillar G3516J used for residue For existing sources, operation began on: 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/cdphelatta nment) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 1/1/2019 ❑✓ Yes ❑ No hours/day 7 days/week 52 weeks/year Mar -May: June -Aug: Sept -Nov: Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 2 co L4attppo Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit. # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: ❑✓ Compression What is the maximum number of hours this engine will be used for emergency back-up power? 0 Engine Make: Caterpillar Engine Model: G3516J Serial Number6: TBD hours/year What is the maximum designed horsepower rating? 1,350 hp What is the engine displacement? What is the maximum manufacturer's site -rating? hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8,227 BTU/hp-hr l/cyl Engine Features: Cycle Type: 0 2 -Stroke ❑r 4 -Stroke Combustion: ❑✓ Lean Burn 0 Rich Burn Ignition Source: ❑r Spark ❑ Compression Aspiration: 0 Natural ❑ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes ❑ No If yes, what type of AFRC is in use? El OZ Sensor (mV) ❑NOX Sensor (ppm) Is this engine equipped with a Low-NOx design? ❑r Yes ❑ No Engine Dates: What is the manufactured date of this engine? What date was this engine ordered? ❑ Other: What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. FormAPCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1 /2017 3 eCzt c`i rtADu Permit Number: AIRS ID Number: [Leave blank unless AF ;.D has already assigned a permit h and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) Lat 40.636234, Lon -104.066660 Operator Stack ID No. Discharge Height Above GroundFLevel Temp. (•F) Flow Rate (ACFM) Velocity (ft/sec) Compressor 4 TBD TBD TBD TBD Indicate the direction of the Stack outlet: (check one) ❑ Downward 0 Other (describe): ❑✓ Upward ❑ Horizontal Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 0 Upward with obstructing raincap TBD Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100% Load (SCF/hour) Actual Annual Fuel Use (MMSCF/ year) Requested Annual Permit Limit' (MMSCF/year) 10 40 (o (gel 8 S' . 3'-(1 From what year is the actual annual amount? Indicate the type of fuel useds: ❑ 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 Natural Gas Heating Value (give units): 1,089 Btu/scf 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating internal Combustion Engine APEN - Revision 112017 4 I H-10 COLOnAnO -1 > Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit {" and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.5 SOx NOx VOC Oxidation Catalyst 54.2 CO Oxidation Catalyst 63.2 Other: Formaldehyde- Oxydafion Catalyst 92.9 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? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions9 Requested Annual Permit Emission Limits) Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) 9.91E-03 lb/MMBtu AP -42 0.48 0.48 PM10 7.71E-05 lb/MMBtu AP -42 0.0037 0.0037 PM2,5 7.71E-05 lb/MMBtu AP -42 0.0037 0.0037 SOx 5.88E-04 lb/MMBtu AP -42 0.028 0.028 NOx 0.50 g/bhp-hr Mfg. 6.52 6.52 VOC 1.07 g/bhp-hr Mfg. 13.95 6.39 CO 2.85 g/bhp-hr Mfg. 37.15 13.69 Does the emissions source have any uncontrolled actual emissions of non -criteria 0 Yes pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: ❑ No Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions9 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds/year) Formaldehyde 50000 0.42 g/bhp-hr Mfg. 10,950.2 782.2 Acetaldehyde 75070 8.36E-03 lb/MMBtu AP -42 joas, g 13 -ti )06- 8l3.'A Acrolein 107028 5.14E-03 lb/MMBtu AP -42 4ytJor•, I "4,9r1 _coo. I Benzene 71432 4.40E-04 lb/MMBtu AP -42 42.56 42.56 Other: 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Colo icAeu Form APCD-201 - Reciprocating internal. Combustion Engine APEN -• Revision 1/2017 5 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a Permit A and AIRS ID) Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. if this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each conditi6n of general permit GP02. Signature of Legally Authored Person (not a vendor or consultant) Colin Moe Date Vice President of Commercial Development Name (please print) 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) Title This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 Make check payable to: https: //www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Form APCD-201 = Reciprocating Internal Combustion Engine ADEN s Revision 1/2017 6 AVCOLORADO 6 �P!1!h k fMgPY Wql 5/25/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application STATE OF COLORADO Gruel - CDPHE, Andrew <andrew.gruel@state.co.us> RE: Taproot Radicle Gas Plant Phase I Construction Permit Application Rebecca Martarella <RMartarella@swca.com> To: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Cc: Brad Sohm <bsohm@swca.com> Hi Andy, Fri, May 25, 2018 at 2:12 PM We based the fuel use rate on the fuel flow from the specification sheet (169 scfm * 60 min/hr =10,140 scf/hr). However, we are fine with using the more conservative 10,199 scf/hr based on your calculation. Thank you, Rebecca Martarella Air Quality Specialist SWCA Environmental Consultants Email: rmartarella@swca.com Toll Free 800.828.8517 www.swca.com SWCA From: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Sent: Friday, May 25, 2018 12:59 PM [Quoted text hidden] [Quoted text hidden] https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver—FPvd7uxXULs.en.&cbl=gmail fe_180508.13_p10&view=pt&msg=16398ee6b70f6520&search=inbo: 5/25/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application STATE OF COLORADO Gruel - CDPHE, Andrew <andrew.gruel@state.co.us> RE: Taproot Radicle Gas Plant Phase I Construction Permit Application Rebecca Martarella <RMartarella@swca.com> To: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Cc: Brad Sohm <bsohm@swca.com> Hi Andy, Thu, May 17, 2018 at 3:37 PM We have attached the specification sheet for the 3516i engines to this email. The fuel use rate for points 001 through 004 will be 169 scfm (10,140 scfh). Please let us know if you would like us to update the APEN forms with this new fuel use rate, or if redlining is acceptable. in addition, we agree with you redlining the engine APENs with the HAP values. Thank you, Rebecca Martarella Air Quality Specialist SWCA Environmental Consultants Email: rmartarella@swca.com Toll Free 800.828.8517 www.swca.com SWCA From: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Sent: Wednesday, May 9, 2018 2:58 PM To: Rebecca Martarella <RMartarella@swca.com> Cc: Brad Sohm <bsohm@swca.com> Subject: Re: Taproot Radicle Gas Plant Phase I Construction Permit Application [Quoted text hidden] CatG3516J.pdf 174K https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver=FPvd7wOW Ls.en.8,cbl=g mail_fe_180508.13_p10&view=pt&msg=163700942c570f0f&search=inbox Reciprocating Internal Combustion 1 -C - Engine APEN m Form APCD 2®1 '/r f jg Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 18 tAF o'-('fy AIRS ID Number: I Z 3 I/ F8 7 f °°5 Section 1 - Administrative Information Company Name: Site Name: Site Location: Sectio , OW County: Weld Taproot Rockies Midstream Radicle Gas Plant Phase I Sew.., II �TBN, R GI Mailindress: (Include Zip Code) 518 17th Street, Suite 1800 Denver, CO 80202 Portable Source Home Base: N/A Site Location NAICS or SIC Code: 213112 Permit Contact: Phone Number: Chris Rial (713) 481-1864 E -Mail Address2: crial@taprootep.com Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. &PF,k7 414,(..4.(4.v" Permit Number: AIRS ID Number: / / Section 2 - Requested Action ✓❑ NEW permit OR newly -reported emission source (check one below) J STATIONARY source ❑ PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) - OR ▪ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Et Notes: Phase I Rental Residue Compressor 5 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. General description of equipment and purpose: compression Residue Compressor 5 Rental 600 HP Caterpillar CG137-12 used for residue For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.gov/cdphe/attainment) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 1/1/2019 ❑ Yes ❑ No. hours/day 7 days/week 52 weeks/year Mar -May: June -Aug: Sept -Nov: 2 j 1. Permit Number: AIRS ID Number: Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump 0 Water Pump 0 Emergency Back-up ❑ Other: E Compression What is the maximum number of hours this engine will be used for emergency back-up power? 0 Engine Make: Caterpillar Engine Model: CG137-12 What is the maximum designed horsepower rating? 600 hp What is the engine displacement? 1/cyl What is the maximum manufacturer's site -rating? hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,400 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke E 4 -Stroke Combustion: ❑ Lean Burn Rich Burn Ignition Source: ❑✓ Spark ❑ Compression Aspiration: ❑ Natural p Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? p Yes ❑ No If yes, what type of AFRC is in use? ❑ O2 Sensor (mV) ONOx Sensor (ppm) ❑ Other: Is this engine equipped with a Low-NOx design? ❑✓ Yes ❑ No Engine Dates: What is the manufactured date of this engine? Serial Number': TBD hours/year What date was this engine ordered? What is the date this engine was first located to Colorado? What is the date this engine was first placed in service/operation? What is the date this engine commenced construction? What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes E No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. 3 Permit Number: AIRS ID Number: Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) Lat 40.636235, Lon -104.066576 Operator Stack ID No. Discharge Height Above Ground Fee)tLevel Temp. ("F) Flow Rate (ACFM) Velocity (ft/sec) Compressor 5 TBD TBD TBD TBD Indicate the direction of the Stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 0 Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): ❑ Upward with obstructing raincap TBD Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate ® 100% Load (SCF/hour) Actual Annual Fuel Use (MMSCF/ year) Requested Annual Permit Limit (MMSCF/ year) 4,077 35.72 From what year is the actual annual amount? 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 0 Other (describe): Residue Natural Gas Heating Value (give units): 1,089 Btu/scf 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. E Cif \I 4 I AelaW Permit Number: AIRS ID Number: Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM 2.5 SOX NOx Three-way Catalyst 93.3% VOC Three-way Catalyst _...4..1-9 0 —Q CO Three-way Catalyst 84.0% Other: 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? Criteria Pollutant Emissions Inventory Emission Factor Actual Annual Emissions9 Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) E-030.019YIb/MMBtu AP -42 ittli 0.38 t> O-38 PM10 7 050....04 lb/MMBtu AP -42 0.j 1'5. 0.36 0.ge?t- 0_ 3 6 PM 15 7.7 - 5 Q.V19 N lb/MMBtu AP -42 0 1517. 30 9.4'V 0,38 SOX 5.88E-04 lb/MMBtu AP -42 0.011 0.011 NOx 2.21 lb/MMBtu AP -42 42.98 2.90 VOC Ib/MMBtu AP -42 """... /.33 1.33 CO /A44 3.72 lb/MMBtu AP -42 72.34 11.59 Does the emissions source have any uncontrolled actual emissions of non -criteria ❑✓ Yes pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: ❑ No Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions9 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds/year) Formaldehyde 50000 0.02. I AP -42 -} q q- 3- q -- Acetaldehyde 75070 „5...2...§.F.-02'lb/MMBtu Acrolein 107028 2.63E-03 Ib/MMBtu AP -42 Benzene 71432 1.58E-03 lb/MMBtu AP -42 Other: 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. h iTc oi r? 5I Permit Number: AIRS ID Number: [Leave blank unless AP -CE has already assigned a permit 4 and AIRS IN 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 copriittori of general permit GP02. Signature of Legally Auorized Person (not a vendor or consultant) Colin Moe Vice President of Commercial Development Name (please print) Title Check the appropriate box to request a copy of the: O 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 reportabte change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C, for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246.1530 Make check payable to: https://www.colorado,gov/cdphe/aped Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Form APCD-201 = Reciprocating Internal Ccnbustion Engine APEN = Revision 1/2017 E. I -b��. STATE OF COLORADO Gruel - CDPHE, Andrew <andrew.gruel@state.co.us> RE: Taproot Radicle Gas Plant Phase I Construction Permit Application Brad Sohm <bsohm@swca.com> Mon, Jul 2, 2018 at 1:00 PM To: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Cc: Colin Moe <cmoe@taprootep.com>, Chris Rial <crial@taprootep.com>, Daniel Kennedy <dkennedy@taprootep.com>, Bill Jamieson <bjamieson@swca.com> Andy, I agree with the corrections and proposed redline changes. Best Regards, Brad Sohm, P.E. Sr. Air Quality Specialist SWCA Environmental Consultants Email: bsohm@swca.com Toll Free 800.828.8517 www.swca.com Sound Science. Creative Solutions. From: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Sent: Monday, July 2, 2018 11:34 AM To: Brad Sohm <bsohm@swca.com> Cc: Colin Moe <cmoe@taprootep.com>; Chris Rial <crial@taprootep.com>; Daniel Kennedy <dkennedy@taprootep.com>; Bill Jamieson <bjamieson@swca.com> Subject: Re: FW: FW: Taproot Radicle Gas Plant Phase I Construction Permit Application Brad, I've found a few minor errors on the APEN you sent on 6/12/18 for "Residue Compressor 5" (point 005, Cat CG137-12). I will need to redline the APEN. It looks like you've erroneously applied AP -42 uncontrolled emission factors for VOC and formaldehyde from Table 3.2-2, which is for 4 -stroke lean burn engines. Instead (as you properly did for NOx and CO), we'll need to use Table 3.2-3 for rich burn, which is 0.0296 lb VOC/MMBtu, and 0.0205 lb HCHO/MMBtu. However the manufacturer's "controlled" emissions specs have VOC at 0.23 g/hp-hr, which is 0.069 lb/MMBtu and exceeds the AP -42 listed above. So for VOC only, I will use the manufacturer's controlled emission rate as the uncontrolled rate, and then assume 0% control of VOC. Ultimately this affects emissions in two ways: 1) VOC uncontrolled changes from 2.29 tpy to 1.33 tpy. No change to controlled VOC. VOC control credit is 0%. 2) Formaldehyde uncontrolled/controlled is now reportable at 797 lb/yr. Please reply to this email with approval for me to redline the APEN. Thank You, Andy Gruel, P.E. Oil and Gas Permit Engineer Stationary Sources Program Amine Sweetening Unit - Form. APCD-206 j ,t rF -& 20/6 Air Pollutant Emission Notice (APEN) and \ ell • 1 c {•r1ary ,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 Amine Sweetening 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,colsradsuoviCtIoheLami, 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: ' e (it/E O Li Li Li AIRS ID Number; 1 Z3 / ?F / co 04 II Ca,r., Monk firth <i A c;n liEi, e lrimtly wslgitot1 a µ riiilr ?t hnd A11,1 II)1 Company equipment identification; Rental Amine [Provid,= tclrrlpirient ID to Itiftntiry how this equipment - quip ent i r!rerenci-,d within your orpt ilzcttturtl Section 1 Administrative Information Company Name'; Taproot Rockies Midstream Site Name; Radicle Gas Plant Phase I Mailing Address; (Maude Zip Code) 518 17th Street, Suite 1800 Denver, CO 80202 E -Mail Addresst: crial@taprootep,com Site Location County; Weld NAiCS or SIC Code; 213112 Permit Contact:. Chris Rial Phone Number: (713) 481-1864 IPlease 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 APC0 via c -coati to the address provided, A -.) /A-c4t Form APCD-2OO Amine Strvootening Unit APEN Rt,vi ionn 04/2011 3I- v v 16 FoLQR4PR 1 iNalkv • IIMl Icon a. Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID) Section 2- Requested Action ID 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 name ❑ Add point to existing permit ❑ Change permit limit O Transfer of ownership3 O Other (describe below) -OR- ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PIE) Additional Info & Notes: Phase I Rental Amine Unit 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: 20 MMSCFD Rental Amine Treater Facility equipment Identification: For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Rental Amine / / 1 /1 /2019 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 Will this equipment be operated in any NAAQS nonattainment Yes O area Does this facility have a design capacity less than 2 long Yes O tons/day of I -12S in the acid gas? weeks/year No No Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 AtilivcoLoRmao 2 Ma Ir 11=t Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: TBD Model : TBD Serial Number: TBD Reboiler Rating: 6.0 Amine Type: ❑ MEA Pump Make and Model: TBD MMBtu/hr Absorber Column Stages: 21 ❑ DEA O TEA stages MDEA O DGA # of pumps: Sweet Gas Throughput": Design Capacity: 20 MMSCF/day Requested: 7,3©{} MMSCF/year Actual: MMSCF/year 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Inlet Gas: Pressure: 939,5 psig Temperature: 114 Rich Amine Feed: Pressure: 954.2 psia Flowrate: Gal/min Temperature: 148.5 °F Lean Amine Stream: Pressure: 987.3 psia Temperature: 120 Flowrate: 60 Gal/min Wt. % amine: 50 Mole loading H2S 4.0 ppm °F Mole LoadingCO2 0.0287 mai/mid Sour Gas Input: Pressure: 951,8 psia Flowrate: 20 MMSCF/Day Temperature: 114 'F NGL Input: Pressure: Flowrate: psia Temperature: Gal/min 'F Flash Tank: O No Flash Tank Pressure: 72.3 psia Temperature: 122.7 °F Additional Required Information: Q Attach a Process Flow Diagram • Attach the simulation model inputs & emission report • Attach composition reports for the rich amine feed, sour gas feed, NGL feed, & outlet stream (emissions) ❑✓ Attach the extended gas analysis (including BTEX & n -Hexane, H2S, CO2, temperature, and pressure) Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 COLADO s I OR�� Permit Number. AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit / and AIM ID] Section 5 - Stack Information Lat 40.636294, Lon -104.067443 a- y Rental Amine TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) 2✓ Upward O Horizontal ❑ Downward ❑ Other (describe): O Upward with obstructing raincap Indicate the stack opening and size: (check one) Q Circular Interior stack diameter (inches): TBD O Square/rectangle interior stack width (inches): Interior stack depth (inches): O Other (describe): Form APCD-208 - Amine Sweetening Unit APEN - Revision 4/20.17 4 ( A COLORADO Depesparrtafik.istiz Permit Number: AIRS ID Number: / t [Leave blank unless APCD has already assigned a permit # and Ails ID] Section 6 - Control Device Information ❑ VRU: Used for control of: Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed 4� ❑ Combustion Device: Used for control of: Flash and Acid Gas Rating: 2.44 MMBtu/hr Type: Thermal Oxidizer Make/Model: TBD Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency $ Minimum Temperature; 1,400 Waste Gas Heat Content 81.52 Btu/scf Constant Pilot Light:❑ Yes 0 No Pilot burner Rating 0.218 MMBtu/hr 0 Other: Used for control of: Description: Control Efficiency Requested Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 5 AW COLORADO J]yu1,61.0 ntAafk i�•YYY Huenbuunrcn.M Permit Number: AIRS ID Number: f [Leave blank unless APCD has already assigned a permit # and AIRS ID) Section 7 -Emissions Inventory Information Attach ail emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? C✓ Yes O No If yes, please describe the control equipment AND state the overall control efficiency (6, reduction): PM SOS H25 NOs VOC Thermal Oxidizer 95% CO HAPs Thermal Oxidizer 95% Other: From what year is the following reported actual annual emissions data? 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.) PM ttedV mile 5 'year Fni SOX H2S NOX VOC 16.03 MMMSCF Promax 58.51 2.93 CO 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-206 - Amine Sweetening, Unit APEN - Revision 04/2017 6 COLORADO AtratrinatarPubtc wavn Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS 30] Section 7 (continued) na Benzene 0.068 lb/MMSCF Promax 71432 :Fork ne Toluene 108883 0.049 lb/MMSCF Promax Ethylbenzene 100414 2.97E-03 lb/MMSCF Promax Xylenes 1330207 8.73E-03 lb/MMSCF Promax n -Hexane 110543 0.29 Ib/MMSCF Promax 2,2,4- Trimethylpentane Other: 540841 4.64E-05 Ib/MMSCF Promax 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Applicant Certification I hereby certify that all information contaiVerein and correct. nd information submitted with this application is complete, true Signature of Legally Authorized Person (not a vendor or consultant) Colin Moe Date Vice President of Commercial Development Name (please print) Title Check the appropriate box to request a copy of the: O Draft permit prior to issuance []i Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more Information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 or visit the APCD website at: https://vvww.colorado.gov/cdpheiapod Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 cas.4e.a oa 7I,j� a� iii►. JUN -8 2018 Glycol Dehydration Unit APEN - Form APCD-202 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You rriay 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 (Deny) 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-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 at: www.colorado.00v/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: I IA� p `-(� i AIRS ID Number: ( 2-3 /qF 87_/ o o 7 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: Rental TEG [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name1: Taproot Rockies Midstream Site Name: Radicle Gas Plant Phase I Site Location: S J R$OW c-0 I(, Te N, R 6i v✓ Mailing Address: (include Zip Code) 518 17th Street, Suite 1800 Denver, CO 80202 E -Mail Address2: trial @taprootep.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Chris Rial Phone Number: (713) 481-1864 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing Invoices will be issued by APCD via e-mail to the address provided. Ac4 N A Form APCD-202 - Glycol Dehydration Unit APEN - Revision 02/2017 3-7869T, ( COLORADO eepam,st'OVUM fe. IRMOF [1Wi1.01.f Permit Number: AIRS ID Number: / I [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 O Change company name ❑ Add point to existing permit ❑ Change permit limit O Transfer of ownership3 ❑ Other (describebelow) 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 & Notes: Phase 14 GPM Rental TEG Dehydrator 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: of water from natural gas Rental 4 GPM TEG Dehydrator for the removal Facility equipment Identification: For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Rental TEG / / 1 /1 /2019 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 Will this equipment be operated in any NAAQS nonattainment 1] Yes ❑ area Is this unit located at a stationary source that is considered a ❑ Yes Major Source of (HAP) Emissions weeks/year No No Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 Ay i CO 21 L Permit Number: AIRS ID Number: / I [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: TBD Model Number: TBD Dehydrator Serial TBD Reboiler Rating: 0.5 Number: Ethylene Glycol DiEthylene Glycol Glycol Used: ❑ (EG) � (DEG) Glycol Pump Drive: Q Electric ❑ Gas If Gas, injection pump ratio: Pump Make and Model: TBD Glycol Recirculation rate (gal/min): Max: 4 Lean Glycol Water Content: 0.15 Wt.% d MMSTU/hr TriEthylene Glycol (TEG) Requested: 4 # of pumps: Acfm/gpm Dehydrator Gas Throughput: Design Capacity: 20 MMSCF/day Requested: 7,300 MMSCF/year Actual: MMSCF/year Inlet Gas: Pressure: 937 Water Content.: Wet Gas: Flash Tank: Pressure: 65 Cold Separator: Pressure: Stripping Gas: (check one) [] None ❑ Flash Gas ❑ Dry Gas ❑ Nitrogen Flow Rate: scfm psig Temperature: Ib/MMSCF [ Saturated Dry gas: psig Temperature: psig Temperature: 122 145 °F Ib/MMSCF 'F ❑ NA °F ta NA Additional Required Information: ▪ Attach a Process Flow Diagram O Attach GRI-GLYCaIc 4.0 Input Report & Aggregate Report (or equivalent simulation report/test results) Q Attach the extended gas analysis (including BTEX & n -Hexane, temperature, and pressure) Form APCD-202 -Glycol Dehydration Unit FtPEN - Revision 02/2017 3 I, COLORADO )liNfk631WOMnMf Permit Number: AIRS ID Number: I / [Leave blank unless APCD has already assigned a permit # and AIP,S ID] Section 5 - Stack Information TBD TBD Rental TEG Lat 40.636310, Long -104.067535 TBD TBD Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): 2 Upward ❑ Horizontal O Upward with obstructing raincap Indicate the stack opening and size: (check one) (Q Circular Interior stack diameter (inches): TBD O Square/rectangle Interior stack width (inches): Interior stack depth (inches): El Other (describe): Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 4 VJJXXCQLQRADO taIh YinroiAeowlea Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and AIRS 1D] Section 6 - Control Device Information a Condenser: Used for control of: Regenerator Gas Type: BTEX Maximum Temp 160 Make/Model: TBD Average Temp 125 Requested Control Efficiency 0 % ❑ VRU: Used for control of: Size: Make/Model: Requested Control Efficiency % VRU Downtime or Bypassed 96 Combustion V Device: Used for control of: Regenerator Gas, Flash Gas Rating: 2.44 MMBtu/hr Make/Model: TBD Type: Thermal Oxidizer Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: 1,400 95 95 Waste Gas Heat Content Constant Pilot Light: El Yes O No Pilot burner Rating 81.52 0.0218 Btu/scf MMBtu/hr Closed Loop System: Used for control of: Description: System Downtime O Other: Used for control of: Description: Control Efficiency Requested Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 j co'iORADO O ; rzri.=Frwm 5 � e�,nsu,�.� PM Permit Number: AIRS ID Number: I I [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): eral ei 95% SOX NO, CO VOC BTEX Condenser and Thermal Oxidizer NAPS BTEX Condenser and Thermal Oxidizer 95% Other: From what year is the following reported actual annual emissions data? 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.) c�ori PM (yea (year) SO, NO, CO VOC 24.87 IbtMMSCF GRI-GlyCalc 90.78 4.54 Benzene 0.102 lb/MMSCF GRI-GlyCalc 0.373 0.019 Toluene 0.0931 lb/MMSCF GRI-GlyCalc 0.340 0.017 Ethyl benzene 0.00996 I&MMSCF GRI-GlyCaic 0.037 0.0018 Xylenes 0.0293 Ib'MMSCF GRI-GlyCalc 0.107 0.0053 n -Hexane 1.934 Ib/MMSCF GRI-GlyCalc 7.06 0.353 2,2,4- Trimethylpentane Other: 4.80E-04 Ib/MMSCF GRI-GlyCaic 0.0018 9.0E-05 4 Requested values will become permit limitations. Requested limits) should consider future process growth. sAnnual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 COLOR ADO a.�+.n.entis#11bue H+�bbb€xKanmmerz< Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification , I hereby certify that all information cunt ed herein and information submitted with this application is complete, true and correct. Signature of Legally Adeorized Person (not a vendor or consultant) Colin Moe Vice President of Commercial Name (please print) Title Check the appropriate box to request a copy of the: O 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) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, Co 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://wm,colorado.gov/cdphe/apcd Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 7j FAi(Stli==,"dI1vA[ft"wtPCP+Mt Boiler APEN Form APCD 220 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 boilers, hot oil heaters, process heaters, and similar equipment. If your emission unit does not fall into one of these categories, there may be a more specific APEN for your source (e.g. paint booths, mining operations, engines, 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. Do not complete this form for the following source categories: Heaters or boilers with a design capacity less than or equal to 5 MMBtu/hour that are fueled solely by natural gas or liquid petroleum gas (LPG). Heaters or boilers with a design capacity less than or equal to 10 MMBtu/hour used solely for heating buildings for personal comfort that is fueled solely by natural gas or liquid petroleum gas (LPG). More information can be found in the APEN exempt/permit exempt checklist: https: / /www.colorado.g'ov/pacific/cdphe/apen-or-air-permit-exemptions. 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: 1 Z3 /9Fe7./ oo'7 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Taproot Rockies Midstream Site Name: Radicle Gas Plant Site Location: S k6 flillb Sec&•(1,r "1261 Mailing Address: (Include Zip code) 518 17th Street, Suite 1800 Denver, CO 80202 E -Mail Address2: crial@taprootep.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Chris Rial Phone Number: (713) 481-1864 1 Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 318699 Form APCD-220 - Boiler APEN - Revision 11/2017 1 I ♦ ` CO COLORADO uepa,im.e.elrueuc Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑� NEW permit OR newly -reported emission source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit O Transfer of ownership3 ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Please 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) ❑ APEN submittal for permit exempt/grandfathered source Additional Info £r Notes: Phase I and Phase II - Hot Oil Heater A 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: 12.0 MMBtu/hr Hot Oil Heater for the Stabilizer Reboiler, MRU Reboiler, and Inlet Flash Heater Manufacturer: TBD Model No.: TBD Serial No.: TBD Company equipment Identification No. (optional): Hot Oil Heater A For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: 1/1/2019 ❑r 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 Seasonal use percentage: Dec -Feb: Mar -May: June -Aug: Sept -Nov: Are you reporting multiple identical boners on this APEN? ❑ Yes ❑✓ No If yes, please describe how the fuel usage will be measured for each boiler (i.e., one meter for all boilers or separate meters for each unit): Form APCD-220 - Boiler APEN - Revision 11/2017 2 I COLORADO Department NWNI*EMISI utwm f.= Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) Lat 40.636714, Lon -104.067403 Operator Stack ID No Discharge Height Above Ground Level , u (Feet) Temp ( F) Flow Rate (ac_.. <, Velocity (ft/sec) Hot Oil Heater A TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward 0 Other (describe): Indicate the stack opening and size: (check one) E Circular ❑ Square/rectangle Interior stack width (inches): 0 Other (describe): Interior stack diameter (inches): ❑ Upward with obstructing raincap TBD Interior stack depth (inches): Section 5 - Fuel Consumption Information Design Input Rate:. (MMBTU/hr) Actual Annual Fuel Use4 (Specify Units) Requested Annual Permit Limits (Specify Units) 12.0 96.54 MMSCF/yr From what year is the actual annual fuel use data? Fuel consumption values entered above are for: 0 Each Boiler ❑ All Boilers ❑✓ N/A Indicate the type(s) of fuel used6: ❑ Pipeline Natural Gas O Field Natural Gas ❑ Ultra Low Sulfur Diesel ❑ Propane 0 Coal E Other (describe): (assumed fuel heating value of 1,020 BTU/SCF) Heating value: BTU/SCF (assumed fuel heating value of 138,000 BTU/gallon) (assumed fuel heating value of 2,300 BTU/SCF) Heating value: BTU/lb Ash content: Sulfur Content: Residue Natural Gas Heating value (give units): 1,089 Btu/scf 4 If you are reporting multiple identical boilers on one APEN, be sure to clarify if the values in this section are on an individual boiler basis, or if the values represent total fuel usage for multiple boilers. 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 If fuel heating value is different than the listed assumed value, please provide this information in the "Other" field. Form APCD-220 - Boiler APEN - Revision 11/2017 3 I AY COLORADO Departmeetal Public NWTklen.rOrirt4N Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6- Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes ® No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Control Efficiency (% reduction in emissions) TSP (PM) PA() PM2.5 SOX NO. CO VOC Other: From what year is the following reported actual annual emissions data? Use the following tables to report the criteria pollutant emissions from source: (Use the data reported in Section 5 to calculate these emissions.) Primary Fuel T e YP (natural gas; #2 diesel, etc.) Pollutant ,: Uncontrolled - Emission (specafy Units) Emission Factor Source = (.AP -42, mfg. et) al ., µ . ;actual Annual; Emissions it_ , Zfif. Requested Annual Permit - .-, x- �� Emission L1mrt(s) -' 3.. - . ,„ dti Uncontrolled (Tons/year) "Controlled? (Tons/year) - Uncontrolled (Tons/year) , '' Controlled (Tons/year) Natural Gas TSP (PM) 8.1141b/MMSCF AP -42 0.39 0.39 PM10 8.1141b/MMSCF AP -42 0.39 0.39 PM2.5 8.1141b/MMSCF AP -42 0.39 0.39 SOX 0.641 Ib/MMSCF AP -42 0.03 0.03 NO. 31.737IbMIMSCF Mfg. 1.53 1.53 CO 89.682IbRv1MSCF AP -42 4.33 4.33 VOC 5.872Ih/MMSCF AP -42 0.28 0.28 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 4I AV Department COLORADO d' W. N 414.M.uaaN. Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] ❑✓ Check this box if the boiler did not combust a secondary fuel during this reporting period and skip to Section 7. If multiple fuels were fired during this reporting period, complete this secondary fuel emissions table and the total criteria emissions table below: Secondary Fuel Type (#2 diesel, waste oil, etc ) Pollutant Uncontrolled Emission (sp Factor Units) Emission Factor Source , (AP -42, mfg. etc) Actual Annual' Emissions w „ . Requested Annual Permit Emission Limits) . _. I,, - Uncontrolled (Tons/year) Controlled? (Tons/year) Uncontrolled " (Tons/year)" Controlled (Tons/year) TSP (PM) PM,o PM2.5 SO. NO. CO VOC Other: If multiple fuels were fired during this reporting period, use the following table to report the TOTAL criteria pollutant emissions from the source. Values listed below should be the sum of the reported emissions from the primary and secondary fuels' emissions tables in this Section 6: Pollutant Actual Annual $ -- Emissions - ._.,. Requested Annual Permrt ,_ Ivry Emission 'Limit(s)5 Uncontrolled (Tons/year) Controlled? (Tons/year) Uncontrolled ` (Tons/year) Controlled (Tons/year) TSP (PM) PM10 PM2.5 SOX NO. CO VOC Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 7 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. © COLORADO Form APCD-220 - Boiler APEN - Revision 11/2017 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP- hazardous air pollutant) equal to or greater than 250 lbs/year? ❑ Yes ® No in table to report the non -criteria pollutant (HAP) emissions from source: CAS Number Chemical Name Overall Control Efficiency Uncontrolled Emission Factor (specify units) Emission Factor Source (AP -42, Mfg. etc) Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions z (Ibslyear) Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-220 - Boiler APEN - Revision 11/2017 6l AY Otpataneneolhattic COLORADO Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Lega ( Au horized Person (not a vendor or consultant) Date Colin Moe Vice President of Commercial Development Name (please print) Title Check the appropriate box if you want: p Draft permit prior to public notice O Draft of the permit prior to issuance (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: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692- 3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-220 - Boiler APEN - Revision 11/2017 7 ',COLORADO '. Papawrmeed aauetk W6tfik R#YY9 t General APEN --- Form APCD-200 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. 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/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: (23 /yF$7/ o / C7 [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 1 - Administrative Information Company Name': Taproot Rockies Midstream Site Name: Radicle Gas Plant Phase Site Location: Se Ng -1460W - 26(w Mailing Address: 518 17th Street, Suite 1800 (Include Zip Code) Denver, CO 80202 Portable Source N/A Home Base: Site Location Weld County: NAICS or SIC Code: 213112 Permit Contact: Chris Rial Phone Number: (713) 481-1864 E -Mail Address: criai@taprootep.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. /Rk' a S-1-3 0 Form APCD-200 - General APEN - Revision 1/2017 1 I =Tire P,Alic COLORADO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source (check one below) O STATIONARY source O PORTABLE source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name O Add point to existing permit O Change permit limit ❑ Transfer of ownership3 O 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 a Notes: Phase I Thermal Oxidizer 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: Thermal Oxidizer to control VOC and HAPs from the Amine Vents, Glycol Vents, Tank Vapors, and Truck Loadout Vapors Manufacturer: TBD Model No.: TBD Serial No.: TBD Company equipment Identification No. (optional): TO For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 1/1/2019 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 Seasonal use percentage: Dec -Feb: Mar -May: days/week weeks/year Jun -Aug: Form APCD-200 - General APEN - Revision 1/2017 2 I Sep -Nov: COLORADO 9 .CCf:Riliic mom fr.pxssenxn.x Pilot Gas Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use O Check box if this information is not applicable to source or process From what year is the actual annual amount? Design Process Rate (Specify Units ual Annual Amount Specify Units, Requested Annual Permit Limit Specify Units] Mateiiai Consumption: Finishe Product 0.18 MMscf/yr Assist Gas 8.85 MMscf/yr Waste Gas 1 . 2 MMscf/yr 1611.53 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Arc, 3'-fri Section 5 - Stack Information eographica( Coordinates .atitude/Longitude or UTM)`', Lat 40.636146, Lon -104.067728 ❑ 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. Indicate the direction of the stack outlet: (check one) TO I TBD TBD TBD TBD Q Upward ❑ Horizontal ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) • Circular Interior stack diameter (inches): TBD ❑ Square/rectangle Interior stack width (inches):. ❑ Other (describe): Interior stack depth (inches): Form APCD-200 - General APEN - Revision 1/2017 Avr COLORADO 3 iemcu.O H* fF mt TSP (PM) Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Combustion Equipment £t Fuel Consumption Information ❑ 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 MMBTU/hr) Actual Annual Fuel Use (Specify Units)' Requested Annual Permit Lumtt4 [Specify Units) 2.44 1 MMscf r From what year is the actual annual fuel use data? Indicate the type of fuel used5: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: 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: ❑✓ Other (describe): Amine, TEG, Tank and LnadoutVapors / Pilot and AssistGas Fuel Heating value (give units): 81.52 Btu/scf / 1,089 Btu/scf 163• 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes (] No If yes, describe the control equipment AND state the overall control efficiency (% reduction): verall Control Efficten (%reduction in emissions) PMta PM2.5 SOX NO„ CO VOC Other: Form APCD-200 - General APEN - Revision 1/2017 :!COLORADO 4 ii Permit Number: AIRS ID Number: / / [Leave blank urAess APCD has already assigned a permit # and AIRS ID] Section 7 (continued) From what year is the following reported actual annual emissions data? 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.) TSP (PM) ontrolled6 _ Uncontrolle (Tons/yearn) (Tpm/year 06' PM10 PM2.s SOx Nox 31312_ CO -7.4.6`18 VOC I S�MM 7.6 Ib/MMscf AP -42 5.7 Ib/MMscf AP -42 ,0,6 Ib/MMscf AP -42 14211 /�vlMscf TNRCC 25.811 MMscf TNRCC st4 047- l __(;)...0-716' o.17_ 0.0 . 0.01 3_ o O:Ofl� 0,087 1X 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 bla o•I7- 0. t2- 6 .0 I f.)6 _1l 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 250 lbs/year? If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: controlle ctual uveralt Control Efficienc /- 16(.01 2y`1 -S 1.1-3 2yy. S 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-200 - General APEN - Revision 1/2017 51 COLORADO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification 1 hereby certify that all information contai true and correct. herein and information submitted with this application is complete, Signature of Legally 1 t orized Person (not a vendor or consultant) or Date Colin Moe Vice President of Commercial Development Name (print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance I] 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 Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-200 - General APEN - Revision 1/2017 COLORADO 6 I I Nw°'" STATE OF COLORADO Gruel - CDPHE, Andrew <andrew.gruel@state.co.us> Draft permit for your review - 18WE0444 Brad Sohm <bsohm@swca.com> Mon, Jul 9, 2018 at 4:22 PM To: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Cc: Daniel Kennedy <dkennedy@taprootep.com>, Chris Rial <crial@taprootep.com>, Dale Hunt <dhunt@alien-energy.com>, Bill Jamieson <bjamieson@swca.com> Andy, v‘ -requested, please find attached the updated and signed APEN and O&M Plan for point 005 (Residue Compressor 5, Cat CG137-12). In addition, we agree with your edits on the TO vapor volumes and heat input rates from your July 2, 2018 email. Please proceed with making the redline updates for a requested permit limit to 164.6 MMscf/yr and the following emission rates NOx (3.06 tpy), CO (6.11 tpy), and n -hexane (294 Ib/yr). We are currently reviewing the draft permit and will provide any comments by July 17, 2018. Please let us know if you have any additional questions or concerns. Best Regards, Brad Sohm, P.E. Sr. Air Quality Specialist SWCA Environmental Consultants Email: bsohm@swca.com Toll Free 800.828.8517 www.swca.com Sound Science. Creative Solutions. From: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Sent: Thursday, July 5, 2018 10:26 AM To: Brad Sohm <bsohm@swca.com> Condensate Storage Tank(s) APEN Form APCD-205 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 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-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 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: I $w -(7I -P -1y AIRS ID Number: I Z 3 /Ii 887-/ D I I [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Taproot Rockies Midstream Site Name: Radicle Gas Plant Site Location: s Site Location o 8Nr-R6OW County: Weld 5 Cc % II, 7611/4) .6( Mailing ddress: (Include Zip code) 518 17th Street, Suite 1800 Denver, CO 80202 NAICS or SIC Code: 213112 Permit Contact: Phone Number: E -Mail Address2: Chris Rial (713) 481-1864 crial@taprootep.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 y APCD via e-mail to the addres ,Qjoid d. 37 Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 1 COLORADO DepumbnMN t fl Health F v 6emnmee¢ F Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action p NEW permit OR newly -reported emission source p 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 $250 must be submitted along with the APEN filing fee. -OR ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment O Change company name ❑ Change permit limit ❑ Transfer of ownership3 ❑ 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 a Notes: Phase I and Phase II - 500 -bbl Gunbarrel Tank 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: For existing sources, operation began on: 500 -bbl Gunbarrel Tank For new or reconstructed sources, the projected start-up date is: 1/1/2019 Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Storage tank(s) located at: ❑ Exploration £t Production (E&P) site ❑✓ Midstream or Downstream (non EftP) site Will this equipment be operated in any NAAQS nonattainment area? Yes No SI • Are Flash Emissions anticipated from these storage tanks? ■ Yes 12 No Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? Yes No 0 • If "yes", identify the stock tank gas -to -oil ratio: 1.05e-04 m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No • I2 Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual• emissions ≥ 6 ton/yr (per storage tank)? Yes No p 0 Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 21 • Co COLORADO Ovanasent el Public Huhla irk Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl/year) Condensate Throughput:` From what year is the actual annual amount? Average API gravity of sales oil: 76.50 degrees ❑ Internal floating roof Tank design: ❑✓ Fixed roof Requested Annual Permit Limit4 (bbl/year) 1,0 361, 5 2. 6 A- s/2 s 1,6 t RVP of sales oil: 10.84 O External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank ` Total Volume of Storage Tank (1)/31) Installation Date of Most Recent Storage Vessel in . Storage Tank"(month/year) _ Date of First '..` Production (monthlyear)-. Gunbarrel 1 500 01/2019 Wells Serviced by this Storage Tank or Tank Battery5 (MP Sites Only) API Number Name of Well Newly Reported Well 0 0 0 0 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The EftP 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) Lat 40.636069, Lon -104.067214 ' Operator Stack ID No. Discharge Height Above: Ground Level (feet)_- , Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) Gunbarrel TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) I] Upward ❑ Horizontal ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): TBD ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 3 1 ifCOLORADO ff l 6"Er Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information O Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Vapor ❑ Recovery Unit (VRU): Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: % ❑ Combustion Device: Pollutants Controlled: VOC, HAPs Rating: 4.86 MMBtu/hr Type: Flare Make/Model: TB D Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: Minimum Temperature: Waste Gas Heat Content: 3,926.99 Btu/scf Constant Pilot Light: Yes ❑ No Pilot Burner Rating: 0.62 MMBtu/hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: 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: Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 COLORADO 4 �fEntPubtic I£ Benzene Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form6. 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): Pollutant VOC Description of Control Method(s) Flare Overall Requested Control Efficiency (% reduction in emissions) 95 NOx CO HAPs Flare 95 Other: From what year is the following reported actual annual emissions data? Pollutant VOC Criteria Pollutant Emissions Inventory Emission Factor6 Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)4, Uncontrolled Basis 0.11 Units Ib/bbl E&P Tanks Uncontrolled Emissions (Tons/year) Controlled, Emissions7 (Tons/year) Uncontrolled Emissions (Cons/year), 20.7 Controlled Emissions (Tons/year) 1.04 NOx CO Non -Criteria Reportable Pollutant Emissions Inventory Chemical Abstract Service (CAS) Number Emission Factor6 Actual Annual Emissions Uncontrolled Basis! Units Source (AP -42, Mfg. etc) Uncontrolled Emissions. (Pounds/year) Controlled `- Emissions? (Pounds/year) 71432 7.43E-04 lb/bbl E&P Tanks Toluene 108883 4.05E-04 lb/bbl E&P Tanks Ethylbenzene 100414 3.37E-05 lb/bbl E&P Tanks Xylene 1330207 6.56E-05 lb/bbl E&P Tanks n -Hexane 2,2,4- Trimethylpentane 110543 0.0 540841 llq 3.89E-06 lb/bbl lb/bbl E&P Tanks E&P Tanks 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 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. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. AG s125/16 Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 5 I COLORADO wreak s Permit Number: AIRS ID Number: [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. 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 complia ith each co ion of the applicable General Permit. C//y�1oi c Signature of Legally Author' -d Person (not a vendor or consultant) Date Colin Moe Vice President of Commercial Development 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 $152.90 and the General Permit For more information or assistance call: registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 6 COLORADO Ne-,�.m..t,.e Public 5/25/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application STATE OF COLORADO Gruel - CDPHE, Andrew <andrew.gruel@state.co.us> RE: Taproot Radicle Gas Plant Phase I Construction Permit Application Rebecca Martarella <RMartarella@swca.com> To: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Cc: Daniel Kennedy <dkennedy@taprootep.com>, Chris Rial <crial@taprootep.com>, Dale Hunt <dhunt@alien-energy.com>, Brad Sohm <bsohm@swca.com>, Bill Jamieson <bjamieson@swca.com> Andy, Please see responses to your questions below in red. Thank you, Rebecca Martarella Air Quality Specialist SWCA Environmental Consultants Email: rmartarella@swca.com Toll Free 800.828.8517 www.swca.com SWCA From: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Sent: Thursday, May 10, 2018 3:57 PM To: Rebecca Martarella <RMartarella@swca.com> Cc: Brad Sohm <bsohm@swca.com> Subject: Re: Taproot Radicle Gas Plant Phase I Construction Permit Application Rebecca and Brad, Here are additional questions for the Radicle Gas Plant application: Wed, May 23, 2018 at 11:43 AM 3) "Hot Oil Heater A" (Point 009) -- I see the manufacturer's specs for NOx emissions, but I cannot trace the calculation steps to arrive at the model -specific NOx emission factor of 31.737 lb/MMscf. Would you please clarify that emission factor calculation? We used EPA Reference Method 19 to convert 24 ppm of NOx to lb/MMBtu. The lb/MMBtu value was https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver=FPvd7uxXULs.en.&cbl=gmail fe_180508.13_p10&view=pt&msg=1638e1960f808a59&search=inbo: 5/25/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application then multiplied by the gas heating value of 1,089 Btu/scf to convert to 31.737 lb/MMscf. We have attached a spreadsheet showing the ppm to lb/MMBtu conversion. 4) "Hot Oil Heater A" (Point 009) -- in order to use that model -specific NOx emission factor, Taproot will be required to install that specific make/model of heater. It appears it is Fulton 12005-LF, please confirm. Yes, the Fulton 1200S- LF will be installed. 5) Gunbarrel tank (Point 011) APEN has requested annual permit limit of 1012.4 bbl/yr which appears to be an error. Calc sheets and narrative specify 369,526 bbl/yr. I will need to redline the APEN with your permission. Yes, please redline this APEN. 6) Gunbarrel tank (Point 011) - APEN appears to have a typo in the emission factor for n -hexane. Calc sheet has 0.0119 lb/bbl, but the APEN hs 0.019 lb/bbl. I agree with the 0.0119 lb/bbl, and if you agree this was a typo I'll need to redline the APEN with your permission. Yes, we agree that 0.0119 is correct. Please redline the APEN. 7) Condensate tanks (Point 012) -- APEN has the same error in requested annual permit limit (1012.4 bbl/yr). I'll redline the APEN with your permission. Yes, please redline this APEN. 8) NGL Loadout (Point 013) -- HAPs calculation appears to multiply the HAP weight fraction by the VOC emission rate. I think it would be more correct to multiply the HAP weight fraction by the overall vapor emission rate. I.e., for n - hexane, 0.2062 * 15956.8 * 0.11038 = 363 lb/yr. This results in slightly higher HAP emissions than you had calculated. Do you agree? Nevertheless n -hexane remains the only reportable HAP. If you agree I'll redline the APEN with your permission. Yes, we agree. You may redline the APEN. 9) NGL Loadout (Point 013) -- What is the source of the NGL composition (used to derive VOC and HAP emissions)? Is it from a similar gas plant? Is methanol anticipated to be present in the NGL and/or condensate streams? The NGL composition was based on the ProMax simulation of the facility. No methanol is anticipated to be present in the condensate, and only 0.00676 vol% methanol is anticipated to be present in the NGL. Thank You, Andy Gruel, P.E. Oil and Gas Permit Engineer Stationary Sources Program COLORADO. Air Pollution Control Division l_ epA tni nt cal Health b- !_t It l f'}?`T` ent P 303.692.3143 4300 Cherry Creek Drive South, Denver, CO 80246-1530 andrew.gruel@state.co.us I www.colorado.gov/cdphe/apcd https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver=FPvd7uxXULs.en.&cbl=gmail_fe_180508.13_p 10&view=pt&msg=1638e 1960f808a59&search=inbo: Condensate Storage Tank(s) APEN Form APCD-205 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 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-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 at: www.colorado.Rov/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: AIRS ID Number: 113 / 9F37/ o 12_ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Taproot Rockies Midstream Site Name: Radicle Gas Plant Site Location: Se 6 8N7R68W- ��o�, II , TON , Ci A/ Mailing Address: (Include Zip Code) 518 17th Street, Suite 1800 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Chris Rial Phone Number: (713) 481-1864 E -Mail Address2: crial@taprootep.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via a -mail to the address provided. 378702 Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 1 COLORADO Oap.rtmsa t of Pudic N Ca° Sou es Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source E Request coverage under traditional construction permit ❑ Request coverage under a General Permit 0 GP01 0 GP08 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN filing fee. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) O Change in equipment 0 Change company name ❑ Change permit limit 0 Transfer of ownership3 ❑ 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 Et Notes: Phase I and Phase II - 2 x 400 -bbl Condensate Storage Tanks 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: For existing sources, operation began on: Two (2) 400 -bbl Condensate Storage Tanks For new or reconstructed sources, the projected start-up date is: 1/1/2019 Normal Hours of Source Operation: 24 hours/day 7 days/week 52 Storage tank(s) located at: 0 Exploration a Production (E&P) site weeks/year ✓❑ Midstream or Downstream (non E&P) site Will this equipment be operated in any NAAQS nonattainment area? Yes No 12 ■ Are Flash Emissions anticipated from these storage tanks? Yes No • 12 Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? Yes No • ■ If "yes", identify the stock tank gas -to -oil ratio: 1.01e-04 m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No • p Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes No ■ p Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 2 COLORADO , aflhf °mow Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl/year) Requested Annual Permit Limit4 (bbl/year) Condensate Throughput From what year is the actual annual amount? Average API gravity of sales oil: 76.50 degrees O Internal floating roof Tank design: 0 Fixed roof 361) .C RVP of sales oil: 10.84 O External floating roof Storage ' Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First', Production (month/year) Condensate 2 800 (2 x 400 -bbl) 01/2019 API Number' Wells Serviced by this Storage Tank or Tank Battery 5 (E8P Sites Only) Name of Well Newly Reported Well CI ❑ 0 CI 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The EV 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) Lat 40.636069, Lon -104.067214 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. (°F)! Flow Rate (ACFM) Velocity (ft/sec) Condensate TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) 0 Upward 0 Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 0 Circular ❑ Square/rectangle ❑ Other (describe): 0 Upward with obstructing raincap Interior stack diameter (inches): TBD Interior stack width (inches): Interior stack depth (inches): Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 3 I 4 Co -a COLORADO oepartmentals.we Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] 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: Vapor ❑ Recovery Unit (VRU): Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: ❑ Combustion Device: Pollutants Controlled: VOC, HAPs Rating: 4.86 MMBtu/hr Type: Flare Make/Model: TB D Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: Minimum Temperature: 95 Waste Gas Heat Content: Constant Pilot Light: ✓❑ Yes 0 No Pilot Burner Rating: 3,926.99 Btu/scf MMBtu/hr O Closed Loop System Description of the closed loop system: O Other: Pollutants Controlled: 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: Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 4 COLORADO Nealzbfln Crease et Chemical Name Benzene Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form6. 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): Pollutant VOC NOx CO Description of Control Methods) Flare Overall Requested Control Efficiency (% reduction in emissions) 95 HAPs Flare 95 Other: From what year is the following reported actual annual emissions data? Pollutant Criteria Pollutant, Emissions Inventory Emission Factor6 Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled Basis Ib/bbl Uncontrolled Emissions (Tons/year), Controlled Emissions? (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) VOC 0.11 E&P Tanks 19.85 0.993 NOx CO on -Criteria Reportable Pollutant Emissions Inventory Chemical Abstract Service (CAS) Number Emission Facto Actual Annual Emissions'. .` Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds/year), 71432 7.12E-04 Ib/bbl E&P Tanks Toluene 108883 3.89E-04 Ib/bbl E&P Tanks Ethylbenzene 100414 3.23E-05 Ib/bbl E&P Tanks Xylene 1330207 6.28E-05 Ib/bbl E&P Tanks n -Hexane 110543 1.14E-02 Ib/bbl E&P Tanks 2,2,4- Trimethylpentane 540841 3.73E-06 Ib/bbl E&P Tanks 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 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. Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 1COLORADO 5I I XeepEbEnuL n P,aUc Permit Number: AIRS ID Number: / / [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. 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 •ach c• dition of the applicable General Permit. Signature of Legally Auth.rized Person (not a vendor or consultant) Date Colin Moe Director 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 $152.90 and the General Permit registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 6 COLORADO Deparsesset 5/25/2018 State.co.us Executive Brandi Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application STATE OF COLORADO Gruel - CDPHE, Andrew <andrew.gruel@state.co.us> RE: Taproot Radicle Gas Plant Phase I Construction Permit Application Rebecca Martarella <RMartarella@swca.com> To: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Cc: Daniel Kennedy <dkennedy@taprootep.com>, Chris Rial <crial@taprootep.com>, Dale Hunt <dhunt@alien-energy.com>, Brad Sohm <bsohm@swca.com>, Bill Jamieson <bjamieson@swca.com> Andy, Please see responses to your questions below in red. Thank you, Rebecca Martarella Air Quality Specialist SWCA Environmental Consultants Email: rmartarella@swca.com Toll Free 800.828.8517 www.swca.com SWCA From: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Sent: Thursday, May 10, 2018 3:57 PM To: Rebecca Martarella <RMartarella@swca.com> Cc: Brad Sohm <bsohm@swca.com> Subject: Re: Taproot Radicle Gas Plant Phase I Construction Permit Application Rebecca and Brad, Here are additional questions for the Radicle Gas Plant application: Wed, May 23, 2018 at 11:43 AM 3) "Hot Oil Heater A" (Point 009) -- I see the manufacturer's specs for NOx emissions, but I cannot trace the calculation steps to arrive at the model -specific NOx emission factor of 31.737 lb/MMscf. Would you please clarify that emission factor calculation? We used EPA Reference Method 19 to convert 24 ppm of NOx to lb/MMBtu. The lb/MMBtu value was https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver=FPvd7uxXULs.en.&cbl=gmail fe_180508.13_p10&view=pt&msg=1638e1960f808a59&search=inbo: 5/25/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application then multiplied by the gas heating value of 1,089 Btu/scf to convert to 31.737 lb/MMscf. We have attached a spreadsheet showing the ppm to lb/MMBtu conversion. 4) "Hot Oil Heater A" (Point 009) -- in order to use that model -specific NOx emission factor, Taproot will be required to install that specific make/model of heater. It appears it is Fulton 1200S-LF, please confirm. Yes, the Fulton 1200S- LF will be installed. 5) Gunbarrel tank (Point 011) APEN has requested annual permit limit of 1012.4 bbl/yr which appears to be an error. Calc sheets and narrative specify 369,526 bbl/yr. I will need to redline the APEN with your permission. Yes, please redline this APEN. 6) Gunbarrel tank (Point 011) - APEN appears to have a typo in the emission factor for n -hexane. Calc sheet has 0.0119 lb/bbl, but the APEN hs 0.019 lb/bbl. I agree with the 0.0119 lb/bbl, and if you agree this was a typo I'll need to redline the APEN with your permission. Yes, we agree that 0.0119 is correct. Please redline the APEN. 7) Condensate tanks (Point 012) -- APEN has the same error in requested annual permit limit (1012.4 bbl/yr). I'll redline the APEN with your permission. Yes, please redline this APEN. 8) NGL Loadout (Point 013) -- HAPs calculation appears to multiply the HAP weight fraction by the VOC emission rate. I think it would be more correct to multiply the HAP weight fraction by the overall vapor emission rate. I.e., for n - hexane, 0.2062 * 15956.8 * 0.11038 = 363 lb/yr. This results in slightly higher HAP emissions than you had calculated. Do you agree? Nevertheless n -hexane remains the only reportable HAP. If you agree I'll redline the APEN with your permission. Yes, we agree. You may redline the APEN. 9) NGL Loadout (Point 013) -- What is the source of the NGL composition (used to derive VOC and HAP emissions)? Is it from a similar gas plant? Is methanol anticipated to be present in the NGL and/or condensate streams? The NGL composition was based on the ProMax simulation of the facility. No methanol is anticipated to be present in the condensate, and only 0.00676 vol% methanol is anticipated to be present in the NGL. Thank You, Andy Gruel, P.E. Oil and Gas Permit Engineer Stationary Sources Program COLORADO Air Pollution Control Division Department of Public Health Environment P 303.692.3143 4300 Cherry Creek Drive South, Denver, CO 80246-1530 andrew.gruel@state.co.us I www.colorado.gov/cdphe/apcd https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver=FPvd7uxXULs.en.&cbl=g mail_fe_180508.13_p 10&view=pt&msg=1638e1960f808a59&search=inbo: Hydrocarbon Liquid Loading APEN - Form APCD-208 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 Hydrocarbon Liquid Loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: euJEot1 l AIRS ID Number: / Z 3 MFL7 / 01 3 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: NGL Loadout [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Taproot Rockies Midstream Site Name: Radicle Gas Plant Site Location: Sec kt S-c�4h4" I) TEN R6(v/ Mailing Address: (Include Zip Code) 518 17th Street, Suite 1800 Denver, CO 80202 E -Mail Address2: crial@taprootep.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Chris Rial Phone Number: (713) 481-1864 'Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that wilt 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 APCD via e-mail to the address provided. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev 02/2017 378703 Amy-- COLORADO 1 I Ziff °`P Haa U, & Emlennmanl Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ▪ NEW permit OR newly -reported emission source ❑✓ Request coverage under construction permit ❑ Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $250 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 0 Transfer of ownership3 0 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) Additional Info £t Notes: Phase I and Phase II NGL Loadout 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: Truck Loadout of Natural Gas Liquids (NGL) For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: / / 1/ 1 /2019 Will this equipment be operated in any NAAQS nonattainment area? Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Does this source load gasoline into transport vehicles? Is this source located at an oil and gas exploration and production site? If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Does this source splash fill less than 6750 BBL of condensate per year? Does this source submerge fill less than 16308 BBL of condensate per year? El Yes O No ❑ Yes [] No ❑ Yes p No ❑ Yes ❑✓ No ❑ Yes 0 No 0 Yes 0 No ❑ Yes 0 No Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 2 ►ATWpm-Meataf Public nail. 6 Envuaam.Mt Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: ❑ Condensate O Crude oil p Other: Natural Gas Liquids (NGL) If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded4: Bbl/yr Actual Volume Loaded: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth This product is loaded from tanks at this facility into: (eg, "rail tank cars" or "tank trucks") If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: Average temperature of bulk liquid loading: `F True Vapor Pressure Asia 60 ° F Molecular weight of displaced vapors Lb/lb mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: 3,419,320 Bbl/yr Actual Volume Loaded: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Product Density: Load Line Volume: 0.19 0.55 Lb/ft3 ft3/truckload Vapor Recovery Line Volume 0.55 ft3/truckload Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 31 AV Haallh 6Envumm.n1 COLORADO Permit Number: AIRS ID Number: ❑ Upward ❑ Horizontal [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Geographical Information Geographical Coordinates (Latitude/Longitude or UTM), Lat 40.635991, Lon -104.067383 Operator x**_ p o StacklD Nod' 0,-.1,-,,.: Discharge=Height' A oveGrounLevelt��;� � a Fee Feet) ,, Temp Fj .. ,mm r. 7 Flow Rated ( CFM�� fit" velocity;, (f t/ et N/A Indicate the direction of the stack outlet: (check one) ❑ Downward 0 Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): 0 Upward with obstructing raincap Section 6 - Control Device Information ❑ Loading occurs using a vapor balance system: Requested Control Efficiency ❑ Combustion Device: Pollutants Controlled: Rating: Type: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: MMBtu/hr Make/Model: Waste Gas Heat Content Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating Btu/scf MMBtu/hr hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested 0/0 Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 4 I®�,P Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes ❑✓ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested control Efficiency (% reduction in emissions) PM SOX NOx CO VOC HAPs Other: ❑ Using State Emission Factors (Required for GP07) VOC O Condensate 0.236 Lbs/BBL ❑ Crude 0.104 Lbs/BBL Benzene n -Hexane 0.00041 Lbs/BBL 0.0036 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled i i Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Av,- ,�g Actual Annual Emiss>on a_ i ..., e .v� Requested Annual Emissions 's u r , Permt imiit(s .go� Uncontrolled (Tons/year) - Controlled' (Tons/year) ! Uncontrolled (Tons/year) -' Controlled (Tons/year) PM SOX NOX 11/171 VOC o. ort..Z8 .LQ6O1 topslkra—Cr Eng. Estimate 1.60 1.60 CO Benzene ...1.27-E:01 tons/load Eng. Estimate 0.002 0.002 Toluene a.0Oo4 is/sb1 Ethylbenzene Xylenes n -Hexane y1.1't-u5 to Eng. Estimate 0 152 l .4 7' 0 O 2,2,4- Trimethylpentane o-q.,2S3 IS/LEA Other: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 5I . Nt FYalitlb£nvnnnmaN 1 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance wit each condition of the applicable General Permit. Signs a ot egaC Ily Aut orized Person (not a vendor or consultant) Date Colin Moe Vice President of Commercial Development 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 $152.90 and the General Permit registration fee of $250 as applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO l7�IW 6EMaanwMnl 5/25/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application STATE OF COLORADO Gruel - CDPHE, Andrew <andrew.gruel@state.co.us> RE: Taproot Radicle Gas Plant Phase I Construction Permit Application Rebecca Martarella <RMartarella@swca.com> To: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Cc: Daniel Kennedy <dkennedy@taprootep.com>, Chris Rial <crial@taprootep.com>, Dale Hunt <dhunt@alien-energy.com>, Brad Sohm <bsohm@swca.com>, Bill Jamieson <bjamieson@swca.com> Andy, Please see responses to your questions below in red. Thank you, Rebecca Martarella Air Quality Specialist SWCA Environmental Consultants Email: rmartarella@swca.com Toll Free 800.828.8517 www.swca.com SWCA a ca' ! ,.,y_l From: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Sent: Thursday, May 10, 2018 3:57 PM To: Rebecca Martarella <RMartarella@swca.com> Cc: Brad Sohm <bsohm@swca.com> Subject: Re: Taproot Radicle Gas Plant Phase I Construction Permit Application Rebecca and Brad, Here are additional questions for the Radicle Gas Plant application: Wed, May 23, 2018 at 11:43 AM 3) "Hot Oil Heater A" (Point 009) -- I see the manufacturer's specs for NOx emissions, but I cannot trace the calculation steps to arrive at the model -specific NOx emission factor of 31.737 lb/MMscf. Would you please clarify that emission factor calculation? We used EPA Reference Method 19 to convert 24 ppm of NOx to lb/MMBtu. The lb/MMBtu value was https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver=FPvd7uXXULs.en.&cbl=g mail_fe_180508.13_p10&view=pt&msg=1638e 1960f808a59&search=inbo: 5/25/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application then multiplied by the gas heating value of 1,089 Btu/scf to convert to 31.737 lb/MMscf. We have attached a spreadsheet showing the ppm to lb/MMBtu conversion. I) "Hot Oil Heater A" (Point 009) -- in order to use that model -specific NOx emission factor, Taproot will be required to install that specific make/model of heater. It appears it is Fulton 12005-LF, please confirm. Yes, the Fulton 1200S- LF will be installed. 5) Gunbarrel tank (Point 011) APEN has requested annual permit limit of 1012.4 bbl/yr which appears to be an error. Calc sheets and narrative specify 369,526 bbl/yr. I will need to redline the APEN with your permission. Yes, please redline this APEN. 6) Gunbarrel tank (Point 011) - APEN appears to have a typo in the emission factor for n -hexane. Calc sheet has 0.0119 lb/bbl, but the APEN hs 0.019 lb/bbl. I agree with the 0.0119 lb/bbl, and if you agree this was a typo I'll need to redline the APEN with your permission. Yes, we agree that 0.0119 is correct. Please redline the APEN. 7) Condensate tanks (Point 012) -- APEN has the same error in requested annual permit limit (1012.4 bbl/yr). I'll redline the APEN with your permission. Yes, please redline this APEN. 8) NGL Loadout (Point 013) -- HAPs calculation appears to multiply the HAP weight fraction by the VOC emission rate. I think it would be more correct to multiply the HAP weight fraction by the overall vapor emission rate. I.e., for n - hexane, 0.2062 * 15956.8 * 0.11038 = 363 lb/yr. This results in slightly higher HAP emissions than you had calculated. Do you agree? Nevertheless n -hexane remains the only reportable HAP. If you agree I'll redline the APEN with your permission. Yes, we agree. You may redline the APEN. 9) NGL Loadout (Point 013) -- What is the source of the NGL composition (used to derive VOC and HAP emissions)? Is it from a similar gas plant? Is methanol anticipated to be present in the NGL and/or condensate streams? The NGL composition was based on the ProMax simulation of the facility. No methanol is anticipated to be present in the condensate, and only 0.00676 vol% methanol is anticipated to be present in the NGL. Thank You, Andy Gruel, P.E. Oil and Gas Permit Engineer Stationary Sources Program COLORADO Air Pollution Control Division Loeb artrrrerat ref Public Health {: l=::m,...; onmr nt P 303.692.3143 4300 Cherry Creek Drive South, Denver, CO 80246-1530 andrew.gruel@state.co.us I www.colorado.gov/cdphe/aped https://mai l.google.com/mail/u/0/? u i=2&i k=9030c1528b&jsver=FPvd7 uxXU Ls. en. &cbl=gmai I_fe_180508.13_p 10&view=pt&msg=1638e 1960f808a59&search=i nbo: Hydrocarbon Liquid Loading APEN - Form APCD-208 \ Air Pollutant Emission Notice (APEN) and .j 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 Hydrocarbon Liquid Loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: AIRS ID Number: I 2 3 /1F-87-/ b1 L( [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: Condensate Loadout [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Taproot Rockies Midstream Site Name: Radicle Gas Plant Site Location: .— S-<(+:..^ I1,7eN, R6r tov Mailing Address: (Include Zip Code) 518 17th Street, Suite 1800 Denver, CO 80202 E -Mail Address2: crial@taprootep.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Chris Rial Phone Number: (713) 481-1864 '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. 378704 Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev 02/2017 1 I •nCOLORADO .°°P..=V„ f6 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑✓ NEW permit OR newly -reported emission source ❑✓ Request coverage under construction permit ❑ Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN Filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment 0 Change company name O Change permit limit 0 Transfer of ownership3 0 Other (describe below) -OR- ❑ APEN submittal for update only (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: Phase I and Phase II Condensate, Slop, and Produced Water Loadout 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: Truck Loadout of Condensate, Slop and Produced Water For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: / / 1/ 1 /2019 Will this equipment be operated in any NAAQS nonattainment area? 0 Yes 0 No Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Does this source load gasoline into transport vehicles? Is this source located at an oil and gas exploration and production site? If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Does this source splash fill less than 6750 BBL of condensate per year? Does this source submerge fill less than 16308 BBL of condensate per year? El Yes El No Yes Yes El El No No ❑ Yes 0 No ❑ Yes 0 No ❑ Yes ❑ No Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 2 I ��' Health. mNInme HeO L O R, l�enmO Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: 0 Condensate ❑ Crude Oil 0 Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded4: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth 413,262 Bbl/yr Actual Volume Loaded: Bbl/yr This product is loaded from tanks at this facility into: (eg, "rail tank cars" or "tank trucks") tank trucks If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: Average temperature of bulk liquid loading: °F True Vapor Pressure Asia ® 60 ° F Molecular weight of displaced vapors Lb/lb mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: Bbl/yr Actual Volume Loaded: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Product Density: Lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume ft3/truckload Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 3 I �bepasfaxv—atalPublic aa�il� 6 ErtWertmertl Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Geographical Information Geographical Coordinates (Latitude/Longitude or 11TM) Lat 40.635991, Lon -104.067383 :Operators Stack 1D No �D-Vha�re� ht:# Above Ground Level �, -;Te p 5 FloRate � (ACFM) :Velocty (f{>secee Condensate Loadgb TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) 0 Upward O Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): O Other (describe): ❑ Upward with obstructing raincap TBD Section 6 - Control Device Information E Loading occurs using a vapor balance system: Requested Control Efficiency 95 % ❑ Combustion Device: Pollutants Controlled: Rating: Type: VOC, HAPs 4.86 Flare Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: MMBtu /hr Make/Model: TBD 95 % Waste Gas Heat Content 3,926,99 Btu/scf Constant Pilot Light: 0 Yes El No Pilot burner Rating MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested 0/0 Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 p COLORADO 4 I L31�'= borpartment �..� Health la Fanovanaratt, PM PM Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Control Equipment Description Overall Requested Control Efficiency (96 reduction in emissions) sox NO„ CO VOC Flare 95 HAPs Flare 95 Other: 0 Using State Emission Factors (Required for GP07) VOC 0 Condensate 0.236 Lbs/BBL 0 Crude 0.104 Lbs/BBL Benzene n -Hexane 0.00041 Lbs/BBL 0.0036 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? 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.) Uncontrolled Emission Factor Emission Factor, Units Emission Factor Source (AP -42, Mfg. etc) Controlled5 (Tons/year) ply nested Annual Permit mission Cimrt(s Uncontrolled (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) SOx NO„ VOC 5.6t°� lb/1,000 gal CDPHE Co 41.16 2.44 Benzene 0.0099 lb/1,000 gal CDPHE 0.09 0.004 Toluene Ethylbenzene Xylenes n -Hexane 0.086 lb/1,000 gal CDPHE 0.75 0.04 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. Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 5 Hea1th6E..m. , t, F` - Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for cover ge under General Permit GP07, I further certify that this source is and will be operated in full compliance with eac ondition of the applicable General Permit. Signature of Legally Au sized Person (not a vendor or consultant) Date Colin Moe Vice President of Commercial Development 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 $152.90 and the General Permit registration fee of $250 as applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-2O8 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 6 COLORADO Depa.nacnea Rd. Hulg14 Ervaaxarrae 6/5/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application STATE OF COLORADO Gruel - CDPHE, Andrew <andrew.gruel@state.co.us> RE: Taproot Radicle Gas Plant Phase I Construction Permit Application Brad Sohm <bsohm@swca.com> Fri, Jun 1, 2018 at 2:08 PM To: "andrew.gruel@state.co.us" <andrew.gruel@state.co.us> Cc: Chris Rial <crial@taprootep.com>, Colin Moe <cmoe@taprootep.com>, Daniel Kennedy <dkennedy@taprootep.com>, Bill Jamieson <bjamieson@swca.com> Andy, We have responded to your questions below in red. Based on your questions, the Promax model has been updated to include 4 ppm of H2S. In addition, please note that Taproot is proposing to replace the facility flare with a thermal oxidizer and add an emergency flare. The thermal oxidizer will control the same streams as the facility flare (truck loading, amine emisisons, dehy demissions), and the emergency flare will be permit -exempt. Thank you, Brad Sohm, P.E. Sr. Air Quality Specialist SWCA Environmental Consultants Email: bsohm@swca.com Toll Free 800.828.8517 www.swca.com Sound Science. Creative Solutions. From: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Sent: Tuesday, May 15, 2018 8:37 AM To: Rebecca Martarella <RMartarella@swca.com> Cc: Brad Sohm <bsohm@swca.com> Subject: Re: Taproot Radicle Gas Plant Phase I Construction Permit Application Hello Rebecca and Brad, https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver—dxVNc9Y02g.en.&cbl=gmail fe_180516.06_p8&view=pt&msg=163bcf71e3aca0a7&search=inbox& 6/5/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application I have completed an initial review of all of the APENs for the Radicle Gas Plant. I appreciate that you have put together a clear and fairly complete application - thank you. Below I have provided my remaining current questions and requests. I will place my review "on hold" until I receive responses to these and the previously emailed questions. 10) Point 006 (Amine) -- The Promax stream name from the flash tank is named "Flash Gas to Reboiler". The APEN and talc sheets state that flash gas will be controlled by a combustion device. Please confirm the destination of flash gas vapors. The Promax model has been updated to show amine flash vapors are routed to the combustion device. The updated flow sheet is attached. 11) Point 006 (Amine) -- please provide Promax model output for the "Flash Gas to Reboiler" stream. The Promax output for this stream is included in the attached "Steam Details" Excel spreadsheet. 12) Point 006 (Amine) -- I'm concerned that H2S is being underestimated in the sour inlet stream (model assumes zero). This impacts 502 emissions. Taproot will be required to account for 502 emissions based on sampling for H2S (assuming a 1:1 molar conversion of H2S to SO2). If actual 502 emissions exceed 2 tpy, then Taproot will have to report it on an APEN. If SO2 exceeds 10 tpy in a year, Taproot will be required to modify the permit to obtain a permit limit. The Promax model has been updated to include 4 ppm of H2S at the inlet. The updated flash and acid gas streams are attached. 13) Point 007 (TEG Dehy) -- What is the source of the input composition that was input to GLYCaIc? Is it the "sweet gas" stream from the Promax model? Yes, the composition of. the sweet gas leaving the amine unit was used as the input composition in GlyCalc. The Glycatc model has been updated with the new sweet gas composition from the updated Promax model and is attached. 14) Point 010 (Flare) -- Is this an enclosed flare, or an open flare? Regulation No. 7 Section XVII requires control of tank vapors and dehy vapors by enclosed flare. Taproot is requesting to authorize two combustion devices. The tank/truck Loading vapors, dehydrator vapors, and amine vent gas wilt be routed to a thermal oxidizer, and an emergency flare will be a stand-alone open flare. The emergency flare will only control unplanned emergency releases that are not proposed to be included in the permit, so this source will be APEN and permit exempt. We have attached the Promax stream summary of the combined vapors being sent to the thermal oxidizer, and the updated calculations and APEN form are attached. 15) Point 010 (Flare) -- how will Taproot demonstrate compliance with process limit? Will they install a gas meter to measure all vapors sent to the flare? or individual gas meters on the vapor lines from each of the different equipment controlled at this flare? This information is required on the CAM Plan, but at first glance it looks like that info isn't on the O&M Plan. (I'll review all of the OEtM Plans once I've verified emissions and regulatory applicability for the whole site). A thermal mass flow meter will be used to measure the combined flow rate to the thermal oxidizer. The composition wilt be obtained from a rate -based composite sampler. 16) Point 010 (Flare) -- Using AP -42 Table 1.4-3, n -hexane is reportable (465 lb/yr). I will need to redline the APEN with your permission. Yes, you may redline the APEN. https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver=-dxVNc9Y02g.en.&cbl=gmail_fe_180516.06_p8&view=pt&msg=163bcf71 e3aca0a7&search=inbox& 6/5/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application 17) Point 014 (Atmospheric loadout) -- you've applied an incorrect number for the state default emission factor for condensate. The correct amount is 5.619 lb/1000gal. This reduces VOC emissions very slightly (48.76 tpy uncontrolled). Please provide permission to redline the APEN. Yes, you may redline the APEN. 18) Point 015 (Fugitives) -- Benzene total has a calculation error. In cell J56 you added "46" rather than a reference to cell J46. Correcting this reduces the uncontrolled benzene total to 501.63 lb/yr. Please grant permission to redline APEN. Yes, you may redline the APEN. 19) Point 015 (Fugitives) -- APEN reports an estirriated 21 pump seals in heavy liquid service. There is no emission factor available for this component in Table 2-4 of the 1995 Protocol. I propose we use the emission factor in Table 2- 2 (0.021 kg/hr/source). With 21 such components, this would increase the VOC total by 8516.81 lb/yr. VOC uncontrolled total would be 129.23 tpy. Please provide your thoughts on this approach and if you agree please provide OK to redline the APEN. We agree with this approach, and you may redline the APEN. Thank You, Andy Gruel, P.E. Oil and Gas Permit Engineer Stationary Sources Program ',COLORADO Air Pollution Control. Division Lac wtii7 otit of I•t:45llc klenItlt b l'i-t'v Cyr,rrtor°tt P 303.692.3143 4300 Cherry Creek Drive South, Denver, CO 80246-1530 andrew.gruel®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. On Thu, May 10, 2018 at 4:57 PM, Andy Gruel - CDPHE <andrew.gruel@state.co.us> wrote: Rebecca and Brad, Here are additional questions for the Radicle Gas Plant application; 3) "Hot Oil Heater A" (Point 009) .• I see the manufacturer's specs for NOx emissions, but I cannot trace the calculation steps to arrive at the model -specific NOx emission factor of 31.737 lb/MMscf. Would you please clarify that emission factor calculation? 4) "Hot Oil Heater A" (Point 009) „ in order to use that model -specific NOx emission factor, Taproot will be required to install that specific make/model of heater. It appears it is Fulton 1200S-LF, please confirm. 5) Gunbarrel tank (Point 011) APEN has requested annual permit limit of 1012.4 bbl/yr which appears to be an error. Calc sheets and narrative specify 369,526 bbl/yr. I will need to redline the APEN with your permission. https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver=-dxVNc9Y02g.en.&cbl=gmail fe_180516.06_p8&view=pt&msg=163bcf71 e3aca0a7&search=inbox& A'. 7 Fugitive Component Leak Emissions APEN - Form APCD-203 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 fugitive component leak emissions. If your emission source does not fall into this category, there may be a different specialty APEN available for your operation (e.g. natural gas venting, condensate tanks, paint booths, 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 specialty APENs is available 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: 10 &/F_-(,-4t-(i-f AIRS ID Number: 23 Mr&74 oiS [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Site Name: Taproot Rockies Midstream Radicle Gas Plant Site Location: Secti -R66W Sex -6 '1, ToN, R.6( MailinTzCddress: 518 (Include Zip Code) 17th Street, Suite 1800 Denver, CO 80202 Permit Contact: Chris Rial E -Mail Address2: crial@taprootep.com Site Location Weld County: NAICS or SIC Code: 213112 Phone Number: (713) 481-1864 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. is Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 COLORADO 1 I . I nrn.nm.marnnic momit Emmimvm AIRS ID Number: / / Permit Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action 2 NEW permit OR newly -reported emission source (check one below) - OR ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change process or equipment ❑ Change company name 0 Add point to existing permit 0 Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - [I APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info & Notes: Phase I and Phase II Fugitive Emissions 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 1/1/2019 ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: Facility Type: ❑ Well Production Facility4 0 Natural Gas Compressor Station4 0 Natural Gas Processing Plant4 ❑ Other (describe): hours/day days/week weeks/year 4 When selecting the facility type, refer to definitions in Colorado Regulation No. 7, Section XVII. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 2I COLORADO Ge,anmenl d Pu4Flc Health 6 Environment ti Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Regulatory Information What is the date that the equipment commenced construction? Will this equipment be operated in any NAAQS nonattainment area?5 ❑✓ Yes 0 No Will this equipment be located at a stationary source that is considered a ❑ Yes ❑✓ No Major Source of Hazardous Air Pollutant (HAP) emissions? Are there wet seal centrifugal compressors or reciprocating compressors ❑✓ Yes ❑ No located at this facility? Is this equipment subject to 40 CFR Part 60, Subpart KKK? 0 Yes ❑✓ No Is this equipment subject to 40 CFR Part 60, Subpart OOOO? ❑ Yes ❑r No Is this equipment subject to 40 CFR Part 60, Subpart OOOOa? 0 Yes 0 No Is this equipment subject to 40 CFR Part 63, Subpart HH? ❑✓ Yes 0 No Is this equipment subject to Colorado Regulation No. 7, Section XII.G? ❑✓ Yes 0 No Is this equipment subject to Colorado Regulation No. 7, Section XVII.F? 0 Yes ❑✓ No Is this equipment subject to Colorado Regulation No. 7, Section XVII.B.3? 0 Yes 0 No 5 See http://www.colorado.Qov/cdphe/state-implementation-plans-sips for which areas are designated as attainment/non- attainment. Section 5 - Stream Constituents ❑✓ The required representative gas and liquid extended analysis (including BTEX) to support the data below has been attached to this APEN form. Use the following table to report the VOC and HAP weight % content of each applicable stream. Stream VOC . (wt %) Benzene (wt %) Toluene (wt %) Ethylbenzene (wt %) Xylene (wt %) n -Hexane (wt %) 4 2'2' Trimethylpentane- ,. (wt %) Gas 25.45 0.01 0.01 0.001 0.002 0.69 0.003 Heavy Oil (or Heavy Liquid) 1 00 0 0 0 0 O 0 Light Oil (or Light Liquid) 97.25 0.13 0.31 0.10 0.28 11.04 0.154 Water/Oil Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 31 CO COLORADO Depattemolothftic Heal. bFnrf.onmeee Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Geographical Information Geographical Coordinates (Latitude/Longitude or UTM) Lat 40.636154, Lon -104.066968 Attach a topographic site map showing location Section 7 - Leak Detection and Repair (LDAR) and Control Information Check the appropriate boxes to identify the LDAR program conducted at this site: 0 LDAR per 40 CFR Part 60, Subpart KKK ❑ Monthly Monitoring - Control: 88% gas valve, 76% light liquid valve, 68% light liquid pump ❑ Quarterly Monitoring - Control: 70% gas valve, 61% light liquid valve, 45% light liquid pump ❑✓ LDAR per 40 CFR Part 60, Subpart OOOO/OOOOa 2 Monthly Monitoring - Control: 96% gas valve, 95% light liquid valve, 88% light liquid pump, 81% connectors ❑ LDAR per Colorado Regulation No. 7, Section XVII.F ❑ Other6: 0 No LDAR Program 6 Attach other supplemental plan to APEN form if needed. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 COLORADO 4 I I . xwina�wicn.mee Count8 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emission Factor Information Select which emission factors were used to estimate emissions below. If none apply, use the table below to identify the emission factors used to estimate emissions. Include the units related to the emission factor. ❑✓ Table 2-4 was used to estimate emissions'. ❑ Table 2-8 (< 10,000ppmv) was used to estimate emissions'. Use the following table to report the component count used to calculate emissions. The component counts listed in the following table are representative of: Estimated Component Count ❑ Actual Component Count conducted on the following date: Equipment Type Connectors .' Flanges Open -Ended Lines Pump Seals 1,244 20 7,500 959 1 0 Emission Factor Units Heavy Oil (or Heavy Liqu Count8 1,171 335 0 21 107 0 Emission Factor Units Light Oil (or Light Liquid) Count8 9,869 1,667 318 13 3,121 3 Emission Factor Units Water/Oil Count8 Emission Factor Units 7 Table 2-4 and Table 2-8 are found in U.S. EPA's 1995 Protocol for Equipment Leak Emission Estimates (Document EPA -453/R- 95-017). 8 The count shall be the actual or estimated number of components in each type of service that is used to calculate the "Actual Calendar Year Emissions" below. 9 The Other equipment type should be applied for any equipment other than connectors, flanges, open-ended lines, pump seals, or valves. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 5I COLORADO orPuwk x1.111,6 Environment Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Criteria and Non -Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions and non -criteria pollutant (HAP) emissions from source: Use the data reported in Section 8 to calculate these emissions. Chemical _Name CAS Number Actual Annual Emissions Requested Annual Permit Emission Limits) Uncontrolled (tons/year) Controlled10 (tons/year) Uncontrolled ;' (tons/year) f Controlledll (tons/year), voc 2y1 Does the emissions source have any actual emissions of individual non -criteria pollutants (e.g. HAP- hazardous air pollutant) emissions equal to or greater than 250 lbs/year? Yes If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Chemical Name CAS Number Actual Annual Emissions 26. of ❑ No Requested Annual Permit Emission Limit(s) Uncontrolled (lbs/year) Controlled9 (lbs/year) Uncontrolled (lbs/year) Controled10 (lbs/year) Benzene 71432 501.6 If 83.09 Toluene 108883 1,095.88 183.41 Ethylbenzene 100414 320.49 54.13 Xylene 1330207 837.90 142.73 n -Hexane 110543 26,470.83 4,637.36 2,2,4 Trimethvloentane Other: 540841 314.33 56.35 70 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. 11 Requested values will become permit limitations. Requested limit(s) should consider future process growth, component count variability, and gas composition variability. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 6I� COLORADO Depument of Public Heat. Enalmeef Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 10 - 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 Colin Moe Vice President of Commercial Development 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 $152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 COLORADO 7 AV'. 6/5/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application STATE OF COLORADO Gruel - CDPHE, Andrew <andrew.gruel@state.co.us> RE: Taproot Radicle Gas Plant Phase I Construction Permit Application Brad Sohm <bsohm@swca.com> To: "andrew.gruel@state.co.us" <andrew.gruel@state.co.us> Cc: Chris Rial <crial@taprootep.com>, Colin Moe <cmoe@taprootep.com>, Daniel Kennedy <dkennedy@taprootep.com>, Bill Jamieson <bjamieson@swca.com> Andy, Fri, Jun 1, 2018 at 2:08 PM We have responded to your questions below in red. Based on your questions, the Promax model has been updated to include 4 ppm of H2S. In addition, please note that Taproot is proposing to replace the facility flare with a thermal oxidizer and add an emergency flare. The thermal oxidizer will control the same streams as the facility flare (truck loading, amine emisisons, dehy demissions), and the emergency flare will be permit -exempt. Thank you, Brad Sohm, P.E. Sr. Air Quality Specialist SWCA Environmental Consultants Email: bsohm@swca.com Toll Free 800.828.8517 www.swca.com Sound Science. Creative Solutions. From: Andy Gruel - CDPHE <andrew.gruel@state.co.us> Sent: Tuesday, May 15, 2018 8:37 AM To: Rebecca Martarella <RMartarella@swca.com> Cc: Brad Sohm <bsohm@swca.com> Subject: Re: Taproot Radicle Gas Plant Phase I Construction Permit Application Hello Rebecca and Brad, https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver=-dxVNc9Y02g.en.&cbl=gmail fe_180516.06_ps&view=pt&msg=163bcf71e3aca0a7&search=inbox& 6/5/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I Construction Permit Application I have completed an initial review of all of the APENs for the Radicle Gas Plant. I appreciate that you have put together a clear and fairly complete application - thank you. Below I have provided my remaining current questions and requests. I will place my review "on hold" until I receive responses to these and the previously emailed questions. 10) Point 006 (Amine) -- The Promax stream name from the flash tank is named "Flash Gas to Reboiler". The APEN and calc sheets state that flash gas will be controlled by a combustion device. Please confirm the destination of flash gas vapors. The Promax model has been updated to show amine flash vapors are routed to the combustion device. The updated flow sheet is attached. 11) Point 006 (Amine) -- please provide Promax model output for the "Flash Gas to Reboiler" stream. The Promax output for this stream is included in the attached "Steam Details" Excel spreadsheet. 12) Point 006 (Amine) -- I'm concerned that H2S is being underestimated in the sour inlet stream (model assumes zero). This impacts 502 emissions. Taproot will be required to account for SO2 emissions based on sampling for H2S (assuming a 1:1 molar conversion of H2S to 502). If actual SO2 emissions exceed 2 tpy, then Taproot will have to report it on an APEN. If 502 exceeds 10 tpy in a year, Taproot will be required to modify the permit to obtain a permit limit. The Promax model has been updated to include 4 ppm of H2S at the inlet. The updated flash and acid gas streams are attached. 13) Point 007 (TEG Dehy) -- What is the source of the input composition that was input to GLYCaIc? Is it the "sweet gas" stream from the Promax model? Yes, the composition of the sweet gas leaving the amine unit was used as the input composition in GlyCalc. The GlyCalc model has been updated with the new sweet gas composition from the updated Promax model and is attached. 14) Point 010 (Flare) -- Is this an enclosed flare, or an open flare? Regulation No. 7 Section M/II requires control of tank vapors and dehy vapors by enclosed flare. Taproot is requesting to authorize two combustion devices. The tank/truck loading vapors, dehydrator vapors, and amine vent gas will be routed to a thermal oxidizer, and an emergency flare will be a stand-alone open flare. The emergency flare will only control unplanned emergency releases that are not proposed to be included in the permit, so this source will be APEN and permit exempt. We have attached the Promax stream summary of the combined vapors being sent to the thermal oxidizer, and the updated calculations and APEN form are attached. 15) Point 010 (Flare) -- how will Taproot demonstrate compliance with process limit? Will they install a gas meter to measure all vapors sent to the flare? or individual gas meters on the vapor lines from each of the different equipment controlled at this flare? This information is required on the 0&M Plan, but at first glance it looks like that info isn't on the OaM Plan. (I'll review all of the O&M Plans once I've verified emissions and regulatory applicability for the whole site). A thermal mass flow meter will be used to measure the combined flow rate to the thermal oxidizer. The composition will be obtained from a rate -based composite sampler. 16) Point 010 (Flare) -- Using AP -42 Table 1.4-3, n -hexane is reportable (465 lb/yr). I will need to redline the APEN with your permission. Yes, you may redline the APEN. https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver=-dxVNc9Y02g.en.&cbl=gmail_fe_180516.06_p8&view=pt&msg=163bcf71 e3aca0a7&search=inbox8 6/5/2018 State.co.us Executive Branch Mail - RE: Taproot Radicle Gas Plant Phase I uonstrucuon Permit Hppucation 17) Point 014 (Atmospheric loadout) -- you've applied an incorrect number for the state default emission factor for condensate. The correct amount is 5.619 lb/1000gal. This reduces VOC emissions very slightly (48.76 tpy uncontrolled). Please provide permission to redline the APEN. Yes, you may redline the APEN. 18) Point 015 (Fugitives) -- Benzene total has a calculation error. In cell J56 you added "46" rather than a reference to cell J46. Correcting this reduces the uncontrolled benzene total to 501.63 lb/yr. Please grant permission to redline APEN. Yes, you may redline the APEN. 19) Point 015 (Fugitives) -- APEN reports an estimated 21 pump seals in heavy liquid service. There is no emission factor available for this component in Table 2-4 of the 1995 Protocol. I propose we use the emission factor in Table 2- 2 (0.021 kg/hr/source). With 21 such components, this would increase the VOC total by 8516.81 lb/yr. VOC uncontrolled total would be 129.23 tpy. Please provide your thoughts on this approach and if you agree please provide OK to redline the APEN. We agree with this approach, and you may redline the APEN. Thank You, Andy Gruel, P.E. Oil and Gas Permit Engineer Stationary Sources Program COLORADO Air Pollution Control Division L,e nartmerit of Public Heer lth i, Errv)ronr17ent P 303.692.3143 4300 Cherry Creek Drive South, Denver, CO 80246-1530 andrew.gruel@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. On Thu, May 10, 2018 at 4:57 PM, Andy Gruel - CDPHE <andrew.gruel@state.co.usa wrote: Rebecca and Brad, Here are additional questions for the Radicle Gas Plant application: 3) "Hot Oil Heater A" (Point 009) -- I see the manufacturer's specs for NOx emissions, but I cannot trace the calculation steps to arrive at the model -specific NOx emission factor of 31.737 lb/MMscf. Would you please clarify that emission factor calculation? 4) "Hot Oil Heater A" (Point 009) -- in order to use that model -specific NOx emission factor, Taproot will be required to install that specific make/model of heater, It appears it is Fulton 1200S-LF, please confirm, 5) Gunbarrel tank (Point 011) APEN has requested annual permit limit of 1012.4 bbl/yr which appears to be an error. Catc sheets and narrative specify 369,526 bbl/yr, I will need to redline the APEN with your permission. https://mail.google.com/mail/u/0/?ui=2&ik=9030c1528b&jsver=-dxVNc9Y02g.en.&cbl=gmail fe_180516.06_p8&view=pt&msg=163bcf71e3aca0a7&search=inbox& Natural Gas Venting APEN - Form APCD-211 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 Natural Gas Venting only. Natural 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. 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: iI36vE 0944 AIRS ID Number: 12 3 /9F87/ O /b [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: Phase I CB [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Site Name: Site Location: Taproot Rockies Midstream Radicle Gas Plant Phase Sect octl'n 26 Pi; -R6 — kG 'c41.-,. I(, i8A! R6(w wolf e Mailing Address: (Include Zip Code) 518 17th Street, Suite 1800 Denver, CO 80202 E -Mail Address'-: crial@taprootep.com Site Location County: Weld NAICS or SIC Code: 213112 Permit Contact: Chris Rial Phone Number: (713) 481-1864 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that wilt appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-211 - Natural Gas Venting APEN - Rev 03/2017 378706 COLORADO OspaHaS End c Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ✓❑ NEW permit OR newly -reported emission source - OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit 0 Change permit Limit El Transfer of ownership3 ❑ Other (describe below) - OR • APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: Phase I Only Compressor Blowdowns 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: Compressors) Compressor Blowdowns (Total for 5 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: / / 1 / 1 / 2019 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: 24 hours/day 7 days/week 52 weeks/year Will this equipment be operated in any NAAQS nonattainment area Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 O Yes ❑ Yes ❑ No 2 No 2' a Hu. Erkylromeenu COLORADO Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: Serial #: # of Pistons: Capacity: Gal/min Leak Rate: Scf/hr/pist ❑✓ Blowdown Events # of Events/year: 24 per com scot Volum- • - event: 0.0042 per compressor MMscf/event ❑ Other IL O - -M P, yer^e" Description: / If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑ Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑ No Maximum Vent Rate: SCF/hr Vent Gas Heating Value: BTU/SCF Requested: MMSCF/year Actual: MMSCF/year -OR- Requested: Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limits) should consider future process growth Process Properties: Molecular Weight: VOC (mole %) VOC (Weight %) Benzene (mole %) Benzene (Weight %) Toluene (mole %) Toluene (Weight %) Ethylbenzene (mole %) Ethylbenzene (Weight %) Xylene (mole %) Xylene (Weight %) n -Hexane (mole %) n -Hexane (Weight %) 2,2,4-Trimethylpentane (mole %) 2,2,4-Trimethylpentane (Weight %) Additional Required Information: ❑ Attach a representative gas analysis (including BTEX £t n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 COLORADO xwmsr;monm.H Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) Lat 40.636290, Lon -104.066873 Operator Stack ID No Discharge Height x Above Ground Level Feet Temper, :F ( 1 a FIowARate ACFM r ( ) Velocity t/sec (f ) CB TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑r Upward 0 Horizontal ❑ Downward 0 Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): ❑ Other (describe): 0 Upward with obstructing raincap TBD Section 6 - Control Device Information O VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency % VRU Downtime or Bypassed ❑ Combustion Device: Pollutants Controlled: Rating: Type: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: MMBtu /hr Make/Model: Waste Gas Heat Content Constant Pilot Light: 0 Yes 0 No Pilot burner Rating Btu/scf MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested 070 Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 4I� COLORADO Departenermatrduc HMtIh6Ehvfannant PM Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit #t 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? O Yes O No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Overall Requested Control Efficiency (% reduction in emissions) Control Equipment Description SO. NO. VOC CO HAPs Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: Pollutant Uncontrolled Emission _ Factor, Emission ' F actor Units '' Emission Factor Source (AP -42, Mfg. etc) � � � Actuaa Annual "�� Emissions _... Requested Annual •Emission Limns u erg Permit s � Uncontrolled (Tons/year) .. Controlled6 (Tons/year) Uncontrolled (Tons/year). Controlled (Tons/year) PM SOx NOx VOC 39.26 lb/event Eng. Estimate 2.36 2.36 CO Benzene 0.02 lb/event Eng. Estimate 0.0013 0.0013 Toluene 0.02 lb/event Eng. Estimate 0.0010 0.0010 Ethylbenzene 0.002 lb/event Eng. Estimate 0.0001 0.0001 Xylenes 0.005 lb/event Eng. Estimate 0.0003 0.0003 n -Hexane 1'.60 lb/event Eng. Estimate 0.096 0.096 2,2,4- Trimethylpentane 0.0061 lb/event Eng. Estimate 0.0004 0.0004 Other: 5 Requested values will become permit limitations. Requested limits) should consider future process growth. 6Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 {COLORADO xeieasen-.,t Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. L f/i—e7 -a /Y Signature of Legally Autrized Person (not a vendor or consultant) Date Colin Moe Vice President of Commercial Development Name (please print) Title Check the appropriate box to request a copy of the: O Draft permit prior to issuance ✓❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd ;COLORADO 61�V Natural Gas Venting APEN - Form APCD-211 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 Natural Gas Venting only. Natural 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. 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: I gwFoLP-19 AIRS ID Number: 1 21 /9F g7-/ 017_ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: Phase I RP [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Taproot Rockies Midstream Site Name: Radicle Gas Plant Phase Site Location: s 4-6 1i(* ha Site Location n iN. _R6QW County: Weld Stogy;,. II, T e N 2 c vo Mailing Address: (Include Zip Code) 518 17th Street, Suite 1800 Denver, CO 80202 E -Mail Address'-: crial@taprootep.com NAICS or SIC Code: 213112 Permit Contact: Chris Rial Phone Number: (713) 481-1864 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-211 - Natural Gas Venting APEN - Rev 03/2017 378707 Co c' 'COLORADO n.wem.ew weuc Heahbb Emus... Permit Number: AIRS ID Number: [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 0 Change company name 0 Add point to existing permit ❑ Change permit limit 0 Transfer of ownership' D Other (describe below) OR - APEN submittal for update only (Please 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: Phase I Compressor Rod Packing 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: Compressors) Compressor Rod Packing (Total for 5 For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: I / 1 / 1 / 2019 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: 24 hours/day Will this equipment be operated in any NAAQS nonattainment area Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions 7 days/week 52 0 Yes 0 Yes weeks/year ❑ No 0 No Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 2 I COLORADO Departmoril e&, per Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: 0 Compressor Rod Packing Make: Ariel ❑ Blowdown Events # of Events/year: D Other Description: Model: JGT/4 Serial #: # of Pistons: Volume per event: Capacity: Gal/min Leak Rate: 50 scf/compressor Scf/hr/pist st MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑ Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: 0 No Maximum Vent Rate: SCF/hr Vent Gas Heating Value: BTU/SCF Requested: MMSCF/year Actual: MMSCF/year -OR- Requested: Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Process Properties: Molecular Weight: VOC (mole %) VOC (Weight %) Benzene (mole %) Benzene (Weight %) Toluene (mole %) Toluene (Weight %) Ethylbenzene (mote %) Ethylbenzene (Weight %) Xytene (mole %) Xylene (Weight %) n -Hexane (mole %) n -Hexane (Weight %) 2,2,4-Trimethylpentane (mole %) 2,2,4-Trimethylpentane (Weight %) Additional Required Information: ❑ Attach a representative gas analysis (including BTEX £t n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX a n -Hexane, temperature, and pressure) Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 (COLORADO 3 t: Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) =' Lat 40.636290, Lon -104.066873 Operator Stack ID No kt � Discharge Height ,.,r . Above Ground Level > Tempi F) P� Flow Rate (ACFM) g r. �.e 1 Velocity a fft/sec) �&, RP TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) O Upward 0 Horizontal 0 Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): ❑ Other (describe): 0 Upward with obstructing raincap TBD Section 6 - Control Device Information O VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency % VRU Downtime or Bypassed ❑ Combustion Device: Pollutants Controlled: Rating: Type: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: MMBtu/hr Make/Model: Waste Gas Heat Content Constant Pilot Light: 0 Yes ❑ No Pilot burner Rating Btu/scf MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested 0/0 Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 COLORADO n�e.ro�coir rw xesnrtr. r,.mmmeec t= PM Permit Number: AIRS ID Number: ! / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑ Yes ✓❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) SOX NOX VOC CO HAPs Other: From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: Pollutant Uncontrolled , ..Emission Factor' Emission ' Factor _ Units Emission Factor Source (AP -42, Mfg. etc) . s..„4„, Actual AnnualEmissionsr: u� -,,,..*„..._ n Re Requested Annual Permit 9= mission-Ltmrt(s)� t ...„ Uncontrolled (Tons/year) Controlled6 (Tons/year) Uncontrolled (Tons/year),. Controlled (Tons/year)'s. PM SOX NOX VOC 9,347.41 lb/MMscf Eng. Estimate 10.24 10.24 CO Benzene 5.02 lb/MMscf Eng. Estimate 0.0055 0.0055 Toluene 4.03 lb/MMscf Eng. Estimate 0.0044 0.0044 Ethylbenzene 0.47 lb/MMscf Eng. Estimate 0.0005 0.0005 Xylenes 1.12 lb/MMscf Eng. Estimate 0.0012 0.0012 n -Hexane 380.41 Ib/MMscf Eng. Estimate 0.417 0.417 2,2,4-1.45 Trimethyipentane ytp lb/MMscf Eng.Estimate 0.0016 0.0016 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 COLORADO 5 I I � U f HeO L O R4onm O Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Legally Authorized Person (not a vendor or consultant) Date Colin Moe Vice President of Commercial Development Name (please print) Title Check the appropriate box to request a copy of the: O Draft permit prior to issuance ❑� Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 43OO Cherry Creek Drive South Denver, CO 8O246 -153O Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 6 I ;COLORADO DepstHeats a.3Ra bic NURIf 6 EnKMImut Hello