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Home My WebLink About20190093.tiffCOLORADO Department of Public Health Et Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 11500 St PO Box 758 Greeley, CO 80632 December 19, 2018 Dear Sir or Madam: RECEIVED DEC 2 1 2018 WELD COUNTY COMMISSIONERS On December 20, 2018, the Air Pollution Control Division will begin a 30 -day public notice period for REP Processing, LLC - Pierce Gas Processing Plant. 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 1/2/Iq 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 CC.PUT PtHL(,S 1, 12121118 2019-0093 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: REP Processing, LLC - Pierce Gas Processing Plant - Weld County Notice Period Begins: December 20, 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: REP Processing, LLC Facility: Pierce Gas Processing Plant Natural Gas Processing Plant SW SEC 21 T8N R66W Weld County The proposed project or activity is as follows: New natural gas processing plant 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 18WE0777 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. Comments may be submitted using the following options: • Use the web form at https://www.colorado.Qov/pacific/cdphe/air-permit-public-notices. This page also includes guidance for public participation • Send an email to cdphe.commentsapcd@state.co.us • Send comments to our mailing address: Timothy Sharp Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 Summary of Preliminary Analysis - NG RICE Company Name REP Processing, LLC Facility Name Facility Location SW SEC21 T8N R66W Facility Equipment ID C-1 thru C-6 Pierce Gas Processing Plant Permit No. AIRS Review Date Permit Engineer 18WE0777 123/9fdb/003-008 09/01/2018 Timothy Sharp Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) Waukesha, Model L7044 GSI S5, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1897 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control This emission unit is used for natural gas compression. Natural Gas Consumption Requested (mmscf/yr) 117.00 Requested (mmscf/m) 9.94 Fuel Heat Value (btu/scf) 1020 BSCF (Btu/hp-hr) 7158 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) Permit limits calculated at (hpy) 8760 8760 Uncontrolled Controlled NOx 0 0 VOC 0 0 CO 0 0 Formaldehyde 0.00 0 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 Describe EF sources - HAPs etc. Describe EF sources - HAPs, etc. Point Summary of Criteria Emissions (t Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency NOx 212.8 5.5 212.8 97.4% VOC 1.3 1.3 1.3 0.0% CO 182.7 7.4 182.7 96.0% SOx 0.0 0.0 0.0 0.0% TSP 1.2 1.2 1.2 0.0% PM 10 1.2 1.2 1.2 0.0% PM2.5 1.2 1.2 1.2 0.0% Total HAPs* 0.0 0.0 1.7 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 HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 1941 1941 1941 0.0% Methanol 365 365 365 0.0% Acetaldehyde 333 333 333 0.0% Acrolein 314 314 314 0.0% Benzene * 189 0.0% 1,3 -Butadiene 79 0.0% Toluene 67 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minim us Permitting Requirements Ambient Air Impacts No NAAQS violations expected (see details of modeling analysis) Public Comment Public Comment Required MACT 7777 #VALUE! 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 requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes Part of FW permit 18W0777 for Pierce Gas Plant. Points (003-008) are same engine model/specification. Preliminary Analysis: RICE Emission Calculations - NG RICE Company Name REP Processing, LLC Permit No. 18WE0777 AIRS 123/9fdb/003-008 Engine Type 4SRB Throughputs MMBtu/yr MMscf/yr Requested Fuel Consumption (MMBtu/yr) 119340 117 Max Potential Fuel Consumption (MMBtu/yr) 119340 117 Actual Fuel Consumption (MMBtu/yr) Emissions (tDv) - Criteria PM10 PM2.5 TSP SO2 NOx VOC CO Uncontrolled Requested Emissions 1.2 1.2 1.2 0.0 212.8 1.3 182.7 Controlled Requested Emissions 1.2 1.2 1.2 0.0 5.5 1.3 7.4 PTE 1.2 1.2 1.2 0.0 212.8 1.3 182.7 Uncontrolled Actual Emissions Controlled Actual Emissions Emission Factors - Criteria PM10 PM2.5 TSP SO2 NOx VOC CO lb/MMBtu - Uncontrolled 0.019 0.019 0.019 0.001 3.567 0.021 3.061 lb/MMBtu - Controlled 0.019 0.019 0.019 0.001 0.092 0.021 0.123 % Control 0.0 0.0 0.0 0.0 97.4% 0.0% 96.0% Emission Factor Sources/Notes: Controlled Uncontrolled PM10 No Control AP -42; Table 3.2-3 (7/2000); Natur SO2 No Control AP -42; Table 3.2-3 (7/2000); Natur NOx 0 0 VOC 0 0 CO 0 0 PM2.5 No Control AP -42; Table 3.2-3 (7/2000); Natur TSP No Control AP -42; Table 3.2-3 (7/2000); Natur Printed 12/18/2018 Colorado Department of Public Health Envrionment Air Pollution Control Division Page 3 of 10 Preliminary Analysis: RICE Emission Calculations Company Name REP Processing, LLC Permit No. 18WE0777 AIRS 123/9fdb/003-008 Emissions - NCRPs Colorado Department of Public Health Envrionment Air Pollution Control Division Pollutant Formaldehyde Methanol Acetaldehyde Acrolein Benzene 1,3 -Butadiene Toluene Xylene PAH Naphthalene 91203 B 11.6 11.6 11.6 Methylene Chloride 75092 A 4.9 4.9 4.9 1,1,2,2-Tetrachloroethane 79345 A 3.0 3.0 3.0 Ethylbenzene 100414 C 3.0 3.0 3.0 Ethylene Dibromide . 106934 A 2.5 2.5 2.5 Carbon Tetrachloride 56235 A 2.1 2.1 2.1 1,1,2-Trichloroethane 79005 A 1.8 1.8 1.8 Chloroform 67663 A 1.6 1.6 1.6 Chlorobenzene 108907 A 1.5 1.5 1.5 1,3-Dichloropropene 542756 A 1.5 1.5 1.5 Styrene 100425 C 1.4 1.4 1.4 1,1-Dichloroethane 75343 B 1.3 1.3 1.3 Vinyl Chloride 75014 A 0.9 0.9 0.9 2-Methylnaphthalene 91576 0 0.0 0.0 0.0 2,2,4-Trimethylpentane 540841 C 0.0 0.0 6.6 Acenaphthene 0 0 0.0 0.0 0.0 Acenaphthylene 0 0 0.0 0.0 0.0 Anthracene 0 0 0.0 0.0 0.0 Benz(a)anthracene 0 0 0.0 0.0 0.0 Benzo(a)pyrene 0 0 0.0 0.0 0.0 Benzo(b)fluoranthene 0 0 0.0 0.0 0.0 Benzo(e)pyrene 0 0 0.0 0.0 0.0 Benzo(g,h,i)perylene 0 0 0.0 0.0 0.0 Benzo(k)fluoranthene 0 0 0.0 0.0 0.0 Biphenyl 92524 C 0.0 0.0 0.0 Chrysene 0 0 0.0 0.0 0.0 Fluoranthene 0 0 0.0 0.0 0.0 Fluorene 7782414 C 0.0 0.0 0.0 Indeno(1,2,3-c,d)pyrene 0 0 0.0 0.0 0.0 n -Hexane 110543 C 0.0 0.0 0.0 CAS BIN Requested Controlled lb/yr 50000 A 1940.7 67561 C Uncontrolled lb/yr PTE lb/yr 1940.7 1940.7 365.2 365.2 365.2 75070 A 333.0 107028 A 313.9 71432 A 188.6 106990 A 79.1 108883 C 66.6 1330207 C 23.3 333.0 333.0 313.9 313.9 188.6 188.6 79.1 79.1 66.6 66.6 23.3 23.3 0 0 16.8 16.8 16.8 Printed 12/18/2018 Ac Controlled lb/yr tual Uncontrolled lb/yr Cont. Req. actual>Rep lb/yr 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 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 0.0 0.0 0.0 PTE >Reportable lb/yr 1940.7 365.2 333.0 313.9 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 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 Unc. Request actual>Rep lb/yr 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 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 0.0 0.0 0.0 Page 4 of 10 Preliminary Analysis: RICE Emission Calculations Company Name Permit No. AIRS REP Processing, LLC 18WE0777 123/9fdb/003-008 Emission Factors - NCRPs Colorado Department of Public Health Envrionment Air Pollution Control Division Pollutant CAS Controlled Uncontrolled Emission Factor lb/MMBtu Ig/bhp-hr % Control Notes Emission Factor Ib/MMBtu Ig/bhp-hr Notes Formaldehyde Methanol 50000 .016262072 0.0528 0.0% 0 0.02 0.0528 0.00 Acetaldehyde Acrolein Benzene 1,3 -Butadiene Toluene Xylene PAH Naphthalene Methylene Chloride 1,1, 2, 2-Tetrachloroethane Ethylbenzene Ethylene Dibromide Carbon Tetrachloride 1,1,2-Trichloroethane Chloroform Chlorobenzene 1, 3-Dichloropropene Styrene 1,1-Dichloroethane Vinyl Chloride 2-Methylnaphthalene 2, 2, 4-Tri methy l penta ne Acenaphthene Acenaphthylene Anthracene Benz(a)anthracene Benzo(a)pyrene Benzo(b)fluoranthene Benzo(e)pyrene Benzo(g,h,i)perylene Benzo(k)fluoranthene Biphenyl Chrysene Fluoranthene Fluorene I n d en o(1, 2, 3-c, d)py rene n -Hexane 0 0.00306 0.009935265 0.0% No Control 0.00306 0.00994 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.00279 0.009058624 0.0% No Control 0.00279 0.00906 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.00263 0.008539133 0.0% No Control 0.00263 0.00854 AP -42; Table 3.2-3 (7/2000); Natural Gas 0.00158 0.00513 AP -42; Table 3.2-3 (7/2000); Natural Gas 0.000663 0.00215 AP -42; Table 3.2-3 (7/2000); Natural G.as 0 0.000558 0.001811725 0.0% No Control 0.000558 0.00181 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.000195 0.00063313 0.0% No Control 0.000195 0.00063 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.000141 0.000457801 0.0% No Control 0.000141 0.00046 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000971 0.000315266 0.0% No Control 9.71E-05 0.00032 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000412 0.000133769 0.0% No Control 4.12E-05 0.00013 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000253 8.21445E-05 0.0% No Control 2.53E-05 8.2E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000248 8.05211E-05 0.0% No Control 2.48E-05 8.1E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000213 6.91572E-05 0.0% No Control 2.13E-05 6.9E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000177 5.74687E-05 0.0% No Control 1.77E-05 5.7E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000153 4.96763E-05 0.0% No Control 1.53E-05 5E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000137 4.44814E-05 0.0% No Control 1.37E-05 4.4E-05 AP -42; Table 3.2.3 (7/2000); Natural Gas 0 0.0000129 4.1884E-05 0.0% No Control 1.29E-05 4.2E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000127 4.12346E-05 0.0% No Control 1.27E-05 4.1E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000119 3.86371E-05 0.0% No Control 1.19E-05 3.9E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000113 3.66891E-05 0.0% No Control 1.13E-05 3.7E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.00000718 2.33122E-05 0.0% No Control 7.18E-06 2.3E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/20P0); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.00158 0.005129974 0.0% No Control 0 0.000663 0.002152641 0.0% No Control • Printed 12/18/2018 Page 5 of 10 Natural Gas -Fired Reciprocating Internal Combustion Engines Emission Factors - 4SRB 1 Uncontrolled Uncontrolled Controlled Controlled AP -42 Value Used Value Used - comments Value Used Value used - comments Table 3.2-3 (7/2000) (lb/MMBtu) (lb/MMBtu) Natural Gas Pollutant CAS BIN lb/MMBtu NOx 3.57 0 0.092398137 0 2.21 CO 3.06 0 0.123197517 0 3.72 VOC 0.02 0 0.021189973 0 2.96E-02 Formaldehyde 50000 A 0.02 0 0.016262072 0 2.05E-02 SO2 0.000588 AP -42; Table 3.2-3 (7/2000); 0.000588 No Control 5.88E-04 PM10 0.01941 AP -42; Table 3.2-3 (7/2000); 0.01941 No Control 0.01941 PM2.5 0.01941 AP -42; Table 3.2-3 (7/2000); 0.01941 No Control 0.01941 TSP 0.01941 AP -42; Table 3.2-3 (7/2000); 0.01941 No Control 0.01941 1,1,2,2-Tetrachloroethane 79345 A 0.0000253 AP -42; Table 3.2-3 (7/2000); 0.0000253 No Control 2.53E-05 1,1,2-Trichloroethane 79005 A 0.0000153 AP -42; Table 3.2-3 (7/2000); 0.0000153 No Control 1.53E-05 1,1-Dichloroethane 75343 B 0.0000113 AP -42; Table 3.2-3 (7/2000); 0.0000113 No Control 1.13E-05 1,3 -Butadiene . 106990 A 0.000663 AP -42; Table 3.2-3 (7/2000); 0.000663 No Control 6.63E-04 1,3-Dichloropropene 542756 A 0.0000127 AP -42; Table 3.2-3 (7/2000); 0.0000127 No Control 1.27E-05 2-Methylnaphthalene 91576 AP -42; Table 3.2-3 (7/2000); 0 No Control 2,2,4-Trimethylpentane 540841 C AP -42; Table 3.2-3 (7/2000); 0 No Control Acenaphthene AP -42; Table 3.2-3 (7/2000); 0 No Control Acenaphthylene AP -42; Table 3.2-3 (7/2000); 0 No Control Acetaldehyde 75070 A 2.79E-03 AP -42; Table 3.2-3 (7/2000); 0.00279 No Control 2.79E-03 Acrolein 107028 A 0.00263 AP -42; Table 3.2-3 (7/2000); 0.00263 No Control 2.63E-03 Anthracene AP -42; Table 3.2-3 (7/2000); 0 No Control Benz(a)anthracene AP -42; Table 3.2-3 (7/2000); 0 No Control Benzene 71432 A 1.58E-03 AP -42; Table 3.2-3 (7/2000); 0.00158 No Control 1.58E-03 Benzo(a)pyrene AP -42; Table. 3.2-3 (7/2000); 0 No Control Benzo(b)fluoranthene AP -42; Table 3.2-3 (7/2000); 0 No Control Benzo(e)pyrene AP -42; Table 3.2-3 (7/2000); 0 No Control Benzo(g;h,i)perylene AP -42; Table 3.2-3 (7/2000); 0 No Control Benzo(k)fluoranthene AP -42; Table 3.2-3 (7/2000); 0 No Control Biphenyl 92524 C AP -42; Table 3.2-3 (7/2000); 0 No Control Carbon Tetrachloride 56235 A 0.0000177 AP -42; Table 3.2-3 (7/2000); 0.0000177 No Control 1.77E-05 Chlorobenzene 108907 A 0.0000129 AP -42; Table 3.2-3 (7/2000); 0.0000129 No Control 1.29E-05 Chloroform 67663 A 0.0000137 AP -42; Table 3.2-3 (7/2000); 0.0000137 No Control 1.37E-05 Chrysene AP -42; Table 3.2-3 (7/2000); 0 No Control Ethylbenzene 100414 C 0.0000248 AP -42; Table 3.2-3 (7/2000); 0.0000248 No Control 2.48E-05 Ethylene Dibromide 106934 A 0.0000213 AP -42; Table 3.2-3 (7/2000); 0.0000213 No Control 2.13E-05 Fluoranthene AP -42; Table 3.2-3 (7/2000); 0 No Control Page 6 of 10 Printed 12/18/2018 Natural Gas -Fired Reciprocating Internal Combustion Engines Emission Factors - 4SRB 1 Uncontrolled Uncontrolled Controlled Controlled AP -42 Value Used Value Used - comments Value Used Value used - comments Table 3.2-3 (7/2000) (lb/MMBtu) (lb/MMBtu) Natural Gas Pollutant CAS BIN lb/MMBtu Fluorene 7782414 C AP -42; Table 3.2-3 (7/2000); 0 No Control Indeno(1,2,3-c,d)pyrene AP -42; Table 3.2-3 (7/2000); 0 No Control Methanol 67561 C 0.00306 AP -42; Table 3.2-3 (7/2000); 0.00306 No Control 3.06E-03 Methylene Chloride 75092 A 0.0000412 AP -42; Table 3.2-3 (7/2000); 0.0000412 No Control 4.12E-05 n -Hexane 110543 C AP -42; Table 3.2-3 (7/2000); 0 No Control Naphthalene 91203 B 0.0000971 AP -42; Table 3.2-3 (7/2000); 0.0000971 No Control 9.71 E-05 PAH 0.000141 AP -42; Table 3.2-3 (7/2000); 0.000141 No Control 1.41 E-04 Phenanthrene AP -42; Table 3.2-3 (7/2000); 0 No Control Phenol 108952 C AP -42; Table 3.2-3 (7/2000); 0 No Control Pyrene AP -42; Table 3.2-3 (7/2000); 0 No Control Styrene 100425 C 0.0000119 AP -42; Table 3.2-3 (7/2000); 0.0000119 No Control 1.19E-05 Tetrachloroethane 79345 A AP -42; Table 3.2-3 (7/2000); 0 No Control Toluene 108883 C 0.000558 AP -42; Table 3.2-3 (7/2000); 0.000558 No Control 5.58E-04 Vinyl Chloride 75014 A 0.00000718 AP -42; Table 3.2-3 (7/2000); 0.00000718 No Control 7.18E-06 Xylene 1330207 C 0.000195 AP -42; Table 3.2-3 (7/2000); 0.000195 No Control 1.95E-04 Page 7 of 10 Printed 12/18/2018 Natural Gas -Fired Reciprocating Internal Combustion Engines Emission Factors - 4SRB 2 3 4 5 GRI HAPCalc 3.0 GRI HAPCalc 3.0 ` GRI HAPCalc 3.0 GRI HAPCaIc 3.0 Literature Literature Test Data Test Data Natural Gas Field Gas Natural Gas Field Gas Pollutant CAS BIN g/bhp-hr g/bhp-hr g/bhp-hr g/bhp-hr NOx 18.3 7.53 CO 14.5 9.08 VOC 0.264 Formaldehyde 50000 A 0.0623 0.0381 0.0994 0.0418 SO2 PM10 PM2.5 TSP 1,1,2,2-Tetrachloroethane 79345 A , 1,1,2-Trichloroethane 79005 A 1,1-Dichloroethane 75343 B 1,3 -Butadiene 106990 A 1,3-Dichloropropene 542756 A 2-Methylnaphthalene 91576 5.05E-05 2,2,4-Trimethylpentane 540841 C Acenaphthene 1.09E-05 Acenaphthylene 1.89E-05 Acetaldehyde 75070 A 0.0039 Acrolein 107028 A 0.0034 Anthracene 4.00E-06 Benz(a)anthracene 1.80E-06 Benzene 71432 A 0.0046 0.0221 0.0221 Benzo(a)pyrene 4.00E-07 Benzo(b)fluoranthene 2.20E-06 Benzo(e)pyrene Benzo(g,h,i)perylene 7.00E-07 Benzo(k)fluoranthene 2.20E-06 Biphenyl 92524 C Carbon Tetrachloride 56235 A Chlorobenzene 108907 A Chloroform 67663 A Chrysene 2.20E-06 Ethylbenzene 100414 C Ethylene Dibromide 106934 A Fluoranthene 1.26E-05 Page 8 of 10 Printed 12/18/2018 Natural Gas -Fired Reciprocating Internal Combustion Engines Emission Factors - 4SRB 2 3 4 5 GRI HAPCaIc 3.0 GRI HAPCaIc 3.0 GRI HAPCalc 3.0 GRI HAPCalc 3.0 Literature Literature Test Data Test Data Natural Gas Field Gas Natural Gas Field Gas Pollutant CAS BIN g/bhp-hr g/bhp-hr g/bhp-hr g/bhp-hr Fluorene 7782414 C 1.72E-05 Indeno(1,2,3-c,d)pyrene 5.00E-07 Methanol 67561 C 0.02 0.00667 Methylene Chloride 75092 A n -Hexane 110543 C Naphthalene 91203 B 2.75E-04 PAH Phenanthrene 3.21 E-05 Phenol 108952 C Pyrene . 8.60E-06 Styrene 100425 C Tetrachloroethane 79345 A Toluene 108883 C 0.002 0.007 7.10E-03 Vinyl Chloride 75014 A Xylene 1330207 C 0.0014 0.0017 1.70E-03 Page 9 of 10 Printed 12/18/2018 COLORADO DEPARTMENT OF PUBLIC HEALTH ENVIRONMENT AIR POLUTION CONTROL DIVISION INVENTORY AIRS (County/Plant) 123/9fdb/003-008 Permit No. 18WE0777 Date 9/1/2018 Engine Type 4SRB Point # Seg * SCC Pollutant or CAS Fug Dust Uncontrolled Emission Factor Emisison Factor Source Controlled Actual Emissions (tpy)* Controlled Requested Emissions (tpy)* PTE (tpy)* Ctrl. Eff% NCRP = reportable ? 003-008 2-02-002-53 NOx n 3637.9 lb/MMscf 0 5.5 212.8 97% CO n 3122.69 Ib/MMscf 0 7.4 182.7 96% VOC n 21.6138 Ib/MMscf 0 1.3 1.3 0% 50000 Formaldehyde n 16.5873 lb/MMscf o 1941 1941 0% Yes 67561 Methanol n 3.1212 lb/MMscf AP -42; Table 3.2-3 (7/2000); Natural Gas 365 365 0% Yes 75070 Acetaldehyde n 2.8458 lb/MMscf AP -42; Table 3.2-3 (7/2000); Natural Gas 333 333 0% Yes 107028 Acrolein n 2.6826 lb/MMscf AP -42; Table 3.2-3 (7/2000); Natural Gas 314 314 0% Yes 71432 Benzene n 1.6116 lb/MMscf AP -42; Table 3.2-3 (7/2000); Natural Gas 189 189 0% No 106990 1,3 -Butadiene n 0.67626 lb/MMscf AP -42; Table 3.2-3 (7/2000); Natural Gas 79 79 0% No 108883 Toluene n 0.56916 lb/MMscf AP -42; Table 3.2-3 (7/2000); Natural Gas 67 67 0% No 1330207 Xylene n 0.1989 lb/MMscf AP -42; Table 3.2-3 (7/2000); Natural Gas 23 23 0% No 0 PAH n 0.14382 lb/MMscf AP -42; Table 3.2-3 (7/2000); Natural Gas 17 17 0% No 91203 Naphthalene n 0.09904 lb/MMscf AP -42; Table 3.2-3 (7/2000); Natural Gas 12 12 0% No NOTES *Emissions of criteria are reported in tons/yr; emissions of NCRPs are in lb/yr. Engine BSCF: 7158 Btu/hp-hr Engine HP: 1897 Fuel Heat Value: 1020 btu/scf Controlled emissions shown above are calculated using the control efficiencies/factors specified, at the permitted fuel use rate (calculated at 8760 hpy) PTE shown above is calculated based on the uncontrolled emission factors and the maximum potential fuel use rate (calculated at 8760 hpy) Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details - - Review Engineer: Package 0: Received Date: Review Start Date: -Timothy Sharp 384866-" 6/29/2015 7/27/2018 Section 01 - Facility Information Company Name: REP Processing Us County AIRS ID: 123 Plant AIRS ID: SI Facility Name:. Physical Address/Location: County: Type of Facility: Natural Gas Processf-,tg P(arsc What industry segment? Oil & Natural Gas Production & Processing Is this facility locatedina NAAQS non attainment area? Yes If yes, for what pollutant? ❑ carbon Monoxide (CO) SW quadrant of Section 21, Township 8N, Range 66W Weld County Section 02 - Emissions Units In Permit Application Quadrant Section Township Range S' Particulate Matter (PM) a - ' Ozone (NOx & VOC). 8N 66. AIRS Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks 003 Natural Gas RICE - C-1 : ::,.- Yes -':18WE0777 --1: '" - - ..-- - " 4srb turbo 004 Natural Gas RICE C-2 Yes 18WE0777 1 4srb turbo 005 ; Natural RI t C-3 Yes 18WE0777 1, 4srb turbo 006 I'.latur9l Gas RI C-4 Yes 18WE0777 2 4srb turbo 007 Natural Gas RICE C-5 Yes - 18WE0777 1-- 4srb turbo 008 : Natural Gas RICE C-5 - - Yes 18WE0777 - 1- - 4srb turbo -- 009 Process Flare CO -'' 18W50777 .. 010 FugitiveCamponent- teaks . FUG Yes 18WE0777 S. - - 0000e LOAR control requested Dehydrator" D - -- - Yea =-18WE0777 1: , 7EG { Amine Sweetening Unit - Al- Yes -18WE0777 '013 <..., - Liquid Loading- - - LD 1 Yes 18WE0777 014 - Separator Venting .MSS -1 - Yes 18WE0777 ,;.:..: 015 - - NG Heater - HTR1 18WE0777/IV :,,. 016 NO Heater _, _ HTR2 18W£0777 r, 017 ; NG Heater --- HTR3 , , 18WE0777 O18 N G Heater HTR4 18WE0777 1 Section 03 - Description of Project Modeling Results Summary from Tech Services Unit: her are NAAQS and CAAQS currently in effect for the following pollutants and averaging periods CO (1 -hr and 8 -hr), Pb (3 -month rolling average), NO2 (1 -hr and annual), PM10 (24 -hr), PM2.5 (24 -hr and annual), 502 (1 -hr, 3 -hr, 24 -hr; and annual), and ozone (8 -hr). For this permit application, quantitative impact analyses are warranted to demonstrate compliance -with the NAAQS/CAAQS for thefollowingpollutants and averaging periods: NO2 (1 -hr and Annual), PM2.5 (24 -hr and Annual), and 30211-ht',3-hr, and 24 -hr). The applicant submitted ubmitted modeling analyse for all required pollutants and averaging periods except the :1 -hr 502, The SSP decided modeling orthe 1 hr 502 NAAQS was notwarranted per PS Memo 10-01. After review of the analyses submitted by the applicant with revisions by the MEIU, it is concluded that the REP Pierce Gas Processing Plant new facility will not cause or ntribute to any modeled violation of the corresponding NAAQS/CAAQS. The MEIU conducted'a modeling analysis for the 1 -hr SO2 NAAQS and it is concluded that the REP Pierce Gas •iP,Ocesing Plant facility will not ca use and/or contribute toany modeled violations of the 1 -hr 502 NAAQS. e' compliance demonstration is valid under the following configuration (recommended permit conditions): - Fencing and Preclusion of Public Access:Impacts were estimated at ambient air receptors only (Le, an -ambient air boundary and fencing was assumed in the modeling). The permit should antain a condition that Srfthe duration of the permit effectiveness, the source operator shall maintain continuous fencing along the boundary depicted in the Horizontal Control Plan of the be 2018 (Revised September 2018) submittal ',Air Quality Impact Analysis Pierce Gas Processing Plan." The boundary depiction is attached. Public access into these areas shall be gre �ecl duded. - -- , Stack Heights and Parameters: Modeled impacts were estimated assuming the stack heights and stack parameters provided in the'submitted APENs and indicated in Tables 5 and 7 of the • J l e 2018 (Revised September 2018) submittal `Air Quality Impact Analysis Pierce Gas Processing Plan." These tables have been updated to reflect the stack parameters from the APENs that ere ultimately used in the modeling analysis. The permit should contain condition that the facility should be constructed with the layout and stack parameters depicted and summarized', n'the Horizontal Control Plan, Receptor Grid 1K Figure and Tables 5 & 7. The stack parameters tables and layout figures am attached. 3: Layout of Sources &:Buildings: Modeled impacts were estimated assuming that the location of the sources and the layout of buildings and sources within thefacility correspond to the one indicated in the Horizontal Control Plan of the June 2018 (Revised September 2018) submittal "Air Quality Impact Analysis Pierce Gas Processing Plan." The permit should contain a condition::. that the facility should be constructed with the aydgt of sources and buildings depicted In the aforementioned figure. - _ - The results of the modeling analyses are summarized below; PM2,5 24 -hr: Modeled impact - 8.23 ug/m3; TotalImpact= 30.28 og/m3, NAAQS = 35 ug/m3 IiIPM2.5 Annual: Modeled. Impact=0.654 ug/m3,Tota I, Impact= 7.654 ug/m3„NAAQS- 12 ug/m3' 502.1 -hr: Modeled impact =9,72 ug/m3, NAAQS='196.5 ug/m3 - -. S023 -hr: Modeled =Impact = 5.00 ug/m3,5IL =-25 ug/m3 SO2 24 -hr: Modeled Impact = 1.46 ug/m3, OIL =.5 itg/m3 _ NO2.1 -hr Total Inspact=1348.14 ug/m3, NAAQS= 188 ug/m3 (Them were 878 modeled exceeda nces of the 1 -hour NO2 NAAQS, but atoll exceedaeces the co nth butien from the Pierce Gas Plant. is insignificant; the facility will not contribute 'to'amodeled violation ofthe l-hour(402NAAQS.)-' - - M102 Annual: Modeled Impact = 5.51 ug/m3, Total Impact = 11,15 ug/m3t.NAAQS -_99.64 ug/rn3 Colorado Air Permitting Project Section 04 - Public Comment Requirements Is Public Comment Required? If yes, why? Section 05 - Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? e If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide StationarySource Classification Is this stationary source a true minor? Itkr 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) Is this stationary source a major source? If yes, explain what programs and which pollutants hers 502 Prevention of Significant Deterioration (PSD) mm Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) 502 NOx CO NOx CO PM2.5 PM10 TSP HAPs El El PM2.5 PM10 TSP HAPs ❑ ❑ Fugitives Emissions Inventory Section 01- Adminstrative Information (Facility AIRS ID: County Plant Point 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 Section 04- Emissions Factors & Methodologies Regulation 7 !information Operating Hours: Emission Factor Source Control Efficiency Source: ,"�,p"1, " 33v1nhIItiyT p [tg F • 0000a Calculations Emission Factor (kg/hr- Service Component Type Count source) Control (%) Pollutant Mass Fraction Uncontrolled Controlled Table2-4 Table 2-8 Emissions (tpy) Emissions (tpy) Connectors ::.5340;' 2.00E-04 1.00E-05 850% VOC 6Eti42 -. ,25.50019661 6.667069513 Flanges ::96491;1 3.90E-04 5.70E-06 0.0% Benzene . 909 ,di11; t.. 0.066271697 0.017326847 Open -Ended Lines : , f±'i " 2.00E-03 1.50E-05 0.0% Toluene '' 4_69EfiAil. 0.04610205 0.01205345q Gas Pump Seals ::'; 6..' 2.40E-03 3.50E-04 0.0% Ethylbenzene 2Md4: 0.023051025 0.00602673 Valves ';'1699' 4.50E-03 2.50E-05 96,0% Xylenes 301S 84:..j 0.328813781 0.007533412 Other ,17#t,,; 8.80E-03 1.20E-04 0.0% n -Hexane a7»�Ek 0.820876447 0.216711148 — — -- — — 2,2,4-TMP R.0 . 60 '041);'v.i' �; 0.003841838 0.001004455 Connectors :( tJ; 6::: " 7.50E-06 7.50E-06 81.0% VOC ::€,00E8d4..., €: 0 0 Flanges ;: .97 �4: 3.90E-07 3,90E-07 0.0% Benzene ;':00009)11 11i1 0 0 Open -Ended Lines :€� i!"; : 1.40E-04 7.20E-06 0.0% Toluene 'x; :p;00046l'K' '. 0 0 Heavy Oil Pump Seals .0-.:. 0.00E-000 0.00E+00 0.0% Ethylbenzene`''i1;ti0OfL'.: 0 0 Valves 0: ,: 8.40E-06 8.40E-06 0.0% Xylenes "Iltt Of111Q408.'..-. 0 0 Other :; 6: f.? 3.20E -DS 3.20E-05 0.0% n -Hexane 0 0 - -- - - - 2,2,4 -TRIP ?i '`6:t(04:94f1iR 0 0 Connectors , ,5889 2.10E-34 9.70E-06 81.0% VOC X4 l i �+9 69.09543607 8.811688889 Flanges :=969$1; 1.10E-04 2.40E-06 0.0% Benzene t.ly:�89�1� ' 0.406972118 0.061900848 Open -Ended Lines ;°.5-''0,°: 1.40E-03 1.40E-05 0.0% Toluene ::1:..,1......: -IIa'�. 0,138808963 0.017447144 Condensate (Light Oil) Pump Seals ,50' 1.30E -n2 5.10E-04 88.0% Ethylbenzene 9... 0 k.'r041l ? 0.007185925 0.000916416 Valves ,:1981: 2.50E-03 1.90E-05 95.0% Xylenes 331E 44?;. 0.022870589 0.002916669 Other ; 24: 7.50E -D3 1.10E-04 0.0% n-Hexane""9046-0Z:':: 6.797609 0.866893953 — — — — — 2,2,4-TMP 1.05E-03:::: 0.572550208 0.009252273 Connectors :.. 0" . 1.10E -D4 1.00E-05 81.0% VOC 1.00E+96:'::: 0 0 Flanges :.. fj:'., 2.90E-06 2.90E-06 0.0% Benzene 0:00`,1; 0 0 Open -Ended Lines 1::': D'�''" 2.50E -D4 3.50E-06 0.0% Toluene OOOE,}•0}7.1'. 0 0 Water/Oil Pump Seals °:; .0 ..� 2.40E-05 2.40E -OS 0.0% Ethylbenzene 0.046`+(��,;11 0 0 Valves :':-0i .j, 9.80E-05 9.70E-06 0.0% Xylenes 0 00E+00,„„ 0 0 Other `. 4 t'i 1.40E-02 5.90E-05 0.0% n -Hexane 0006x00;,: 0 0 0 - -- - -- - 2,2,4-TMP 0.00E 00'4 'r; 0 0 Connectors 2.10E-04 9.70E-06 01.0% VOC 570% -HI - 0 0 Flanges „ 1.10E-04 2.40E-06 0.0% Benzene -: zi44A 0 0 Open -Ended Lines - 1.40E-03 1.40E-05 0.0% Toluene 1.59E -b3,-, 0 0 NGL (Light Oil) Pump Seals 1.30E-02 5.10E-04 88.0% Ethylbenzene 4.39E-04:--:. 0 0 Valves 2.50E-03 1.90E-05 95.0% Xylenes 1.15E-03",! 0 0 Other 7.50E-03 1.10E-04 0.0% n -Hexane 5.?2.03" i " 0 0 - - - - - 2.24-TMP 241E -03M'. o 0 Section 05- Emissions Inventory Pollutant Uncontrolled Emissions Controlled Emissions Source VOC 94.60 toy 15.48 tpy Standard EF: Benzene 946.49 lb/yr 138.46 lb/yr Standard EF Toluene 365.82 lb/yr 59.00 lb/yr Standard EF: Ethvibenzene 60.47 lb/yr 13.89 Ib.lyr Standard EF: Xylenes 103.37 lb/yr 20.90 lb/yr Standard EF: n -Hexane 15252.97 lb/yr 2167.21 lb/yr Standard OF: 224-TMP 152.78 lb/yr 20.51 lb/yr Standard OF: section 06-Re;ulatc Summer An Review Regulation 3, Part B, Section III.D.2 to determine is RACT is required? Review 40 CFR, Pert 60, Subpart KICK to determine if applicable to this source? Review 40 CFR, Part 60, Subpart 0000 to determine if 60.5380 and/or 60.5385 is applicable? Review Section XVII.F to determine is LDAR is applicable? - EPA -453/R-95-017 Table 2-4 - EPA -453/R-95-017 Table 2-4 - EPA -453/R-95.017 Table 2-4 - EPA -453/R-95-017 Table 2-4 - EPA -4531R-95-017 Table 2-4 - EPA -453/R-95-017 Table 2-4 - EPA -453/R-95-017 Table 2-4 Additional Regulatory Considerations Regulation 1 Section II.A1 - 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 (July, 1992)) In all subsections of Section II. Aand B of this regulation. Regulation 2 Section I.A - 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 8 odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air, Part A-APEN Requirements Catena Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required fon each individual emission point in a non -attainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant (pollutants are not summed) for which the area is non -attainment. Applicant is required to file an APEN since emissions exceed 1 ton per year VOC TPY Uncontrolled Controlled 0.473243816 0.0692277 0.182911014 0.0295006 0.030236951 0.0069431 0.051684371 0.0104501 7.626485447 1.0836051 0.076392045 0.0102567 Fugitives Emissions Inventory Regulation 3 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.2.a) Is this source located in an ozone non -attainment area or attainment maintenance area? dyes, is this source subject to leak detection and repair (LDAR) requirements per Regulation 7, Section XVII.F or XII.G or 40 CFR, Part 60, Subparts KKK, 0000, or 0000a? - -' Part B, III.D.2 - RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainmentlmaintenance areas. This source is located in the 8 -hour ozone nonattainment area The date of interest for determining whether the source is new or modified is therefore November 20, 2007 (the date of the 8 -hour ozone NA area designation). Since the fugitives will be in service after the date above, this source Is considered "new or modified." This facility is subject to NSPS 0000a. Following the leak detection and repair program per NSPS 0000a setisifies the RACT requirements of Regulation 3. The permit will contain a condition reflecting this determination. Regulation 6 Is this source at en onshore 'natural gas processing plant" as defined in 40 CFR Part 60.631? Did this source commences construction, reconstruction, or modification after January 20, 1984, and on or beforeAugust 23, 2011? , ; No This source is not subject to NSPS KKK because the facility will commence construction after August 23, 2011, Did this source commences construction, reconstruction, or modification after August 23, 2011 and on or before Sept mbar 18, 2015? Source is not subject to NSPS 0000 because this is a new that facility will commence construction after September 18, 2015- Regulation 7 Isthis source located in an ozone non -attainment area or attainment maintenance area? ._ YeS Is this source at en onshore 'natural gas processing plant' as defined in 40 CFR, Pat 60.631? "Yew Facility is classified as a natural gas processing plant Therefore, this source -s subject to Regulation 7 Section XII.G. Isthe facility classified as a well production facility or natural gas compressor statics? No - Since this facility Is not classified as a well production facility or natural gas compressor station, it is not subject to Regulation 7 Section XVII-F. Regulation 8 Isthis source at a "natural gas processing plant' as defined in 40 CFR, Part 63.761? Yes ethic facility considered a "major source" of HAP as specifically defined in 40 CFR, Part 63.761 for sites that are not prodcu0onfield facilities? -_, -(Sc, If you repond "yes" to bath questions above, further review if the provisions of 40 CFR, Part 63.769 "Equipment Leak Standards" apply? Source is not subject to MACT HH because the facility is classified as a synthetic minor source of HAPs. NSPS 0000 Did this source commence construction, reconstruction, or modification after September 18, 2015? ' Yes Is this source eta well site, compressor station or onshore "natural gas processing plant' as defined in 40 CFR, Part 00.5430a? Yes This facility meets the definition of onshore "natural gas prne=sing plant" asdefined by 40 CFR Part 60.5430a. Therefore, the fugitive emissions at this facility subject to NSPS 0000a. section 07 - Technical Analysis Notes AddNfcgai Natest 1. Neyftntirce ep pitta₹ipm:. .. Three ltutatedVO( e h the pandelis bghtnilserulce;. water(uilservic andheavyidit dinct thw he tinstcanservatwa'estimatefarVt3C, t detarmmed:h`wasoenee eusaryfo.tite operatcrte obtainen inidat 3.Tiiegassemicecompositan iebaseden flue representativelntetgassenples- Since the entire gassemiceishased on inlet gas, the eraissia cafcclated areiiker 'cdiseruative. HowercnI3nheopers5or is;asssmhrgless then l00%VOCarrd thesampie is no sitespeci5c. Asa result initek tasting wilt. inn -haled In the permit requiring a sampFebeobtaitredfromthisserurcetndemonstratecomplraccawhhtbelimitscontainedinthe permit. Annuattestingwill atsehereguired 4, i1nit.coceetstcn from kejbr/saurea fgp-42itoth/ht'fongrce (operator talcs) account for negteglhlecR(FOreecein emissions estimates,— - - 5. Asdiscuss d above, this facility is subjectto NAP50000a,flowerer, this federar rngdlattan has not been adopted bdoColnradastate sego will hceddnn red in the notesto Permit beider. - - 6. Colorado RegulationSection Xli.13,1, requires The following:. "For voc emissions from leuhingoqufpmeut the ledkctetetttonanal repair;(LDARyprograrr providedat40 CFR Pert 60, Subpart KKK (July 1,2616) shalt apply, regardless dills date of construction o€ the affected facifily„Unlescsuhies5taapplicabie t.DARp y es providedat 40CFR Part 60, Subparts 00o0ar 0000a (dulylr 2026}"As discussed aheve,thissaurceissnhjecttoNSP50000a; Fvlihvahgthe requirements of NSPS - 0000e satisfiesthe requirements under'Eotdredo Regutat ter7Snetign OILS. 7 AccordingtoCotorad0 Reguladon3 Part A5ectlenf.S.25b aPugftiveamissicnsshaltnot be cons(deredindeterminInewhether asourceIca :majorsourcefor the purposes oft111s Section 1.8.25.b., unlessttiesource be?orgsto eneuf the following ,cotegorlesofstationarysournes."Thissciilty lsnot included .intheftstedsources and therefore fugitive emissions are not inoludedwhendetenniningwhether or not this facility is major source. 8-, The operatordid:eo.C, provide rovid HAP composition for the heavy oil orwaer/oilservices. This was deemed ecceot4ole for the. falttwingteaso pl-ThisfacilityisnotclosetotheipdividoulartotetHAPmajorsourcethresholds:. (rjrhese two sehdces ocnti'butesscs'ttiaaltny of V0C0athe tctolcvn, inn them this ourgm,AerurthctheiltPagtra weuldtesojtftis Hsese setaf60s.wauld:likelF' , insignlfic.rft.% -,T -9..The-operetorsubsaitted an 0&M plan for hrgitnesndtbthisairpLeaion. Accord:net° the secendperag ph nitre-fnst page oft efugdive O&M pla "ifthe ta'cilifyhat'.-:' NSPSar NMACTrequirements for Leak Oetectionand Repair (e.g,,NSPS10ELand/or t000andifor00ticaandlaectberj;thenthe eperatarshaffellewfhe federai ..i requirementsandthu O&M Plan does not media heaehmitted.^.'F#rissourxetssubject to NSPS 0000a asmdlcatedebave.Ada result, theoperatot'agreed to remove. ttes 0&6# plan from fheapp5cab nastheywilifoltawWARrequirementsper NSPS0400a - - - - Section 08- Inventory 5CC Codingand Emissions Factors AIRS Point N Process # SCC Code 007 01 Uncontrolled Pollutant Emissions Factor Control % Units Varies by Varies by VOC component type component type Standard EFs-EPA-453/8-95-017 Table 2-4 Varies by Varies by Benzene component type component type Standard EFs - EPA -453/8-95-017 Table 2-4 Fugitives Emissions Inventory Varies by Varies by Toluene component type component type Standard EFs - EPA-453/R-95-017Table2-4 Varies by Varies by Ethylbenzene component type component type Standard EFs - EPA -455/R-95-017 Table 2-4 Varies by Varies by Xylene component type component type. Standard EFs - EPA -453/R-95-017 Table 2-4 Varies by Varies by n -Hexane component type component type Standard EFs - EPA -453/R-95-017 Table 2-4 Varies by Varies by 124 TMP component type component type Standard EFs - EPA -453/R -9S-017 Table 2-4 Glycol Dehydrator Emissions Inventory 011 Dehydrator Facility AIRS ID: Conn ti₹,Jl,:Obkgatitunr'4kri,-7,a%i iRtiki Plant Point 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: , flash tank, and re boiler burner One (1) Trlethyiene glycol (TEG) natural gas dehydration unit (Make: TBD, Model: TBD, Serial Number: TBD) with a"design capacity of to MMscf per day. This emissions unit is equipped with 1(Make: thd, Model: tbd) electric driven glycol pump with a design capacity of 7 gallons per minute. Ties dehydration unit is equipped with a still vent, flash tank, and ',Moiler burner. Emissions from the still very are routed to an air-cooled condenser, and then to the Enclosed Flare. Emissions from the flash Sank are muted directly to the closed -loop system. Section 03- Processing Rate Information for Emissions Estimates Primary Emissions - Dehydrator Still Vent and Flash Tank If present) 'Requested Permit Limit Throughput= Potential to Emit (PTE) Throughput = MMscf per year Requested Monthly Throughput = 1860 MMscf per month 21,900 MMscf per year Secondary Emissions -Combustion Devlce(s) for Air 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 Gas 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 Input Parameters Inlet Gas Pressure Inlet Gas Temperature Requested Glycol Recirculate Rate Requested Condenser Outlet Temperature: 9])fiNX,.1€. ,,..; 7 g sF t39 Control Efficiency h /y Requested TO Temp _ '. p��31a0331�j�3 Deg es f Control Efficiency % hr/yr Btu/scf ssfit psig deg F gpm STILL VENT Control Scenario Primary Secondary Pollutant Uncontrolled (lb/hr) Controlled (lb/hr) Controlled (lb/hr) VOC "'24.9740a,11113i/vi 1.24873 0 Benzene R -; 2.6541 i- 0.132555 0 Toluene =_-=:"):'))2:434t0F)-88) 0.12271 0 Ethylfenzene - „5,50eVs..ixw-"'` 0.07969 0 Xylenes h/23790 0.139535 0 n -Hexane Hd 3j yV�fk' 9zllV. 0.046275 0 224-TMP 610029'`}1- -_ ..'M14 0 FLASH TANK Uncontrolled (lb/hr) Control Scenario Primary Controlled (lb/hr) Secondary Controlled (lb/hr)- Pollutant • VOC :3 1504644k16 -'. 0 0 Benzene 111-`/7.f1}»az,°j„,�ry,.j 0 0 Toluene _. O'stiD77&t::: 0 0 Ethylbenzene •_....... AA hh:/, :', 0 0 Xylenes ifIffilififft 0 0 n -Hexane 018)343.30))9=3X3 0 0 224-TMP _ jr0:00.4 l)t)Ll 0 0 Dry Gas Throughput: Still Vent Primary Control: 21,900.0 MMscf/yr Still VentSecondary Control: 21,900.0 MMscf/yr Waste Gas Combusted: Still Vent Primary Control: 9.6 MMscf/yr Still Vent Secondary Control: 0.0 MMscf/yr Dry Gas Throughput: Flash Tank Primary Control: 21,000.0 MMscf/yr Flash Tank Secondary Control: 0.o MMscf/yr Waste Gas Cam busted: Flash Tank Primary Control: 0.0 MMscf/yr Flash Tank Secondary Control: : 0.0 MMscf/yr 1,860.0 0.8 Glycol Dehydrator Emissions Inventory Still Vent Primary Control Device Pollutant dl Vent Secondary Control Device Pollutant (lb/MMscf) (lb/MM (Dry Gas Throughput) (Dry Gas Throughput( Uncontrolled (Ib/MMBtu( (Ib/Mfdscf) (Waste Heat Combusted( Ancontolled (Waste•Ges Combusted) Uncontrolled (Ib/MM Btu) Uncontrolled (lb/M PM10 PM2.5 5Ox NO CO Pollutant PM10 PM2.5 0.0000 0.0080 0.0000 0.0000 SOD NO0 CO Emission Factor Source Emission Factor Source Rash Tank Secondary Control Device Pollutant Uncontrolled (Ib/MMBt Uncontrolled (Ib/Mtd Emission Factor Source Section OS -Emissions Inventory Old operator request a buffer? Requested Buffer(%): 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 SOD NO0 CO VOC 0.0 0.0 0.0 0.0 0.0 6 0.0 0.0 0.0 0.0 0.0 6 0.0 0.0 0.0 0.0 0.0 0 0.3 0.3 0.3 0.3 0.3 57 1.5 LS _ _ 1.5 1.5 _ 1.5 259 190.3 190;3 5.5 190.3 5.5 529 Hazardous Air Pollutants Potential to Emit Uncontrolled (Ibs/year( Actual Emisslons - Uncontrolled Controlled (Ibs/year( (Ibs/year) Requested Pe rut Limits Uncontrolled Controlled (Ibs/year) (Ibs/year( Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 23351 23351 1161 23351 ' ' 1161 21561 21561 1075 _ 21561 1075 13981 13951 698 13981 698 24468 24468 1222 24468 1222 9323 3.0 909 905 30 BQ 1 30 1 Section 06- Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Section XVII.B,D Regulation 7, Section XV11.B.2.e Regulation 7, Section XILH Regulation 8, Part E, MACT Subpart HH (Area) Regulation 8, Part E, MACE Subpart HH (Major) Regulation 8, Part E, MACT Subpart HHH (See regulatory applicability worksheet for detailed analysis) haps tons/yr 11.675 10.780 6.990 12.234 9.989 0.015 0.581 0.537 0.349 0.611 0.203 0.001 Source requires a permit Dehydrator H not subject to Regulation 7, Section XVII.B, D.3 The control device for this dehydrator Is not subjectto Regulation 7, Section XVI1.8.2.e Dehydrator 6 subject to Regulation 7, Section XII.H Dehy is sublet[ to area source MACT HH - Control requirements In 63.765 per 63.764(d((1( 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 MACT HHH. Glycol Dehydrator Emissions Inventory Section 07 - Initial and Periodictampling and Testing Requirements Was the extended wet gas sample used in the 6lycalc model/Process model site -specific and collected within a year af.application submittal? 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 flare or combustion device? If yes, the pent will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based an Inlet end outlet concentration sampling lithe 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 pemrR will contain a condition specifying the minimum combustion chambertemperature for the thermal oxidizer Is the company using a thermal oxidizer AND requesting a minimum combustion chamber temperature lower than 1,400 degrees F? If yes, the permit will contain an "Initial Compliance" testing requirement AND a permit condition specifying the minimum combustion chamber temperature far the thermal oxidizer.. Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point Process R 5CC Code 011 01 Uncontrolled Pollutant Emissions Factor Control% Units PM10 0.003 0.0 b/MMscf PM2.5 0.003 0.0 b/MMscf 5Ox 0.000 0.0 b/MMscf NOb 0.031 0.0 b/MMscf VOC 17.4 97.1 b/MMscf CO 0.139 0.0 b/MMscf Benzene 1.066 95.0 h/MMscf Taluene 0.985 95.0 b/MMscf Ethylbenzene 0.638 95.0 b/MMscf Xylene 1.117 95.0 b/MMscf n -Hexane 0.456 95.9 b/MMscf 224 TMP 0.001 95.9 b/MMsc£ Dehydrator Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements 'Source is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greaterthan 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Are total facility uncontrolled VOC emissions greaterthan 5 TPY, NOx greaterthan 10 TPY or CO emissions greaterthan 10 TPY (Regulation 3, Part B,Section 11.0.3)? 'you have indicated that source is in the -Non -Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Are total facility uncontrolled VOC emissions from the greaterthan 2 TPY, N0x greater than 5 TPY or C0 emissions greater than 10 TPY (Regulation 3, Part B, Section ll.D.2)? Source requires a permit Colorado Regulation 7, Section XII.H 1. Is this glycol natural gas dehydrator located in the 8 -hr ozone ontrol area on any ozone non -attainment area or attainment/maintenance area (Reg 7, Section XII.H.1 and 2)? 2. Isthis glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, natural gas drip station or gas -processing plant (Reg 7 Section 3. Isthe sum of actual uncontrolled emissions of VOC from any single dehydrator or group of dehydrators at a single stationary source equal to or greater than 15 tpy (Reg 7, Section XII.H.3.6)? 4. Are actuafuncontrolled emissions of VOC from the individual glycol natural gas dehydrator equal to or greater than 1 tpy (Reg 7, Section Xll.H.3.a)? 'Dehydrator is subject to Regulation 7, Section Xil.l9 Section XII.H — Emission Reductions from glycol natural gas deiydrators MACT Analysis 1. Is the dehydrator located at an oil and natural gas production facility that meets either of the following criteria; a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)); OR A facilitythat processes, upgrades or stores naturalgas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final b. end user' (63.760(a)(3))? 2. Is the dehydrator located at a facility that is a major source fortlAPs? ' Go to MAR HH Area Source Requirement section to determine MAR HH applicability Yes Yes 'Yes 40 CFR, Part 63, Subpart MACT HH, Oil and Gas Production Facilities Area Source Requirements 1. Is the dehydrator a triethylene glycol (TEG) dehydration unit (63.760(b)(2))? Exemptions 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit lessthan 3.001747 MMscf per day (63.764(e)(1)(i)? 2b. Are actual annual average emissions of benzene from the glycol dehydrationunit process vent to the atmosphere less than 1,984.2 lb/yr (63.764(e)(1)(ii)? Is the unit located inside of a UA plus offset and UC boundary area? Dehy is subjectto area source MACT HH: Control requirements in 63.765 per 63.764(d)(1) Subpart A, General provisions per§63.764 (a) Table 2 §63.765 - Emissions Control Standards §63.773 - Monitoring Standards §63.774- Recordkeeping §63.775 - Reporting Major Source Requirements 1. Does the facility have a faciity-wide actual annual average natural gas throughput lessthan 0.65 MMscf/day AND a facility -wide actual annual average hydrocarbon liquid throughput less than 2493 Small or Large Dehy Determination 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit lessthan 3.001747 MMscf per day (63.761)? 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere lessthan 1,984.2 lb/yr (63.761)? Small Dehy Requirements 3. Did construction of the small glycol dehydration unit commence on or before August 23, 2011 (63.760(b)(1)(i)(B) and (C)? 4. For this small dehy, is a. control device required to meet the BTEX emission limit given by the applicable equation? IYou have indicatedthat this facility is not subject to. Major Source requirements of MACT HH. SubpartA, General provisions per §63.764 (a) Table 2 §63.765 - Emissions Control Standards §63.773 - Monitoring §63.774 - Recordkeeping §63.775 - Reporting 40 CFR, Part 63, Subpart MAR HHH, Natural Gas Transmission and Storage Facilities 1 Is the facility wide actual annual average natural gas throughput less than 0.9994051 MMscf/day and glycol dehydrators the only HAP emission source (63.1270(9))? Small or Large Dehy Determination 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit lessthan 9.994051 MMscf per day (63.1270(b)(2))? 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr (63.1270(b)(2))? Small Dehy Requirements 3. Did construction of the small glycol dehydration unit commence on or before August23, 2011 (63.1270(b)(2) and (3) )? 4. , For this small dehy, is a control device required to meet the BTEX emission limit (standard?) given by the applicable equation? Yes You have indicated that this facility is not subject to MACT HHH. Subpart A, General provisions per §63.1274 (a) Table 2 §63.1275 - Emissions Control Standards §63.1281 -Control Equipment Standards §63.1283 - Inspection and Monitoring §63.1284 - Recordkeeping §63.1285 - Reporting Colorado Regulation 7, Section XVII.D 1. Is the dehydrator subject to an emissions control requirement under MACT HH or HHH (Regulation 7, Section XVII.B.5)? 2. Is this dehydrator located at a transmission/storage facility? 3. Is this dehydrator located at an oil and gas exploration and production operation, natural gas compressor station or gas processing plant (Reg 7, Section XVII.D.3)? 4. Was this glycol natural gas dehydrator constructed before May 1, 2015 (Reg 7 Section XVILD.4.b}? If constructed prior to May 1, 2015, are uncontrolled actual emissions from a single glycol natural gas dehydrator equal to or greater than 6 tons per year VOC or 2 tpy VOC if the 4a. dehydrator is located within 1,320 feet of a building unit or designated outside activity area (Reg 7, Section XVII.D.4.b)? 5. If constructed on or after May 1, 2015, ire uncontrolled actual emissions from a single glycol nateral gasdehydratorequal to or greater than 2 tpy VOC (Regulation 7, Section XVII.D.4.a)? 'Dehydrator is not subject to Regulation 7, Section XVII.B, D.3 Section XVII.B — General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.D.3 - Emissions Reduction Provisions Altemative Emissions Control (Optional Section) 6. Is this glycol natural gas dehydrator controlled by a back-up or alternate combustion device (i.e., not the primary control device) that is not enclosed? IThe control device for this dehydrator is not subject to Regulation 7, Section XVII.B.2.e Section XVII.B.2.e —Alternative emissions control equipment Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," may," "should," and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. Yes No Yes Amine Unit Emissions Inventory s.elen oe-edninlmxM Inform.. 'Nmeryualm nt Pain . nit umrmxmnm Doam an o. AmuU Arnlne Mak ' serial Number: Design panto RedrculatIon lnbennionPurnpType gut/MangrdmuHummatE ArnIne Equipment. Flesh Tank Mnscf/day gnlons/mhate total and reboer burner Ono MMelhNe!emamlamine[Moeal natural gee eweetenlngunitiMeke:Tao,Modet TBD,Seriel Number: Tgol with a design apmIty xaOMMscf tots en.. w3 b eaulppedwfth5 iMeb: Tgo,MadoFTeof elextncdrivenarrgne pumpiel wk. a design...melt.at 800 gallons per minute Amine un@uleipment0xcdpnen combined. uamine umtrs equipped with a s0l wm,Iwhtenk and mboilaWmer. Ernistionefrarstflos...ant we routed m al.eootod condom, andthento ttieThermal Oxidtz secondary control dai.,1o. still vent missknr ere rovtetlto the Endes. Pere. D. -balms from the tlnh tankere muted dbectMto heTeemel Oxidizer. Ale secondary control aevtee,noch tank Emission Control Device Eiescriplion: ...Sons are to...I...Enclosed Hare. )e(l.n 03 -Processing.. IldarmtIonfa Fmle lass Frtimatos Mm.ry Fmi.,ines anlo wdtsn v.nt.nd Inp,w.n 1, geaaesreavamrtumltmmmgxpmt. )lfllllii�'�,d_,,,,,,,,,z:z. Potential to Erna (Pie) Throughput= Sande y5OSkw- Seboxbn a.Nalq tor Afrpollutbn Control stfliVant Control Condiwasen Paw,ccmnadmice union claimed: PrImazy nS.aMerymxai clew.: mn. Seconclarycontrol Me...Gas ...tin.Velum amA Stilt V.0 55055 555 VSSS Pate Mtn., control clew.: Primary control deers operator.. Stioandary control device: Secondary control device operation: Ruh TankaesMoetirgValue Flesh Tank Waste Gas Vent Bate: Section 00 - Emisisw Tern & M..odalogloe Inlet Gas lnputTemperawre Requested Leen Psnaulee Pate Hash TaniTan. Temperature Rash Tank Pressure Leen Pine weft% Ceram! Scenario STILL VENT P.INbn[ ed ON.) [ono-00.10/hr) ton l.1O/hr) wl ton lea0bmrt VOC F3 Ymene ii; a 0 Toluene a zone 17 ' 'Menu U d.fa��ti% 0-ne. fr>i >aa-TM =>ns a o 'Its .......1.771»..1,allllll.Ya�m�dse»�+..s.,.....,:..r��. 0 0 wlm.ry antra teen Pollutant Uncontrolled ned0hmd [anw4d 11dmrl Co.xn glad Wbmrl . Benzene 3l `..- afi lls Ta0ene-0 /ilk ₹e&^.-- EUNbemene Xylenes 1, *2 N P ..n3.rfl.''l. ms ..., u...,rla;;*, a a V. claty Pollutant [lb/ Soo rolied pb/MMse11 r>uPlagE9S: 169. 0.0 MMscf/yr 5.00 Vent.conewymnwl: AdMse/Yr Gas CeStel Vent Prirr.,Condot ono WAWA. BM:Wentsemndsy Con.. C.00 MMscf/yr ...: flash TankMmarycnntrol: u Ms.,/F, Flash Tankseconaaryc sdryr Waste Oa Combust.. Flash 'rank Primarycontrol:mr/yr Flesh Tank Seconaarycontrol. O.w MMscf/yr Emission Factor Source. 17.03998 3.80.5 299263 6250609 6761731 3.71302 0.1.036 00121989 00239711 0.2.062 3.5805.05 0.0BOI 5741 Sal Ruh Benzene 0.000.00 Toluene 0.000Ec00 0.000E. 0.0008400 1100..006000.0 tflen0.000.00N25 s 0.001E. 0.0.00 4.947 38955.72 Section 05 -.anima Inventor( O ld operator bynp Requested Buller (54): PISIO CO VOC so Uncontrolled • (.nsher( SOO 4c.alallusions Unoontnalied Controlled (tons/yes] (tons/yor)' 0. - Amine Unit Emissions Inventory . • Requested Penn.. acs Controlled (Uncontrolled ..Sfeasl 1100 000 0.00 000 5535 0.0 600 55,5 000 sumo 5535 • Toluene aMlm ,0100 22.4 TINS Soma. Errit (mnsndr) Actual Emksbns (meendrl (mn.h0s) ReQ ft Pnm3Wnh Unconlrobl Corso. (tons/yes). - (.00/.0 Uncontrolled mntrollel gahel 0.00 0.00 0.00 0.0 0.00 0.00 0.00 0.00 and 0.0054.00 0.05,00 .00 COO a. 0.0 0.00 0. SOO Section 06, ulat Sunsna Anal xeyulatlant 5•4100.0.41-ezeptai prwkkd in paragraphs 2 enough a below, no owneraraperzmr old source seal amw«ouse rheemhsbn Into Me amwpbeee of am a4 pollosncwhIch Fs. mese CPR opacha me stn.. Sleazedon24 mmcuC.e opatlgreaii. teisnacissemna in0rwb NrsIXMnures.iheappr«eir-,wear tatrnethod« a smeasuremen car, 0od5(00aR,Pertn0.nppmalxsBury,ss3zpio wsunsecawm u secwn 11..0 and Bal. regulation. Castles x 115-4.5ss keleHare or Peres for Se mmbslbn orWate Gases H. owneroropmtor of a smokelesshare«atlrcr Aare for the combust. of waste gases shell Slower cause mvecurNe entIsSam IntoNeatmosphere any air pollubntwhlch b In excess 0130 apesckyfora period or periods aggrepCng more than six Mnu.Nany shay Simulation 2 - - - Section Ilk-Nobested earl cause or allow the.mission of odorous err con.Mnanefrom anysInele murcesuch a m result. ae0ctable atlas when are maser. in excess arena .sh.Ilmlh: Fa ominantly for redden, comm..or comryrpaes Mee..kwon llodoes are detected after the odorous al diluted wath sevenMor estev...c.dr freed... Inbn3 requited tor: each NdNBual eMw"on pain. a nw.amm meat area with uncontrolled actual emksionsof one ton per yearor more denymaMauall criteria ponutent(pawonts are nataummeal far WO meereek anaminmene . ppplfoo Isnquinea mina an SPexsim eMsdwmed itonperycervacRep Part B —Oaretostion Pend umnpd0o .Polloentti rtes.:dm.eWn a pemYtsIsm uncontrolled vacenassions from N4 raalttyaregrtater Nan Ne2L. SreeS0.1.a...3,Partn.5eurn lLo2a) • xsrstu Accorelksgtoe50.69o(drlas provisions oft .subpart applvtoes. affected fealty labntaled In paragraph (a) oft. mein whldrmmmem mmmeNonor aeeletee 0eaructlm.k.rtb0 �4,eMon or Wore August2a,2m1.=me sweetnine(eminel unet et,.nmHyarmmmrwvr result enel em esw«mmns atone not wm7«tenthlssubpar, HePs0000 SUPS 0000 epoffes to arnInesweetenIngunlo that were constructed, modlned, or reeonswctm after 003111 and on or xfere 05/14/15(Seegeas360I.mtsamme unit veSI commence canes wean[( taps pow. unto. setwere censer... m..me.,orrrrecolntbuctle0 anis- /1V, us amine vmtnocommence mmtrucdanatter 03/2./150 aresult, N5P50000. 6epplbble to the muss m4ws3Bselgl(31'Taama eachave adesten capadrylas Nan Clone the perdey(LT/ol of 'Nampo sumie(H2!) In the acld gemeap mmrlare repulsed to coyly wkce ith pingand reportrnarequirernent5 specified fn 460.s473aM eutere no«eq....mmS,StS 4460.5005, Nrauen 005.007e wW 4.05vmgd 6 (ano54154J. TISs sources. have a design pedgftathan 2l«g tons/daynain dm sod gas based on Os Informatine s...el iothaPVBob'an. Pnb source senlbe requited try n.r a(clm the lee of the eq p analysistan alanalysisdemonav g ductile facility, ire descapacity .less than 2LT/0 ofx25 expressed as salts. No oue squ.nsnOappN Based. the process sInsiedon In the application. the gas prrcased by the atone°WI will potentially contain 0.0300.H2seaaed on thkconcentravan the Ptoeax slmultrion resulted In tool H25 emissions 0,15.75 tonsheer in Mensl back and sdll vencweste gas sbms.ine tolbwgng demons.. Ne conversion of tills value. parsley: (18.75 tons H25/year) a (COM Ilea/tonl11long ton/22401bs1e(syeaeA65 days( =0.0,55 long.. H25/day inb calculation above demonstrates Se amine unit will have a design caw./ less Nan 21ong loos/allolxX Was• theextended sour gassample used able Process model sitespMSC and cowithin a year ofapp.,.sub.,. If -no, the pemttwal Dann en Bnldil mmpllarce usdce regmrenentm demonstrate comp once MN en.. fns Dos Ile company request a control deka efflrassygresterchan 55% fora Care or combustion del., ves Mapes...11 sultan and InItticompllencetstconditon to demonstrate the daductlon &Seen, of Ifie combust:1On cloaks based On Inlet and OUdetennantratiOnSienplbg Soaks 00-Technleal Analysts Notes ,,, daesno anewpat randan5Rsee _ __ ulapamrcwaaeim t I 'rand M08rthamNteetid0em€wa„en oTZemdelseetteam tee — 'arrc ucdo n ydmwt e7,liv '..,h hen'TeT, tbepen tto ea ems am i argonhees de ,sheerr n Ins e e, meek <. m semen ace, [thy bu cam -gthq pm e.dlns mmaysae3rds ifus.uvpom the ascot ersxem.caluia , ncem ssionx emswtsere.sre ywmxz reS?a an sSahxir«tietarYyymvldes p.maep,:me.a ransated elk rStalCuid the prea. aryl an bvents. oa q,'ed Ndemonsvam rice therm =mrelzu pa achieving e ryw}gntonue ling N u pmt eaentn sseasIsevssaued kr Nester e nveiamyPs usee'nen vI a aormubeonare ¢spnonc. nsae tl wtcomClaui ngwb.regu: .asters«' .p=ee--ane:,seainte Mau mu aa0n-m sraiexhe vermtmnt misn ova Nae3tl a 7. WhIle sulwM1t acondenser paor lobesg routed to xspr medY lie,' v orawtcmm [ rantl w A o rdfd' w innP ere required o -� g2 - sNI cagedNay) d -0W0a nun cbe (01 ed m oaade Swatlala0.As a ruskacfse mthsv5P5xapce ace nos, to v im [hoaw Oaf -appgc on tls alseutses red savesxom seam ace use sug Sears...heaaa intorme. masua0w,saneneanet neap„vin xti czszm.r. fo samednga .from meemre emus., it yluneres4ma acs. Ss [op0ead reh3en ttcp _<h em soon (.m mexm • �a;.aorsMBmm .eateexharaessed ender °cone awe m . mr 6 . op��tur,mes0 ssaatu/IsluaterisaussSnss ao eatian underSointba.7 ,...S1 se-e,eat tar m, reeouer.. • orrUrs unitkequwptiwith i@e OnM two pumps given erns Tis rel. pures sil bussed ass oacksp I . hffa .rte WOW. 502.f 100,,ads 0Dtlned l ton Jbian ,5 Wed on Cassese aonNK smoke. zit 0n.theam .ga swee_neyprocess with no oirur s as p ctp Hf itoefm th I f ''.'-F ed'"I'-'077.7 - Yh Y h' gN g M t tslun be wow', 5Bsme. r,01,/10001 20 bko 5540 aEwurg rpruosca ear pp no the bp vrrmaalbe xz an c/ INer' o! OnA0 01 y'd mgth Mneanmrs OpoOA clod 4snguws:va ua doe 'so fa.«cquedo 'mauls, Na SO2 u0. maorst ode tkws302F (.685)•(00004)..o274injMM Igzs processed leeks,/be thatraamoacemmssa Katdre502emBs(a�F3dt otstliwbo ore x13 the aiasas stream vmnrertea arinanaad3 • ea.lesSeradoraand that Os z eeterangpasss removes_OS dead 14.in the. mr -e based - .n ax -camp :r0. stud repefana a ga.en;iyea - ream -u unrnr..,a� -w " l mvnuzea rwo-xtema:W;s -:.. rte 4.5,,00 w,. _ SCCCode 01 m4i0n nu- Inventory a0e Coding end [missions Faaon ail , Uncontrolled Polkdsrrt Emissions Factor m mwvl CVO] MO. VOC 0.0 CO 0.000 Benzene MOM To luene 0000 ge MOM Aden. SOSO n-Hesene MOM Z24TMP N25 0.000 oln erol eon mlvpl ralvrol mlvrol MOIV/Ol /4011/01 leDIV/Ol No XOlvpl Unks ed Mss MMsef m/Meter e/MMwr tle/herlscf bNS scf y/ b/MMsf b/Mess! b//00x1 b/MMxf b/MMSci /BANS, Controlled IVY Hydrocarbon Loadout Emissions Inventory 013 Liquid Loading 'Facility. AIRS ID: MBEFE,AtillAMODIamkti Plant Section 02- Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Is this loadout controlled? Collection Efficiency: Control Efficiency: 71.25 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 (661) per year Actual Volume Loaded While Emissiohs Controls Operating = .�1,'j" Barrels (661) per year .5'.:60:M.R80.36.5' (bbl) per year Requested Monthly Throughput = 33121 Barrels (hbl) per month Secondary Emissions- Combustion Device(s) Heat content of waste 3713IP) 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 = Barrels (bbl) per year I- Oxi Btu/scf 768458 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? Are the emissions factors based on a stabilized hydrocarbon liquid sample drawn at the facili being permitted? Loading Loss Equation L=12.46•S'P•M/T 0 MMBTU per year 2,829 MMBTU per year 3,394 MMBTU per year site specific stabilized hydrocarbon liquid sample must be provided to develop a site spegific emissions factor. Factor Meaning , Value Units Source 5 Saturation Factor 0.6�';`,,.�� P True Vapor Pressure ,,, ,,;-9.06. ' {'' pia M Molecular Weight of Vapors „".74t&X8' ,"I Ib/Ib-mol T Liquid Temperature r-- w29167, Rankine L Leading Losses 9.549591473 lb/1000 gallons - 3 0.401082842 lb/bbl Component Mass Fraction Emission Factor Units Source Benzene 0.0044.1040 lb/bbl Toluene „ti0W0763r4 16/661 Ethylbenzene .,; 44926 lb/bbl Xylene ,, ! 3 , � aI „ c.ii 055 6 lb/bbl n -Hexane ...:...... 0.0769:29-git lb/bbl :.-, 1,l„lii 224 TMP ? ... -..' .': _- 0:0004o4384mjk''. lb/bbl 9'v' ,.,, ',% 0 388272582;': Emission Factors Hydrocarbon Loadout Pollutant Uncontrolled Controlled (16/661) (16/661) (Volume Loaded) 1.12E-01 6.59E-04 2.20E-04 1.29E-05 3.55E-04 2.19E-02 1.16E-04 (Volume Loaded) VOC Benzene Toluene 3.88E-01 2.29E-03 :I 7.64E04 ".,,3).M.!32 4.49E-05 _..,._ _.. Ethylbenzene Xylene 24E-03 n -Hexane 224 TMP 02 Pollutant Control Device Uncontrolled (16/MMBtu) Uncontrolled (lb/bbl) (Volume (waste heat combusted) Loaded) Emission Factor Source Emission Factor Source PM10 PM2.S 500 NOx CO 5.40E-05 0.00E+00 0.00E+00 4.93E-04 2.25E-03 indicated on APEN lb/hr 0.102 0.034 0.002 0.055 3.398 0.018 17.285 Point(s) 015, 016, 017, 018: 13 of41 K:\PA\2018\18W E0777.CP1.xlsm Hydrocarbon Loadout Emissions Inventory - Section 05 - Emissions Inventory - Potential to Emit Actual Emissions Requested Permit limits Requested Monthly Ilmits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tans/year) (tons/year) (tons/year) (tans/year) (lbs/month) PM10 0.01 0.00 0.00 0.01 0.01 2 PM2.5 0.00 0.00 0.00 0.00 ' 0.00 0 SOx 0.00 0.00 0.00 0.00 0.00 0 NOx 0.12 0.00 0.00 0.10 0.10 16 VOC 90.85 0.00 0.00 75.71 21.77 3697 CO 0.53 0.00 0.00 0.44 0.44 - 74 Potential to Emit - Actual Emissions , Requested Permit limits Hozardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (Ibs/year) (Ibs/yearl (Ibs/year) (His/year) (Ibs/year) Benzene 1072 0 0 894 257 Toluene 357 0 0 298 86 Ethyibenzene 21 0 0 18 5 7€ylene 578 0 0 402 139 n -Hexane 35720 0 0 29766 8558 224 TMP 189 0 0 158 45 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit RAC)- Regulation 3, Part B, Section III. D.2.a (See regulatory applicability worksheet for detailed analysis) The ioadout must operate with submerged fill and loadout emissions must be routed to Hare to satisfy RAC). Section 07- Initial and Periodic 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 Section 09 - Inventory 5CC Coding and Emissions Factors AIRS Point # 013 Process # 01 SCC Code 4-06-001-32 Crude Oil: Submerged Loading Normal Service (S=0.6) Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons transferred PM2.5 0.00 0 lb/1,000 gallons transferred SOx 0.00 0 10/1,000 gallons transferred NOx 0.01 0 10/1,000 gallons transferred VOC 9.2 71 lb/1,000 gallons transferred CO 0.05 0 lb/1,000 gallons transferred Benzene 0.05 71 lb/1,000 gallons transferred Toluene 0.02 71 10/1,000 gallons transferred Ethylbenzene 0.00 71 lb/1,000 gallons transferred Xylene 0.03 71 lb/1,000 gallons transferred n -Hexane 1.82 71 lb/1,000 gallons transferred 224 TMP 0.01 71 lb/1,000 gallons transferred 14 of 41 K:\PA\2018\ 18WE0777.CP1.xlsm Hydrocarbon Loadout Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and a - APEN and Permit Requirements Source is in the Non -Attainment Area ATTAINMENT' .. - 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section 11.0.1.4? 2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, PartB,Section 1[11.07 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude -oil per day on an annual average basis? 4. Is the loadout operation loading less than 6,750 bbls per year of condensate via spash fill? S. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 6. Are total tacaity uncontrolled VOC emissionsgreater than 5TPY, NOx greater than 10 TPY or 00 emissions greater than 10 TPY (Regulation 3, Part e, Section 11.D3)7 You have indicated that source Is In the Nan -Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section hLol,e)? 2. Is the loadout locatedatan exploration and production site (e.g., well pad) (Regulation 3, PartI3, Section 11.0.1.1)7 - 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? 4. - Is the loadout operation loading less than 6,750 bbls per year of condensatevia splash fill? 5, Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 6. Are total facility uncontrolled'VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 30 TPY (Regulation 3, PartB, Section 11.0.2)? 'Source requires a permit 7. MGT- Are uncontrolled VOC emissions from the loadout operation greater than 20 tpy(Regulation 3, Part B, Section 111.0.2.a)? 'The loadout must operate with submerged fill and loadout emissions must be rotted to flare to satisfy RACT. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is rot a rule or regulation, and the analysis it contains may not acolyte a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations; and Air Quality Control Commission regulations, the language of the statute or regulation will control The use of non -mandatory language such as'recommend,' "may, 'should,"and "can/is intended to describe APCD interpretations and recommendations. Mandatory terminology such as 'must' and 'required` are intended to.descdbe controlling requirements underline terms of the'Clean Air Act and Air Quality Conhol Commission regulations, but this document does not establish regally binding requirements in and of itself Soto next! Cote' quest • The loedou Section 01- Adminstrative Information 'Facility AIRs ID: 123 .9£db%` 014; County Plant Point 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 Compressor Blowdown Volume= Requested Compressor Blowdown Events= Actual Compressor Blowdown Events= Actual Gas Throughput=. Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput MMscf events/year events/year 0 MMscf per year 3.33E-01 MMscf per year 3.33E-01 MMscf per year Actual Gas Throughput While Emissions Controls Operating = Section 04- Emissions Factors & Methodologies Emission Calculation Method EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10 - Displacement Equation (10.4-3) Ex= Q*MW *Xx/C Ex = emissions of pollutant x Q.= Volumetric flow rate/volume of gas processed MW = Molecular weight of gas = SG of gas *MWof air Xx = mass fraction of x in gas C = molar volume of ideal gas (379 scf/lb-mol) at 60F and 1 atm Throughput (Q) MW 3.33E-01 MMscf/yr Ib/Ib-mol 3.80E+01 sd/yr MMscf/d 28.7 0.000911737 mole % MW Ibx/Ibmol mass fraction lb/hr lb/yr tpy Helium "f .. ,,,,,..,0.00 ' 4,0025 0.000 0.000 000 - 0.00 0.00 CO2- 2.588531297' 44.01 1.139 0,040 0.11 1000-29 0.50 N2 - 0.134634206 23,013. 0.038 0.001 0.00 33.12 0.02 methane 43.95826526 16041 7.372 0.257 0.74 6473.19 3.24 ethane .-25.73081253 30.063! 7.735 0.269 0.78 6792.18 3.40 propane '--.18:50137397 - , 44.092: 8.193 0.285 082 7193.84 3,60 isobutane 1;73420488Y ;; ;:;:58118: 1.008. 0.035 0:10 88498 0.44 n -butane 4,1;20418991 59.X18 2.395 0.083 0.24 2102.69 1.05 isopentane 5.483508475 z 72.114 0.349 0.012 0.03 306.16 0.15 n -pentane : 0467186002 - 72.114 0.351 0.012 0.04 308.49 0.15 cyclopentane ", , ,m 0436574032 70.19 0.026 0.001 000 22.52 0.01 n -Hexane .>,f.100089472 `: 86.18! 0.086 0,003 001 75.74 0.04 syclohexane 0.00815235 84.16: 0.007 0.000 000 6.02 0.00 Other hexenes ..0 86.18: 0.000 0.000 0.00 0.00 0.05 heptanes 0,012832793 '.. 100.2k 0.013 0.000 0,00 11.12 0.01 methylcyclohexane 0.002960767 98,19'. 0.003 0.000 0.00 2.55 0.00 224-TMP 0.000768425 114,23'. 0.001 0.000 0.00 0.77 0.00 Benzene 0.906133$44 78.12-' 0.005 0.000 0.00 4.21 0.00 Toluene 0.001567117 92.15' 0.001 0.000 0.00 1.27 0.00 Ethylbenzene r; ,,,£.59302€ 05 :.! '106=171 0.000 0.000 0.00 - 0.06 0.00 Xylenes 3„ l:I:lL r',, 0.00 'l r' 105'.111= 0.000 0.000 - 0.00 0.19 0.50 C8* Heavies 3,,, i kn 0.00 r �a3 X14 - 0.002 0.000 0.00 1.65 0.00 VOC mass fractio 25.5770 MW 28.730 Total VOC (Uncontrolled) 5.46 Notes Mole %, MW, and mass fractions are based on a representative gas sample Emissions are based on 24 overhead compressor blowdown events per year. The MW of C8+ used for calculations is based on theoperator designated value of 114. This is within the expected range and therefore acceptable. Section 05 - Emissions Inventory Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 455.09 lb/event 22.75 lb/evend 5.46 tpy 0,27 tpy Gas Analysis Benzene 0.175 lb/event 0.009 lb/event 4.2 lb/yr 0,2 lb/yr Mass Balance Toluene 0.053 lb/event 0.003 lb/event 1.27 lb/yr 0.06 lb/yr Mass Balance Ethylbenzene 0.003 lb/event 0.000 lb/evert 01)6 lb/yr 0.00 lb/yr Mass Balance Xylenes 0.008 lb/event 0.000-lb/event 0.19 lb/yr 0.01 lb/yr Mass Balance n -Hexane 3.156 lb/event 0.158 lb/event 75.74 lb/yr 3.79 lb/yr Mass Balance 2,2,4-TMP 0.032 lb/event 0.002 lb/event 0.77 lb/yr 0.04 lb/yr Mass Balance Section 06- Regulatory Summary Analysis 18WE0777.CP1.xlsm AQCC Regulation 1 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. AQCC Regulation 2 Section I.A applies to all emission sources. "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." Section 07 - Technical Analysis Notes -The operator aapressed that to demonstrate compliance.with blowdowo permit limits, each t vents .k y t a'emissiomfactoc provided in the notes to per`rnit holder ((b/event). This supports n event will be sf an event bas corded and emissions will .be estimated, by multiplying the number of cess limit contained,lii the permit .. - Permittee has conservatively estimated blowdown emissions.:8iowdewn event limits as requested are considered conservative. 18WE0777.CP1.xlsm Natural Gas Heater Emissions Inventory 015 NG Heater . Fadlity AIRs ID: County Plant 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-OriControl Equipment: One (1) MMBtu/hr One (1) natural gas heater(s) (Make: TOD, Model: TBD, Serial Number. TBD) each with a design heat input rate of 63 MMBtu/hr. Each unit is equipped with low -NOR burners. Each unit is an amine regeneration 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 = No add-on control equipment Low. NOR combustion system is considered an integral control device. 63 MMBtu/hr u/scf rs/year hrs/year 551,880.00 MMBTU per year Actual Fuel Consumption = 541-06 MMscf/year Requested Fuel Consumption = 541.06 MMscf/year Requested Monthly Throughput= 46 MMscf per month Potential to Emit (PTE) Fuel Consumption = Section 04- Emissions Factors & Methodologies 541.06 MMscf/year Emission Factors Natural Gas Heaters Pollutant Uncontrolled Uncontrolled lb/MMBtu lb/MMscf (Fuel Heat (Fuel Combusted) Consumption) Emission Factor Source PM10 PM25 SOx NOx CO VOC _.... 0.00745098 " 7.5 98 7.6 2.1151235 0.6 0 u'4 0.96nO 50 - 3.052352542.2. 84 0.0O53y2357 5.5 Formaldehyde 254E-75. : 0.075 Benzene Toluene n -Hexane 058S25--06 0.0021 -0'... 0.0034 0.005764706 1.8 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 NOR CO VOC 2.06 2.06 2.06 2.06 2.06 349 2.06 2.06 2.06 2.06 2.06 349 0.16 0.16 0.16 0.16 0.16 28 13.53 13.53 13.53 13.53 13.53 2298 22.72 22.72 22.72 -22.72 22.72 3860 1.49 1.49 1.49 1.49 1.49 253 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) Formaldehyde 41 41 41 41 41 Benzene 1 1 1 1 1 Toluene 2 2 2 2 2 n -Hexane 974 974 974 974 974 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 1, Section VI Based on the requested emissions and emission factor, compliance is presumed. Regulation L Section III & Regulation 6, Part B, Section II Based on the design heat input rate, the source is subject to Regulation 1 Section 111.6.1.0. and Regulation 6, Part 8, Section ILC.3. Based on the requested. e Regulation 6, Part A, Subpart Db, SO2 Standards Source is not subject to NSPS Db. Regulation 6, Part A, Subpart Db, NOx Standards Source is not subject to NSPS Db. Regulation 6, Part A, Subpart Dc Source is subject to NSPS D0. Regulation 7, Section XVI.D Source is not subject to Regulation 7, Section XVI.D. Regulation 8, Part E, MACE Subpart DDDDD Source Is not subject to MACE 00000. 18 of 41 K:\PA\2018\18W E0777.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 / NAN5R threshold for NOx? If yes, stack -testing should be required for NO0, as well as for CO. Is the operator limiting their heat input rate below the design rate? If yes, stack -testing should he required for NOx, as well as for CO. Is the project close to the 5 tpy modeling threshold for PM 2.0? If yes, stack -testing should be required for PM 2.5 Does the company use AP -42 emission factors [or more conservative factors)? Ygs @ 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 - Technical Analysis Notes Section 09 - Inventory 5CC Coding and Emissions Factors AIRS Point It Process It 5CC Code 015 Uncontrolled Emissions Pollutant Factor Control % Units 01 1310-004-04: Industrial Process; Oil & Gas Production; Process Heaters; Natural Gas (MMscf) PM10 7.00 0 Ib/MMscf Burned PM2.5 7.60 0 Ib/MMscf Burned SOx 0.00 0 Ib/MMscf Burned NOx 50.00 50 Ib/MMscf Burned CO 84.00 0 Ib/MMscf Burned VOC 5.50 0 Ib/MMscf Burned Formaldehyde 7.50E-02 50 Ib/MMscf Burned Benzene 2.10E-03 50 lb/MMscf Burned Toluene 3.40E-03 50 Ib/MMscf Burned n -Hexane 1.8 50 Ib/MMscf Burned 19 of 41 K:\PA\2018\ 18WE0777.CP1.klsm Natural Gas Heater Regulatory Analysis Worksheet IV.2a mitnras...rata. u daflnadW Nan 0b&Deana/orfa deatairedn burnwalenznma W00.22 MOM Monde sg,bonax trtiA*!TEN and .ntvmoa odremer. AIIAItldENI I. unamtrollad vual.WS.wad, ante. pollutants barn d5NMNdmfzoura geat...21 r¶tegulatrona, Parta,se<tarn ll.o.v)2 2. boo veahatgn Ilea' rtrn ec,. tos.1.101 /h,(gec.atmns. Parts, nosatonlla.l.kl . 3. gn Matlnµtatelessmm�mqua1to10 MMau/Nr? (wgWatlon a. part a,svtlon lt.P.1s.) a. aretetal(ad.,'uncontrolled vaeem(uiom gtvxrt.nsirr.rvagreWvdan 1DIPI arao enbnetsgreater [Han 10 WVIweguboona. Pan B.smtmg:o.5) Are uncontrdled emisslonsofanyrntette pall antsimmn.pat tills...dualsouer.onlirf(geguA lationd.wnsattonll.Delan? ms deFvty M1awatleslgn Fot Input ratele5stfan orgia1to5MMBtµNt (Regulation&. Parc2 s¢rm II.D.v.k:) 3 Dom the heaterFavea deagn hutonatrate less than nreq.101nMMatnm,: (gegnlatta3. partg.5a�twnq.P..�) 4. Arc to1.11 facility mcoarralled emea m ereatemanam.. No.gream01 IPYormemlrrmna greater than 10PT wegd..=3,Pa2B;sertlortlln:v IS.requlme.Om. Mande lieeulatlnnL saiun vl ares. .neat per day?(pe .asa.l � I� anat. and emmdenMee ,compliance kosmumad. s wnv,.a,-tmNamnumbe smcn,vt..sandi. q®dbapng, aa,riag, oaa agent.- mb.Wo baulm'ona srstonllnaed°Moram wrvlmbn a van o-semian It StiNar. Partermano.kr raw Fwl.Burdne FouYnmadt 1. What Ign Feat enM rate of the Karen(Ileguhnony5mIon I IA and Regina ton e, Pat B,season 11.e1 Povttheswi«dizdarge par pmmmv Inatom of 0516/Mmbtu heat Inp2t2(2aga,m1,se-non IIIAIa.a..2..rma,Part a, sad. 2.c.2a nrmlate matter lneeaessofthe following quartet:PEaoS(Flt-.2lgegulaion 1.5evlon111A.ldand aegulann s,nrt 0, section 11.14. a, nest 0.11b/Mmku heat Input?(gc[Wanon 1, Se IIIA1.e) 'compliance de d o, tbozowaroub(eaxiRagWa onasmon ntAl.ea xagWauaos, pareasvtennr.ea.emdgnW. q. der, pesmro yyyl do geau(auoni sat.n gvt.o 2. lathe natural gas fired Fearer 'mated at an anlM 622 Is dasiffed asama)cr,mrmeofNat. acted In Regulation 2 wean 222,2.2 (aasaation Sett.XW.D.2.) 2. eat wrts.oxequal to orgivterthansipfi@aeulanon 2 section gw.o.1.) the natural reeo mataWma to..11on i.sammn XVIO. gars NSPS Analysis Nheat (vaeeaetuyFr121§BBao<pl) 2. ones anatural aas atheanmaxlmurn mxlmian Wow,12333Ma Input anan.grvler..zsmaawatts lMw) RaoMMatudd2(2224Wall tea cril. Part a subpart oe standards at Padarmanetarsmall IndumtaFrammar.ml.lnatlewanal steam aamn'Nw POI 1. Mel cons-M.10n,and , No - Subpart §sOAee Atwrnneadlgemrdbeglrmqqulremeeds Bend an .4 recp.ma.tl amnions mg an.slonfsater, compliance Is p.a.... and& ngaxM amtutan fangr, mmpllaroe B.praeuna, burro is rot eubmotto MPS0 '3.sulaav 452204. Part stand.rdzatP•rferrnmafortbuarid.eemmerieH,.attaml,toemGonamalattMa amtlan or rmetm.ladmesonm genera, lank coamaa...a 19,1984, (460.40451 inawnm dm ooathe,saneatpsn,ea heater haw poemkl Sox miss. raed.40 /i(03x14/Watui heat Input ark.? 1560:Mmry1M11 a. 46th.a.e.I Nnycommenecomtruct. reconstruct. ormm'motbnafter Feb -La 2B 20a. (woaxaktl.11 4. NokStorclords Ma eapa=Oy am MWp50MMmangnrlma,(550.444(gl 5. Do. e the MaermNeaml heater loll Ine onwx(46o.eaepll 5a, combust, alone or In mmanela, only won,q.a. arulgauml,aredml ell.u1. nttmga content d ax welgM percent or ksel...M 11111, 54. wcMfveard 10 parent r les for natural gas, dsallateal. and residualal.Ma nitrogen content ofn30 weght pe.em riers(560.4440)p4 aM wtwo toafmneallenf�aerecal,enathmr�ne.paatlwdtheamaeafadllntomendngofnaturalga., dradlate,n,ana�residummwrma n,mRnmmmtdp30 eir,. peones alas and llmlting°pentla ofthearteudfromyma coma,. anmal npaNy factor dxa paatrless frnal.1 gas,detpkte o4; and residual W.4a nitrogen 00077 Perm. or leas.l§so.44410n 6. Oldtheaffectetliaallryoanynercemnstruct., re r.rw.lon or modnotimafterluly 09.19977 060.4.112(1)) naval Baffled heater a mmp subject andln lance with fwealNedorm5kmwkenee twt karts opuatbnd d,efaoxvta an annual opacity ectd.0 percent (0.1.0)..5 td 7. maLm.ardaturagaspam=rnigna1adt...n, (450..6(11P1) 5. lFwmkatheratural gas (454.44a1Xi11Itrei here Nw taw wt ',dame rate and....rat dkalaeo¢m ex.,,30percmInf.M1.1nput ma 60day mill, avenge from themmdana. of all v.. las n,...oss §fiOA4WM4l-sdarafo.aufredlode.15m1 400.44614) so il) or III:I4) ..1 M 47111.4erd.41 ran 450457 mans 10771 560.455-compllaae and p.domance. ...ads and proceduresf partial.. motor lad nttro5enodd.4 560.475 -Emission maaedngbramw dioxide §60.M6l•Me mederingbrp ram,. meM.end ntmgen odds p aped. n.pardB and r.m rdla.ping rn dmmM MAR ',lab/. 40 Mt vet 65 Solon. MAR OPPPP. Nsniu, Mvbrsauna= hdwdal mmmerd.k and Immubnaleoll.maM Prey Welders 1. Is thelleanr bated at fawtnhat is a maps soufor 4 n1Y,54145 (4+5) 1pm.nrrwon (463rz amRI) a am pwnon (453.x4 W jell d beatctmnmem anoluue M, x010, <he Ness lrrpu mw sty less dun a eqml m s MM etulhr,1553.x5401d1 4. bile Mm4M5utimstMnrmualmxo MMMuM,165..,5w1A1 16 rotas.. MAR 0.0006 455.x5ao(al andiaae3-Work pratdeefurdads 453.x4441.) -General uwa 5emel 56..,5141.1-1ni.41,,,emene formlattng noniron oa 65.,510 lgl to new soured 553.751.5 NI -Subsequent testa, fuel analyse orlune. .3.75304 enc115-oslelcompllance 44a,x5451.11eol and [al.,-orno,.nuaunvmmsuom compliance 4.3.7545101. I1,e ne.I.1.1r1e1111.e1e1..n6.161-xdEetam §44.x5551.1, 15411.1= 111. Mal �a 4..455(u1.1a1141.Mlxl and 65356(151,141a l a.mrdk..q.a Tbk document assk6 apealora will detmrcdng epp4a6,byNwrb6 requkemenls albs Clean..Ad. ifs >npbm.n1174 repa6l/axs. ass 04Ouably Crub0l nnguIslons. ink docum0,4114 warul6Qregulalba, and lna ane/pis may sof apply to apo4.v6rs4wt0Mb n Lased spanldrvsd4alfacts and rhea This discussers, doss 445400010-5740150.notn's-,s546gm. ran sMes. 4ydndvg requirement end ndkgalry enforces.. In Ms event d'any coactlelsesn the language dims d1cummtssetss 67754x9. dine Chan4(Ad,.. 100 Implenerllbg5onu1liv.M, and AYouallry Control Commission regulations. thelanguage 71 the statute cragu6h'o07711 con.. The used non -mandator larg1aga such as "recanmna" ehey.' hou00,"54d"e5C Zed 5 4504047 APCDMlerpreteli004 aMaxa0ana.dahaw. Mandalay I4 indogy such as "mus0 at.Yequ>w ere Intended 6dazmbeconbdb44 requtOmenls under the leans &Me Clean ANAat end ArrQuehly Conbol Commisakn regu6Namr, WHS. document does not es004sn legally aM6gaxylemenis tti as i.ret amleae M.T.. Natural Gas Heater Emissions Inventory 015 NG Heater Facility AIRs ID: Coun a Plan NPIVENE Point Section 02- Equipment Description Details Heater Information Fuel Type Number of Heaters Purpose Make: Model: - Serial Number: Design Heat Input Rate: Equipped wilt Low-NOx burners: Equipped with Add -On Control Equipment: One (1) natural gas heater(s) (Make: TBD, Model: TOD, Serial Number. MD) each with a design heat input rate of 17 MMBtu/hr. Each unit is equipped with low-NOx burners. Each unit is a molecular sieve regeneration heater. Detailed Emissions Unit Description: Emission Control Device Description: • Requested Overall VOC & HAP Control Efficiency % No add-on control equipment 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 = Low-NOx combustion system is considered an integral control device. , 17 MMBtu/hr 10200. Btu/scf 10 hrs/year ihrs/year 148,920.00 MMBTU per year 146.00 MMscf/year Requested Fuel Consumption = 146.00 MMscf/year Requested Monthly Throughput= 12 MMscf per month Potential to Emit (PTE) Fuel Consumption = Section 04 -Emissions Factors & Methodologies 146.00 MMscf/year Emission Factors Natural Gas Heaters Pollutant Uncontrolled Uncontrolled lb/MMBtu Ib/MMscf (Fuel Heat (Fuel Combusted) Consumption) Emission Factor Source PM10 0.30745098 7.6 PM2.5 508 0,000588235 0.6 NOx CO VOC 0.00745098 7'.6 0,0:79019608 50 17$2352941 84 3,,3.0005352157 5.5 3 1352.4E-05 0.075 F .12.65882E-06 0.0021 Formaldehyde Benzene Toluene n -Hexane :3E--06 0.0034 701 1.8 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) (tans/year) Requested Monthly Limits Controlled (lbs/month) . PM10 PM2.5 500 NOx CO VOC 0.55 0.55 0.55 0.05 0.55 94 0.55 0.55 0.55 0.55 0.55 94- 0.04 0.04 0.04 5.04 0.04 7 3.65 3.65 3.65 3.65 3.65 620 6.13 6.13 6.13 6.13 6.13 1042 0.40 0.40 0.40 0.40 0.40 68 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) Formaldehyde 11 11 11 11 11 Benzene 0 0 0 0 0 Toluene 0 0 0 0 0 n -Hexane 263 263 263 263 263 ection 06- Regulators Summary Analysis Regulation 3, Parts A, B - 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 thedesign heat input rate, the source is subject to Regulation 1 Section III.A.1.c. and Regulation 6, Part e, Section II.G3. Based on the requested E Regulation 6, Part A, Subpart Db, SO2 Standards Source is not subject to NSPS Db. Regulation 6, Part A, Subpart Db, NOx Standards Source is not subject to NSPS Db. - Regulation 6, Part A, Subpart Dc Source is subject to HOPS Dc. Regulation 7, Section XVI.D Source is not subject to Regulation 7, Section XVI.D. Regulation 8, Part E, MACE Subpart DDDDD Source is not subject to MACE DDDDD. 22 of 41 K:\PA\2018\18W E0777.CP1.xlsm Natural Gas Heater Emissions Inventory (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periods 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 belowthe 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 fasters)? 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 drily CO, the other should be included as well. Section 09 - Inventory SCC Coring and Emissions Factors AIRS Paint it 016 Process # SCC Code Uncontrolled Emissions Pollutant Factor Control % Units 01 13-10-00404: Industrial Process; tot & Gas Production; Process Heaters; Natural Gas (MMscf) PM10 7.60 0 lb/MMscf Burned PM2.5 7.60 0 lb/MMscf Burned 50x 0.60 0 lb/MMscf Burned NOx 50.00 50 Ib/MMscf Burned CO 84.00 0 lb/MMscf Burned VOC 5.50 0 lb/MMscf Burned Formaldehyde 7.50E-02 50 Ib/MMscf Burned Benzene 2.10E-03 50 Ih/MMscf Burned Toluene 3.40E-03 50 lb/MMscf Burned n -Hexane 1.8 50 Ib/MMscf Burned 23 of 41 K:\PA\2018\18 W E0777.CP1.xlsm Natural Gas Heater Regulatory Analysis Worksheet Bawl on.a honer ptapaaa selection hille %natatory,. unit aae fuel bumhq eguip...parmlgada Regulations,. BB, a mean, g.neaurE nit par tax C11,6,a tada'mit.. 2 eemmordal et. t.Mtu6natboiler aramnm Mww pe per M4'r000o0 'Mauna flags natural au as daltnad byxsys all, Amard/er. dol.,' Wrnq.lfu.b u donned b MAC, WOOD Ixto-ea a,ndrg ebaMmlmre. wu admmetn Arauncontrolladacaualamaskaaafarnaria adgaams Irontitsl ual seam ymnvthanxm(Paydrztma,Part A5wlan11.n.v)i 2 Does ...Awe a trdgn heat Input ratelws da requal WS MMMtWux lPqulamn3, Pan., 5atlmn nnl.b.1 t b M ate lus tban w egrol to 1D MM su(nR (aaga,nwr 3, part B, aaatlon nn tc) a. bet u, bra grmwthan511 ,x greater than1017/ wm.mhnwgmatadanlOlPy aleguntbn s, Part B, Station anal? Iaaatalvaughidarmatbn are r,a,tmciemnslasofanyedena pellrmmcnantnlsbdMdual.uaz greater then 1, {Para..3,Pana,.a.. lla.].a)i Heater lwsea,es lgn haatlnput realmstwnnr equalms MMMru/M, lllegu .11.1 3. Does Ole hater have a design haat Input am less than areawl to to MMBtu/nrr, lgawation 3, PartB,Sanion tinl.e.I 4, Pretistallaaryuacontrolle,a0Carnlaslenaetire,manzmy,No.greaterthan 5my or wvnlavlansgrutvtnananrvy (444ume333,3446, 53410nll0217 1504. reataras a permit Colorado Romalation1 Sad.. Arendfwmuwe anlabmfrom. nmv®eaterthanz tars par day, 0ieggbtbnl,sadon xasa.g wi?�Y,?rn9-iii__ saeean Vial aM> •• 3eco,diaeprc Ra crane Data Ramat. deaf put rate.ftle heatw,(Replamml,.selm I..) Dsb/Mmbtu heat and Magdng4P1.tsd 114,4:. am Regulation s, Pan e,swtlanucl.) 3. Does e darge particulate matter In excess oftherdllmrlrgeguatlanr vF=DsIRl'r 7pegulatbn1,s caan Inz1.6,nd liegulatbn 5, part q Sedren I,rs1 4. Coes-the same dacharav particulata matter Macaad.D.11b/Mmetu beatlnoxtl4eaulatIon l 5attfanlpA1.cl conaallance prawn., Is the natural eastked heater !sated at an raelaydm admimf asa major 'arced Ina as 5stdmReg,latbn'Seaton >3%, wegwtia 759.ral.D.1.1 Dmtlra natural aahearer have urcenralmnmtalemss* axm equal m or greater than stay? W .., 0 salon 11x.0.1.1 semnxxa.3. RmroYcgnebugbn pmm•Adi,aown N5YSAna1ais nalga3Iiredheater ha,aamaximum garnheat Input apacityrdz9megawatts (Mal (lap 0tumrlarlar less, equaItaz.5MW11oMMDtu/hrvls5D.40a(a)r a. Does CaHalune quefired heheater mlafa. a maximum m bola.. beat Input amda Rreataatan 35 megawatts 0.4141 IlW MMBtu/hr111Ka.g015141 I44un. ;,,,west. Nsss u.. subpar, sane.,Prwialaw 334,493' 4933(434 .344 Bemrmsmna gwdameea Sokra Reouitaa no PPM., totmne< quaad.n Source Requires a permit w IEland enae requested Malan and. mitnenr.aaga,nmplmnta annum.. Dazed on the request., mmqursa'¢ anecomed. en Istar, mm mplua prawn..Based an the requaated amimionfxtaa m.plia,ze iayraumed. rme u 42130013*10 49 730 41 Section 3Vl, lee to ewaeamt ',Valle applleabaUn lallys.abl.a.a3axDb. i :;,. <s9=vamlaa,w.elta tax De 4.0 SO-Suivart Stanearda.of Performance for maFlrmdtaroml Stamm mom roxne rin. mhhallon,orreconstmabnd4ms m gneathng unfit commence afterluass,19g4114.0.40b(a)1 4. mng/1(oav h6/mmem)hatI45 lnputo.lea3 0.u614(3)) 3. omtµaffeced encenousw. acnnmmanormdhfradon ahe5ebam28, 20.,620.,6611421.1,1.b ISourcoheetsdalecito a. Does NC.Stardards gas,. heatehaaea heat Input rawenyofT9 {x50 ram9tµnn nrleasi 1450.44610) S. Dees.eheater g6efdaadngamfa21460.4414) - en. momu.e, tom..mmmanatron,nm.neturd as, aldlnare dr,.rrammhal w3ha nrtmgnm,tmcd0.3weeht otmanorlasl4.a...anun: 52. Haves mmbinefannualcapadty farm. of 30 perimeter leo brnatural gas. dralll6teoll,am residual d whha maned) content of 010 werghe perad criers 1450.446410): ana aecxaa/derallyenfarce.a6le,ulremntlrmltlngweanon',tMaffected famryre de frying of natural gas, astelare el,arg/erreslaual al with a N<mynmmertofo30 welg.pexent ode. ademl(mgepeatlondtM1eaFated fadgrymammldndanraal awdtyhaordlo Ferm(orless for nouralga+,dbtplatm0,andretlwlo0whh a Ntmgen mof03a .et percent orIas,14.0.w6411.) C. acghymm o erlupas 9/1§60.446(1)) Isthenatunlgaaredhotefauk, mmphan a ellN enrceaderemr4enent that lrmesaperaden mue(aagryn anano awafy(aanrdl per.. (0.10) ores for Ma �.a (or anycammnale of the rhee.Rl4sa.4411)(111 s: nedheaterhamelmehatreleaeerateana.olnbratnatualoa ord6mlareo4 Mamas 43epatent at.Feat mput ara9o-aayrdlmg,a>agermm theenmbuaeron of all h...1§.ocnell)It) 4apexa4131-standard forauk(edm4a. 140x1 4.0,uaa1 or i ki or ilk (Mandl,' e r m - Coma m (or nhmgen aalde s Isa) 46a.ssm-Comp4.meana wnnm on.test..oaeandoreceduresiersulfur mead 460.4.71, Mau,. menroaamrmraultur am 560.4 )puled end nitrogen oa. 4abaa6 a e mre aoa ammlaaprne.aaroranenn MACT,Analysis 40CF. Pert 53, sulmea Upon 00000.rv5s5hp for mamrswma: West -el. Comm.mal and lredtuvoaleoll.aEnd amma.5amra Is tlxheater 4.malo-mumeforxnpsi 033,4.) gmrwatrLLelb0.o'ut453.,. . on(4.39a9nknonwateammmerceafrttlmea,am0r 3. apadrylanthanor weera sme5urM9(453.'/500(e) 1st... 4. 1st. padry graterthens mmetu/hr6utlasrhan m nn( to 3ommett.e.(4.3.050n(e) a. ttto raacT00000, 4.3.Tsml.l antliable3-wmkpnmasuma. 4...9see (al-aerMequlrements 4.3.o61ab1-Initm mcutrements far ealatmgewrces 6175101g)(erxwsources 443.951. ld1-su4eeguem (dents, fed analyse or.eum 7..7.010.2M -Brtulcamplran 443.05431e113o1 and h110 4, momtr rig am..rumdonce 4.3754.14 Oa--ear(4(14 ere-feraw6(•1.bllil. elal,.nl. ele1-xulncetbm 466.7440141.161.1=y Ml4,a31•..poahe 4a,95ss 1=1,141111 and Wand .3.0s.a lay 04 ..14 14-amdlre.War Disclaimer This document assists aalws with determining app:gildy oimrbe reg4Leme 6 knplerne4Nlp and Air Quality Conbcl a not a,. a-ne84/aeon, and the anayri418 t apply e a part64a upon the end ch... fencees.f This lumen(doesnote/ranges'suealllukhrany/aw, regulation. or olherlagafb 471800requierement and Isr4 airy e8Nrteeble, facts event alary walk( betweenlhe language of this documents', Tillie Clean Ai Act. its implementing regulations, and Av quality Conbpl nnbKe rdalory language such as Yecammerd,"may"'shohhh and 'can: Commission intended14 488 -( be APCO 6r 112412lbne erMacommendationsl144144oy terminology 114, 08100 and rtquirad' are intended todasad»wnbdGng under the terms of the clean Mar./ Quality Gant. Commission reguawns, but this document does not establish legaly binding requirements in nd 3/Lself No The umcnrwterubl4atmmn47.. Gin to next,stiom The source muaeentluaew p nudN. Natural Gas Heater Emissions Inventory • 013 NG Heater Facility AIRS ID: 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-NOx burners: Equipped with Add'-On_Control Equipment: One (1) MMBtu/hr One (1) natural gas heater(s) (Make: TOD, Model: TED, Serial Number, TBD) each with a design heat input -rate of 25 MMetu/hr. Each unit is equipped with low-NOx.borners. Each unit isa 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 contest of waste gas= Actual Hours of Operation = Requested Hours of Operation = Requested heat input rate = Actual Fuel Consumption = No add-on control equipment Low NOx combustion system is considered an integral control device. 25 MMBtu/hr Btu/scf hrs/year „„BOA hrs/year 219,000.00 MMBTU per year 214.71 MMscf/year Requested Fuel Consumption = 214.71 MMscf/year Requested Monthly Throughput= 18 MMscf per month Potential to Emit (PTE) Fuel Consumption = Section 04- Emissions Factors & Methodologies 214.71 MMscf/year Emission Factors Natural Gas Heaters Pollutant Uncontrolled Uncontrolled Ih/MMBtu lb/MMscf (Fuel Heat Combusted) :;fl;30745098 (Fuel Consumption) Emission Factor Source PM10 PM2.5 7,6 7.6 9.6 50 84 5.5 SOx NOx CO VOC j;,•ep0:i7$235294i Formaldehyde 73 0.075 0.0021 0.0034 Benzene Toluene n -Hexane 1.8 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 CO VOC 0.82 0.82 0.82 0.82 0.82 139 0.82 0.82 0.82 0.82 0.82 139 0.06 0.06 0.06 0.06 0.06 _ 11 5.37 5,37 5.37 5.37 5.37 912 9.02 9.02 9.02 9.02 9.02 - 1532 0.59 0.59 0.59 0.59 0.59 100 Hazardous Air Pollutants - Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled Ohs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (Ibs/year) Formaldehyde 16 16 16 16 16 Benzene 0 0 0 0 0 Toluene. 1 1 1 1 - 1 n -Hexane 386 386 386 386 386 Regulation 3, Parts A, B 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 c Regulation 6, Part A, Subpart Oh, SO2 Standards Source is not subject to NSPS Db. Regulation 6, Part A, Subpart Db, NOx Standards Source is not subject to NSPS Dh. - - Regulation 6, Part A, Subpart Dc Source is subject to NSPS Do. Regulation 7, Section XVLD Source is not subjectto Regulation 7, Section XVI.D. Regulation 8, Part E, MACTSubpart DDDDD Source is not subject to MACT 00000. 26 of41 K:\PA\2018\18WE0777.CP 1.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 sequined 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 sequired 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 sequined for PM 2.5 Does the company use AP -42 emission factors (or more conservative factors)? 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 - Technical Analysis Notes Section 09 - Inventory 5CC Coding and Emissions Factors AIRS Point 8 017 Process 0 5CC Code Uncontrolled Emissions Pollutant Factor Control % Units 01 I3-10-004-04, Industrial Process; Oil & Gas Production; Process Heaters; Natural Gas (MMacf) PM10 7.60 0 lb/MMscf Burned PM2.5 7.60 0 Ib/MMscf Bumed 50x 0.60 0 Ib/MMscf Burned NOx 50.00 50 Ib/MMscf Burned CO 84.00 0 Ib/MMscf Burned VOC 5.50 0 Ib/MMscf Burned Formaldehyde 7.50E-02 50 Ib/MMscf Burned Benzene 2.10E-03 50 Ih/MMscf Burned Toluene 3.40E-03 50 Ih/MMscf Burned n -Hexane 1.8 50 Ib/MMscf Burned 27 of 41 K:\PA\2018\18WE0777.CP1.xlsm Natural Gas Heater Ragtdaroly Analysts Warlaheet eeodantM h9mrpurpose selection tn 9199 g4emerv,tN999.49 .laleeeslwl bmnttgequpmnm permlonde Aeryledoml S e, a steam g9mntirgmdt per PISM ebg w end ITtax 4a Peat ...lg. as 919 mdbywsptW&oeertl(orladwgmdte bumps lfwb ed.1k.1bymxr 00000 mlaMaa+oY==uml4 ear "°- 334 ammmmdhiamulengnli. isMstaaI stkanortg999.9tlisl�l990,0,wpenamanirvr(a¢da9.9,9) tt0.5esenll.olali 2. Does thelwales wa ddgn11wtInpnmelacWn34�IteseaMeatuArtgeguhwn3,. smpaIn.vk) 3. 099.i32. h. redden Feat mWtr+telactrt 4ea4Imin MMazu9nrt (101W orc3,Pane,s43bnen1.y 4. zet�1bdgy34dmldyaeanmbm gleat9.w,;:,o..no.natamanlorpr9,6owm.dmnetiaauanlarm(xaguumn3. P.na.sectlw,ll.o4li �Ne ughmw,99 m9 mmanrr 1. Are uconadld erntaal3u of any cmma3dl3Mdmmaheldetdd1 sourxpotertlenl1P1 laegu artns41311.o.1.;)3 2. Dom as tk9 orerualms MMetuthrP plagubtlon3, Pann,Sealann.o.3.t 3. ores the heaterh 34. X199 heat Input np I rate less tka3ar441m33MMatu/TA laervmt13n3.Part4 33ll3no.n.v...l 9. rake u a mgtole1397311,90xereatatbansmym6Demlmuns ,1414339733134 (negwaean 3, 94 13. Sect.,a.o211 fraurce r4quiron 431313 4. k3&aeauldona seeknvl 1. aea day?(aewh 14#1,5444. 49.33..9 �ea.een enaFore ed 4,ee,anloeer, mmpltanea a presumed. 6eda734.asadr amaeepta,ite mnymvaaavmn m m rpNx9.1d whatislhe design Fat Input rata oft,. vi(ReNnl, ati5ee14111wd a and a. Part e,.sxt.11.Cca 6 ) a9.9999.99.99.911schange parkulate nutter In s Ib/Mm4u hot Input? (990.192.92,991999 a d 434349 rt4 6, Part 6, 6343371l.u.) 3. Doesthesourcedulvrgepardalaternantet..ossofthefollowlagequatIon:PE90.59919,9.42(Ragulation1,Sedlon R9Ndtmn6. Pane,5ee4(1ln) g, Does theseurcedfatim rtrollate matte. In etras lv..199 btu Feel uti u n43mxm Regulation 1 so4lan1s u.e #.11zsd� a gu n s. nrt a,soatbnllc3.eood on 9199.9999sted.991a73ga9wr. .9 toe. nuatmaealon. mah.epe9999.49 So. ct ;WNW 8,0rIllit 199 laa>.d3n,m may.x.4.mb33a 4aid a4a.laela 443 COJIIAIMOZnw.aumw. Wanda aervWenr s.elon gyro Istfienatural heaterIcotd at andmngbditythx g dass9.94a malo.nawdN34es usW 1nargnhuenl 5343vgai @9333944775434414oy 3. Den Ahemtural haterhaveummroaldacaemrs a1nlssa4 Nat emoltaorgrnmithan saptila¢Nav4>svl4xa w.vl seam x99.0.3. uvd .. NSPS Analysis 2. pees the natural gasfired heater have; rnwarnurn aeslgn hex Mputmpa44 d3smegawarn(MW)(1o3MMaau/nrl3laa, w<g3alathano ssmw(1a3metu/bl?(§6a.mc(all we 2. Does aheat tn. cepac.9realertM1ani7 megawatts (MWI(lop MMelu/11r1i1663.aablall[[valuate 4417134 n 3335 w94xt.n below, a wbaart3( Nrnd.N.alPerform.w.for71,411 I7? .lepmm.rtI.I-IMltale41c earn 3441at4mLk& v. 3st 333. Ian ofehesream generating rng 479 eommenaherlune6,1D63116co.aodall 'Source,. oublea3o Ns95 w. 494.993.-ae4Nne and pemNYxwrn Requirements baud onN repu.atod emlotpnimtor,wmpina.a pnwencl. Sawa a oat p m ao.Natl.n i, section M.o. Iw3a,anot 9ubp4m NS.PS adman 1. construct., ogtwtfon, or ieoretrunlun of the nom generaang unItcommence aherlune 35.2584? I .4o6(a)l 2. aes.esatmal PaPoe lwaterla4e a potent.; w2 ernlsdon art a 140 nO0.S2lb/MMe.l heat al(460..b(rypll 3. wat rezomtmuw ormce axnnanenrebrwrvae,2arotf46a<zb(dl=1, Iww.e a rot sakiIse. 35PS ob. NENStardazda tiredheater4awa.atinputa aagyt7a M., (25a MMetu h.I orlaa4(46a.446p)) 5. belt.. heatermeetgof thefollawIftgalteria?{45,.*11 paulyfacta>10 pevmor less krnawal ps,dlrnlatewtantlr.ual mwgh a afarogenmmemt,03oweltyteenenter1�1480.4plann); an eano ubjeetae fede rally enforceable equal,ementllmmne opemlon of the a fsthM to the Rang dnatwal gas, W,.Ryas.oll wall a nrtmgen mrzstofo3a welghe ,cenearltes andllmi eafreadfaedgyto. m,binei annul capacity factor p otorlosfans g , utn6t ,a lakwloawnha Ntmge 0.34 m�e4Ia.. 45415262454 5diry omm`geceht m14mctron, raonrtrumonormodmotionmerfuMas. n7(4s0,44g21 Is die natural gas flimi sublexm and Inmmp4ance wama federally enfome.able repuIrement thar elreratIondthe n ann.1opacity fadaof 20 paant(0,0} orless for natural n Ps loracombinationathemree17(460.448(41(?)1 Does m natural per fired heatahavelon hotmlwsente and mmLust,atural gas ordgN6reegln oass d 30 percent efineh l Input on a 30 -day rolling amaze from the m.o.+,.fall e. rags (�o.44n(27zp 4sa,4zaa141•sta,datdfosadfurdfmfae(aoe) £en.540.toralar(gam.namo.l0• ...rdmr24reeen?425i 2448? §60.466-aompo.maad gaammanais. methd.and procedures.. Ru. 0,de 46a.46,[empg.ree and waormar e tanm.Meda and pmaduasfer partl=.clam matarednineemn ends 464A 541588n.ua.e s60acn.w p B.ma rename ai a�w In red MALTAnalysis 455 Part 63 Sawn MAT OW, xsxnPIer Mawr seuaes.Idmeaal.ad Ins...11neers ad promo Heaters Is the mafasaumefo44(P.a(h6a.74es1 3. o?14a44.1,41afo on(565.'4454(tllg3eatermmmenceafter.iune 4. aovof 3. opanty leas than�yual ms MMgtumrt (463.75w(ep 4. lie me heat pN..weenyg,eater than sMMetulhr but less man ens equal. 30 MMetalrr714sa.7541[4n §65.7800 (.1 ane1116k 3 -Work parn-metandar. 463.75051,1-eemal,equireme. 466as4atd-422415u4•mam for asolgsourcesaa ..75.1.0ce u kg, for newseu, .3.7535Idl- 6nbso,wan tats, fuel .Rata...runts 4s.a l.Il(8I. andm8441••845.154 nag mmarwusmmpuance 63.7555152 (g-fondserg era for newl,lal,lal 1,al6Leu1. 8101-aamctbns .7ssc1a201,Ie1.k1142M3iSa.mmre £4 453.7855 fat, lace l ad 121 and 63.75621a1.1,..lrl-a.aNlm.plrw DIsclaimer This dacema.assists operators with determining appl abflay4fttvmk requuemen647444Chan Alt.( ifs implementing regulations, and 454545lity Conbol Carom regulations, 0714 document u ratan regulation. the Mats aconmay t apply �o a deu upon thai1 i,Hatlea f • cirearnstamcay Ms and law, reguklfort a any aNxkgalry -n ngnp uaarenfNa�besact ed*algen a8SNe,l e I be(5'854 the language offlhi4 documentand the 154418554? 48 Clean Ai Ac(, Rs gnplerrentig rgulatbrns, and PX puality Canbol • anyconrgction, the language tithe slatute or tea..., ail/contr.. The use d non-mandalay language such as Yecamnead,"may •should,' and•can• anted to describe AFCC21144 Clean and recommendations. Mandator terminology such as Ia.( and freq.. are Intend. to cloacae con...9 Iquliemmis under Me terms date Clean AnAel and Air Oea ly Coned Commission regulations, Idt this document does not esmbliah legally binding reWuamen. In and dAselt Natural Gas Heater Emissions Inventory 015 NG Heater Fadility AIRs ID: 3n 13Y 3i..₹3d1idi3NICEMBA.... County Plant Poin Section. 02 - Equipment Description Details Heater Information Fuel Type Number of Heaters Purpose Make: Model: Serial Number: Design Heat Input Rate: Equipped with Low-NOxburners: Equipped with Add -On Control Equipment: Natural Gas One (1) natural gas heater(s) (Make: TBD, Model: TED, Serial Number TBD) each with a design heat input rate of 24 MMBtu/hr. Each unit is equipped with low-NOx burners. Each unit is a hot oil heater. Detailed Emissions Unit Description: Emission Control Device Description: _ Requested Overall VOC & HAP Control Efficiency SC: Section 03- Processing•Rate !nine -nation for Emissions Estimates Design Heat Input Rate= Heat content of waste gas = Actual Hours of Operation = Requested Hears of Operation = • Requested heat input rate = No add-on control equipment Low NOx combustion system is considered an integral control device. 24 MMBtu/hr Btu/scf /year 9.';5Ahrs/year 210,240.00 MMBTU per year Actual Fuel,Consumption = _ 206.12 MMscf/year Requested Fuel Consumption = 206.12 MMscf/year Requested Monthly Throughput= - 18 MMscf per month Potential to Emit (PTE) Fuel Consumption = Section 04 -Emissions Factors & Methodologies 206.12 MMscf/year Emission Factors Natural Gas Heaters Uncontrolled Uncontrolled Pollutant PM10 PM2.5 SOx NOx CO VOC Formaldehyde Benzene Toluene n -Hexane Section 05 -Emissions Inventory Ib/MMBtu Ib/MMscf (Fuel Heat (Fuel Combusted) Consumption) Emission Factor Source 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 CO VOC 0.78 0,78 0.78 0.78 • 0.78 133 0.78 0.78 0.78 0.78 0.78 133 0,06 0.06 0.06 0.06 0.06 11 5.15 5.15 5.15 5.1b 5-15 875 8.66 . . 8.66 8.66 8.66 8.66 1470 0.57 0.57 0.57 0.57 0.57 - 96 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (Ihs/year) (Ns/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) - - Formaldehyde 15 15 15 15 15 ' Benzene 0 0 0 0 0 Toluene - 1 1 1 1 1 n -Hexane 371 371 371 371 371 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B 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 HI.A.1.c. and Regulation 6, Part B, Section II.C.3. Based on the requested e Regulation 6, Part A, Subpart Db,5O2 Standards Source is not subject to NSPS Db. Regulation 6, Part A, Subpart Db, NOx Standards Source is not subject to NSPS Db. Regulation 6, Part A, Subpart Dc Source is subject to NSPS De: Regulation 7, Section XVI.D Source is not subject to Regulation 7, Section XVI.D, Regulation 8, Part E, MACT Subpart 00000 Source is not suhjectto MACT DDDDD. 30 of 41 K:\PA\2018\ 18WE0777.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 he 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. Isthe 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)? +r If no and testing hasn't already been required due to proximity to modeling thresholds, testing should be required for any pollutants far 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 - Technical Analysis Notes Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 018 Uncontrolled Emissions Process # 5CC Code Pollutant Factor Control % Units 01 I3-10.00404: Industrial Process; Oil & Gas Production; Process Heaters; Natural Gas (MMscf) PM10 7.60 0 Ib/MMscf Burned PM2.5 7.60 0 Ib/MMscf Burned 5Ox 0.60 0 Ib/MMscf Bumed NOx 50.00 50 Ih/MMscf Burned CO 84.00 0 Ib/MMscf Burned VOC 5.50 0 Ib/MMscf Burned Formaldehyde 7.50E-02 50 Ib/MMscf Burned Benzene 2.10E-03 50 Ib/MMscf Burned Toluene 3.40E-03 50 Ib/MMscf Burned n -Hexane 1.8 50 Ib/MMscf Burned 31 of 41 K:\PA\2018\ 18WE0777.CP1.xlsm Natwal Gas Heater ReNlatory Analysis Worksheet &need ondm Mater Fuqua.. ualealontntbelmarto y, this unit qua. ream fwlbwdr.aqumwm per mlemdo Regulations 1. S.. a meem generating mverREPS D68 I% and j TUN unnfi.n natural a.aes AflnadbyMSPsobam.N/er lada.4wdthumps ituah fade/fired bW V.=00000 mbMom l aurmein tM ��-PPENmmw vn asoanm,m NriaBlumn- ema pull. from. lMNdal serve pataNan3lPy@egdatm3,Part0.5mbnlldblali dmgn teat, Input seam lm thanmwul te5 I M3tuMil.aNhtbn3,nrc0. smlm Nn.Lk7 3. Dues the beater eeslgn ben mien me las than or equal to to MMetuAri IRe,datM 3, P.n., Smim,...1z1 O. Pretantlacl unoardrolleel VOC emissions terthanslm,140x v.3,110171' or CO =fusions Manta -nu/ e latfan3 um. section u.0.3 NaNATTP.INMEIVI 1. trdtel enhuanaoleny cmel.Pdlumne.ran Nis lratddual sore than 1WY IReNlatbn3, Part smg Iw11.0.1.4, Iin Mat Input rate lea. Ng orgams M alMetWNTIReNlatbn3,Pert SeaIm A, 11.0.111 oothe neaterharea design Feat Input maims Tan or tole MMPtWnri(Peuhtwn 3, Pan.,Saeori11.01.e1 a. stetseallisty ur rolled o[ enuab,u matemimu nul,NC. meaner than 5 my r CO embeleu N1W ereate.nlaIne&6tlen 3, Pan e, Yalo.nnl)2 oure.wuou.uu wrma Colorado ResulutfunI.SuctIonVI. L sense ben from,. MaeNate� than2 tunadaytlWmlc un l,5mlon Mesa.l .leam� umayestedentimiumandmmimieraactor,enmpliar® isormiumed. co 1. t inpnmtextnehatet (l�,d.2bn1ala, ..P-) 2 ox6dAsch rge Nnlorxmmette nacemao.0 MMmnu�hea and lwaulation1,tsmbo Mira,.. ma.eulauq E.Pan.,Senbnllcv.) 3. Do. thesourteclischarga particulate msttelna®s oNFefulbeing equation: PE.0.50I,.?tileNlatbnl,5emm IIIA1.h and Reguhtbn., Part ..Section 11:[2.7 coat 0.11u/Mmbtu Fe .out, lReuletbni, Section 111..1-c.I .o P. M de Foot Mpm rumtle.o2mma .,.,Ag bnl suntanm.ua.esn aegw.adrn6.. Partwnh<.1. e...2. an , ada,i..lrmbaer, Pr'su Colorado Pmmbateni s.df3Axvbx 2. is.. natural mtoiat an eusttnpfaotny thatbdenNS as amalwaouadNOa a Ibred2R 22tbnismkk22..i Ixedatlgiseab2XMD.14 a. ma nsl.dl®tchave u,mtudletamcl enbsbm orxa equal to or erateeN.n5 ton+ IReaatlot TSectlonnl.O.LI Isom ..N r.—mmbusUeu Promealummea seamen xaFina.—atenatFe to requirements aaaro2l b 5ealom nv oaa. twoteF gM.o3: era xM.N3a. NSPS Analysis poeu um,, fimSMate ha.ea maximum design het Input aped, of2u megawatt, iMwl lloo nanStO„) ale., b2 gmterMan or equaltoLS MW (v2MOtuArllg I§so.4O2(42 2. OoatFe natural ga. fired bete. Ma maximum 232202.2 kw Cap.. emM ate0n20 mgaw.te 1Mwl 1282 MMetu/w1PIW0.a03a11 INIumequertmm MMUS mmoa tetow. 40.R. Part SO wboarta 023 .x2.22 P.rrormarr ferSmalllydutrlalmmrmnla2nstlmdowl mourn O.wr.t2282t o,d construction.modlficaVoru or reconstruction cra,emam gerenNrg unit commence afterlunes, IMNSs...cla)1 ISeurce subleo to NSK a. 392502 P. Oenml Pawble20 rla200 • Revtlne acl Rew,db..oimt Rquberme39 Source Requires anAPV.I.Ge MN next uum5dau ea to Ulu nod muanlon. eat, nun quoutton. Nat Ina..da2N.r.,eat.dams..lowand...funAde,uumglwm. P2•um.d. a.m. one. requested umisailfictou conuatimuceiumtmumud. 9asetl en Me remmaxed•mission Nam, comp...., preummad. sauna nrat uutsjud to negda.oma.5ralanNaae. 102.,.22.5 ,at.,xir. 2 1125 02. m i. sub.o to 238200. 1. n moamavon, w m-onawmmn a me steam e=noanne unit commence otter lone ss.zmax (160 .401314D 502 Suardarcla vea putemlalwa x ernbslon s:140 n IJ (pax IMametu) heat lnputalers/ (§m.azb1i1n11 3. Old h face ycornmna mmtrualun, aonstnstl,., or movncaon after Febnry3e,xm13(4a0.4xa01111 kat. hr tasnereoran01, natural psi-wed -mpn....*v 11 wpm mmeiWlu)or esx l§m.a4bry1) s. �tlmhe.ta.meer_a*h o�a.„�g�ea.,(4�..4ahn� wcmfaawan percent orless fomata.lgas. matIllateon.am middai oil with a nn,ogenamemab3aweight pe,amorla.s(§m.4.bmnn;ana Aresafecttoa orally enforceable faddy to ,anyur ef. Y am13lnd annual apaaty facto do percent err la. mrnatunlsas, 15111aeoa and residualoilnuroge 9c. content 0,11.30 a ',valet percent or las.I4a..bm(311 vla fwilryrnm«m e aicm m tmct.,anfraaon.fterluly00,z3a3t(4.0.4ab011 Is hh�annt gas 11redlhamsuaea to and lnmmdlance with a federally enforceable re0ul,emert that. lints°pennon cl.efadliry to an anneal awcltY factor dla percent (0.10)or 1¢s for coal. al, and natural g s(crany combination at hemree)x(4s0.n4bm(l11 tfraa er dre low hero release ateand combust om net or in aces of p mpm entatheh a e;(5m.HHIVEpce tiro ne .earzfmmtlemmbrmm o,a Ise :eny.a,n ry�avb. 4,11,1.21311.11-seanda,aforaulfura§o.ft 4.011 4mMaal orlmar111111Ond Iporm-smN.rafornnrogenoedsllaml 4aa43 b- Emasfen me nIadng mr.aF. dioxide • 4m. 4ro.4.b-n pa,aB,. recarelfmapIngraquiromenes MAR Analysis 2. �sa1a swap mefor. .3(§a3a as( (4E3z4a0(1311areaawabn(4Ez.amplla end aherlunea,x01o1 3, Iwthen®t pmapamyl..cwnorw...../1,x(5.3. Fewer mm mezu/F.wtlastF.n ermalaso mramuM/I§.aasm(e11 isourie m rot arelaato rarvcrvv0va gs3.na0(.1 andn.eg -won onnlenftadar.ts 4a3.3n01a1-Innol rer„ eenmaferaastingseurces aga3.zs10(g)fa.ftaa.ew= 4.3.3111111-3ubsevuent fwlmelyneser.coa .3,..(a) .P1111- ttemonstratIng In1lal compliance §3.xs4a(.11101ana (a1N1-o comd,an 4.3.311,1.1,113- newl,1 ,1.111 :1.1,111. Mel-raoteamn. §.a.313n1.l.lbl.11.4121.d.25.121.114 1.d �ae�m,¢ 4.a.3au (.1, mu]rra ulna m.3s.aln. (m.ra w-aemmlh..po. No o(s<lalmar Caaxa a.a.laa Th/adaw;Wdewmm�na avw;rouiaYer,.a theanamemaaWaclaen.wan its lmnramanwerace//awna, and apa., ml;ty Control end ckQ a ft fts. ans. .meat donf innolardk w mau2as arazbeanalysis dcma,a may, anvy mapanw.rsrivafun based urn We iMNaual Filth menfdceanotfhargeasvbalanc, roranYlaw, ref Ihft Cn,carry oWalagally binding regulementandla AnQ..Oenftaf ie. InWe eve.a Yv.naKl be'IwaenvlaalanguagaeltSft orreg lapel Welangtage Theueat.vAddict unplanenesuchhu2lrons,aMRk qually Conbvl on regulalbnx,IHe Inadsae WWe srelure areguhb-onw,ll ronlml. The use Goon-mentlalaaraadaaeaO are dnsy,"'afiould; and'can; aide APCO A,. don. rylemimlogysucM1 as'mux 0aaa0apubm mended WdasaOeconbdtlna d. -We terms Nthe Clean ArActand AvgvaAty Cpnbd Cammissan reaukdom, bufWis document dws not establish asallY N'MMa /ryuuensnfs • In and MiseH.n t a source moat mndua a tueub omuaItO Natural Gas Heater Emissions Inventory 01"5 NG Heater Facility' AIRS ID: County Plant Point J,"'" ,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: One (1) MMBtu/hr One (1). natural gas heater(s) (Make: TOO, Model: TOD, Serial Number. TBD) each with a design heat input rate of 0.5 MMRtu/hr. Each unit is equippedwith low-NOx burners. Each unit is a glycol regeneration 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 contemt of waste gas = Actual Hours of Operation = Requested Hours of Operation = Requested heat input rate = Actual Fuel Consumption = No add-on control equipment Low NOx combustion system is considered an integral control device. 1 MMBtu/hr Btu/scf s/year hrs/year 4,380.00 MMBTU per year 4.29 MMscf/year Requested Fuel Consumption = 4.29 MMscf/year Requested Monthly Throughput = MMscf per month Potential to Emit (PTE) Fuel Consumption = Section 04- Emissions Factors & Methodologies 4.29 MMscf/year" Emission Factors Natural Gas Heaters Pollutant Uncontrolled Uncontrolled Ib/MMBtu Ib/MMscf (Fuel Heat (Fuel Combusted) Consumption) Emission Factor Source PM10 PM2.5 ≥Iasi. 7.6 7.6 0.6 50 84 5.5 SOx NOx CO VOC e�8 Formaldehyde Benzene Toluene. n -Hexane moiWilokaa 1.8 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 .r SOx NOx CO Hoc - 0.02 0.02 0.02 0.02 0.02 3 0.02 . 0.02 0.02 0.02 0.02 3 0.00 0.00 0.00 0.00 0.00 0 0.11 0.11 011 0.11 0.11 18 0.18 0.18 0.18 0.18 0.18 31 0.01 0.01 0.01 0.01 0.01 2 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) Formaldehyde 0 0 0 0 0 Benzene - 0 0 0 0 0 Toluene 0 0 0 0 0 n -Hexane 8 8 8 8 8 Section 06 - Regulatary Summary Analysis Regulation 3, Parts A, B Source is APEN exempt per Regulation 3, Part A, Section 11.0.1.k. 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 6, Section ti.C.3. Based on the requested e Regulation 6, Part A, Subpart Db, 302 Standards Source is not subject to NIPS Db. Regulation 6, Part A, Subpart Db, NOx Standards Source is not subject to NSPS Db. Regulation 6, Part A, Subpart Dc Source is subject to NSPS Dc. Regulation 7, Section XVLD - Source is not subject to Regulation 7, Section XVI D. Regulation 8, Part E, MACT Subpart DDDDD Source is not subject to MACF DDDDO. 34 of 41 - K:\PA\2018\18 W E0777.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 be required for PM 2.5 Does the company use AP -42 emission factors (or more conservative factors)? 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 - Technical Analysis Notes Section 09 - Inventory SCC Coding and Emissions Factors Uncontrolled Emissions AIRS Point # Process # SCC Code Pollutant Factor Control % Units 019 01 13-,0-004-0.: Industrial Process: Oil & Gas Protection; Process Heaters; Natural Gas (MMscf) PM10 7.60 0 lb/MMscf Burned PM2.5 7.60 0 lb/MMscf Burned sox 0.60 0 lb/MMscf Burned NOx 50.00 50 lb/MMscf Burned CO 84,00 0 Ib/MMscf Burned VOC 5.50 0 Ib/MMscf Burned Formaldehyde 7.50E-02 50 Ib/MMscf Burned Benzene 2.10E-03 50 Ib/MMscf Burned Toluene 3.40E-03 50 lb/MMscf Burned n -Hexane 1.8 50 lb/MMscf Burned 35 of 41 K:\PP,\2018\18WE0777.CP1.xlsm Natural Gas Heater Regulatory Analysis Worksheet Bamaanth. heaterimpme eetetpan,nthe ,memary,tkswmquaNiesaa,uetbwmre equi memps rom g msae,oss mpne a w i....Deartd IThtaunknmamtunl pas at doNma W t.P5Db a Deed/arbdclgndm 6umae1.1grzdehadbyMAci DDol. rabr.ao Paerysoo rosndo Na,.ntm.nmemaaaa nu,remetattn.ans.A and APEX and P.n... ms • ATTAINMENT 1. Are ontmlld actual ea(sslm,sefanycrrcala palutamsrrm tlgsBmlrauals.ucegreatarthan22,fPymation ,Parta,samnll.olal? 2. Dow the Featecluve a design.. Input ate less than e:galm5 MME.4.2 lRegula, on 3, part a, xnbn I(.o.1.k1 3. Does Me heater have a deAgn heat Input ate less than arqualte 10MMatu/M1R(RegWet(on3OPart(I,Sedlen0,o.1z) a. act fadlmunmmmlledweemIssbna g,eaterthan5 Tay,rvoeereate.than loi102P),orCDemissions greaterthan 10 Try (Regulations, part',So,. ll.D.zl? INet a skaremreter a. narcrolld emisslms of anyaftda2321.msfmm MlsldMauel source lyeatertlianSTM jPeyulatmn 3, part A,5Mlanll,o.1.a1? 2. Cam Fearer haws deslm6eat(rap, metes than orequalmsMMEtµ/hr2(Reguhtlon3.nrta,xsttonllD.3.k) 3. D the ehezteihave desrgn hat nputram leot,anorqual to 10MMBtumr?(Regulation 3,Part B,Sed(anll.o.l<.1 4. Are [et, facility uncontrolledvaeemissbns ereaterthan2rw, Ng, greatmthan sips orm emm(onsg,a.thanlaTf (Regulation 3,Pau B,yelon11.D2)? ISaameIs. Apwwxempt par R.gnl..an3.Pan A,satenu.D.].k. • 1. asufur d(mlrkemaamy mfamthe heater ',ream -than 2 tens per day?(Reo,btbnl, sett(.Masai xwona.e.cana2-Rrad worry Rgmin&Data Retention weWa6'er,savtianp( and Colorado Reavlmene sans Suntan ll,sedardsN parformanm for N., fua60urngne Eoulomeut 1. what rsthedeslgn heat Input ate ofthchm,e+2.0 gulatfm2,x¢kn lll.a.andRegulrt(nn e,Part B,5a1(on II.G) rticrbre matte.ln cress ei0sm/Mm., hex Imp.?IPa .D1.) 3. Daa thesaveemsdarger 2242 2. matta(n aemzntthddbx(Merntont2E-.50),I4aal?( Nlbtlb1S43.l endil Aulharna RegMen Be Parca, setup ll.�) a. 116/Mmku Feat input; fReeuanonl,sarronaas.cl • Immpl(epanel e,Nazauran..ubpam ante lug... znmAi.c ad wasw one. eo¢e.x¢ronlBca.emd onrsramg a(n enfaeo., • 1_ Is thenatural gas ulatingh.ghythat6dassfid attan as malarsmme d.NmazIhtdln Rery6tlonyscttS 8J42?(Reyu2 re4abrXN.D11 2. o natural ered heater have actual ern.fons of No. equal toargwtertban 3 tpv7Megulatlon>xalon XN.0.21. IEo 5.dan Xvhg2.a,a adf.—combustion Pn asadhetmem NSPS Analysis 5sd, 1414024414424.3,1,42 424144 aapaeaya29 megawztts(Mw1(10o MMawmrl alp, aW gre¢ertnenorgoalmss Mw(54MMsnr/'mp. (450.424;)) 2. Dom ¢Inputmpacrtyoa1mt242s m¢awatta NW mmeh,/b)?(440.4351.11 Source t not.relett 2, N4F5 Mar MPS o., ao rnt pan en subpart oc standard.N wrfermam fans 01.1uamlsammerlal Im<g ea(BteamwmraeneuNr- Par Rvgule.n, Par, iimaA, Na IBamd enMeraqueamdemlvlamana enxa(anfeaor,amplrmm ispresume, u5MMgw/hr cola pun an 2. isau saubyam NEpsa. aalpmns(am 46u.4ae PepoMng and RemNgeephg Reqwmmams eeaea enthe requested oniKa(onfiaar,e mplleenkpmsumad. 44444.5j#2444Reb!gadon1settlon 45W. 523.4.c.e is. Mt subjeate NSF, 6, ar w wOi.Irma ,ameea1-1.1 1.34.wain ee aema Una" 1. MI coutroution, Flo donor®0101 433 A W swm ge`erarine onrc mnmmm 101480113.1980 560.440,40 Anda 2. Coes the natural gas fired Fleater havea peace., 502 algal.. rate re pat laulh lurneteat Input or Ins, (¢60.421(k)(21)3. OW the ac a e„m,nm.9m. emecer"m """mm�etw>wl naftawle. 2005,600 4-31.11, elChrdards 4. m ga e but Input capacitycapacity0173 Mw 1 M ,250 metu/drl°Hasa 05(1.8ak11 5. ees thehaa ermeeall ofthefdlouing alter.? Igsd.44hk11 se. mmwn,aloneor mamdn.len4nly natural gas, dnenlate aleorres.al ollwlth a nrcraa catty d 0s eeeht perm or less l§8.4aa111111: cep., factor dll p=x.¢v�s fornmoal as,.111ateel, and rvlduel1001,41 nftrogenmmem 4.130 weight percent m I§604413giR11: and �ub• je,a �renfam ngoperaton edfadlityr4 1314. annregenmrt we'gMpecercor�le enforceable tFeamdv.Wfadgty,a mn13nd annalaWdhfieord �pvantdor las for natural gn, dbalateol, mtlresMnlepw4ha nrc0 5c =atom ,,agnt reaxx o Im.l§60.8ag411 taffea.4rleywmaau mmm tr0h rnwtnm4 rt or masgmdm8 w4 after,* .133701431.a111 Is aunlect m and rnmmplence Ma federally vdaeeablempuenet that gun.apvamnadrefa4xyman areal apawr faevell pveert10.i114rlessfor ®la aranar. p Id nr eenmurwnortkmree10L4s0...all flredlmv ha01.401 heatm6rer rearrammdxnatwai gas ne.tilate m in moms d 30 percent cetheheatiwmme 3ldayrdling atmgehvn tlemNxmra d all fuck, 146auggRll §314x4444114-aar.+sdforau7udbdaelsoil 41A4N.1 orI44 or PE IN aM130444•ssModfornerog.n4xida1NW §31.451 ..mpna a..neadomram.tatm3mad3andpmnd... orWho. dau4 §31.4313, 34mpna rend n d4m ante tat,.mma.rd pr.atlur es for paalatdate m.m e.m nitrogen... §61.4713 -Eaten in...ring,rawfm dioxide 43146b-gmragmn m.xterhufarp.rdegn. mature ani.r4cen oxide 46146*-Reporlir. and mardseping r,iren.m. MARA41344ss x040. nera,abo.e MA0'00001 N6HMfer M.brsoum4 Indust.., Comm...4 and rredtmlonl¢onus and prow. x41,41 1. m a faclity WM a map some ps71§ia7aa51 2. Okl constrrmm/49434944444rem orw4aq 414 463.443044/dlmmme termaea2e3ure 4.20100 3. It the atuputam lesWn or eqalto6 M13344 0(343.16nad1 4. utne M64u144ml4s than or4alto4a MMm4M11f61.750o1ell Isouree. roca4114,444043401040944 §443.x5444141 andrade3 -work praal.em0101 §.f.nmfal-14remgremerts §6.7sse 1.1-114040 4040here fora luing source OP 63.7514 VI fornew sourss §43.73441.1-64h,ame4 tes,fmh analyses ortuneem 543.73411.1 andlfl-4emom4adng 01411/04 441 §61.71431.111.1and.01441•,,4-ommdnIomnuoracomdlanm 46.73411.1,14-(4..69/,7 ore -for 61.1.1111..161, 0171. Nel-rva04.tam 563.795014M. (4. 19(111 .4314 a. w 4110 aeg 545.7635 414 Mal 1444141 and 69.7351 4441,11414.4,141414444444,444,4, 4141 131 ad 1d 48w.dkn ea DISetelmer This want annuls peealm Wee delam1310343,01Ma40tain',run.. a Me clean AiAcP0linyw4v4r regulalionz. Cmbd 41102• 0smn rrvg40gons. Th,3 *tune. is not ,ingd40on and Me anae,ais contains may Waggle a 4wlla4¢rname eased upon the individual Fits Item deed 40400 msso7sde4 her anyMen443404440404044any4MerlenlaW.amgr.403ne ndggyyalfr4( nMe • N any, Inut�MmnMe434g4age 4r M a document and tee lany4ege of the Clean Meet. Ts',lamentg4ag44'1344 0 l*ouaNy Control 044 the language of the slated. mgukgon7caned. The use dm047433 ay lanaeaeaovenas 7r.uaallale •800131444074914 •wan.' 144, 31)33 ;eau...,cle14 4FCG41erpret Clean AI recommendations.,140)01 0007,3gy srsh as muse and'reggae• are intended bdasa4emnedeng reg l4eemens under the new dine Clean AIrAdand Aeoeagay Coned Commission agu6tio40, byte. document does nal 04404,34 legally dealing requirements In and desalt mm eau me.44eatoM4eT. me,emse nuet aram44o4 eneaas yew, ennad,.d in 63.7;40,63,5addl. Section 01- Adminstrative Information Facility AIRs ID: 123 9fdb ' 014 County Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: vent vie r4ti0 Section 03 - Processing Rate Information for Emissions Estimates Compressor Slowdown Volume= Requested Compressor Slowdown Events= Actual Compressor Slowdown Events= Actual Gas Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput= elfed byplantflare MMscf i4 events/year events/year 0 MMscf per year 2.30E-01 MMscf per year 2.30E-01 MMscf per year . 6060...,'„ __..............._ .._,.:e�. Actual Gas Throughput While Emissions Controls Operating = Section 04 - Emissions Factors & Methodologies Emission Calculation Method EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10- Displacement Equation (10.4-3) Ex=Q* MW Xx /C Ex = emissions of pollutant x Q= Volumetric flow rate/volume of gas processed MW = Molecular weight of gas = SG of gas * MW of air Xx = mass fraction of x in gas C = molar volume of ideal gas (379 scf/lb-mol) at 60F and 1 atm Throughput (Q) MW 2.30E-01 MMscf/yr Ib/Ib-mol 2.63E+01 scf/yr MMscf/d 25.0 0.00063069 mole % MW Ibx/Ibmol 4.0026. mass fraction lb/hr lb/yr 0.00 tpy 0.00 Helium 0.000 1.138 0.612 0.000 0.045 0.024 0.414 0.159 0.184 0.00 0.35 CO2 .2.585427406. 14.01 0.08 691.12 N2 methane ethane 2.185048213 64,57099177 '13.20360218 23.013 16.041 30.063 0.04 0.72 0.28 0.32 371.78 0.19 3.15 1.21 10.358 6291.28 2410.99 2796.55 3.969 4.604 propane isobutane n -butane ,.....095490. isopentane :: 0.699864905 n -pentane ..:'0.755654252 cyclopentane : s.:i'8.039338964 n -Hexane .. :.0.27280916 cyclohexane Other hexanes :0 heptanes 0.115649983. methylcyclohexane 0.012095466 224-TMP . 0:001411! Benzene 0:010129673 Toluene .. .:0.008388134 Ethylbenzene _. _. .. .. Xylenes C8+ Heavies VOC mass fractia 0.3557 MW 24.300 0.44221814 .092 1.40 0.23 0.63 .27573141 58.118 58.118 0.741 2:068 0.505 0.030 0.083 0.020 0.022 0.001 0.05 450.34 ss09s1 0.14 1256.31 72.114 0.03 306.55 11.15 72114 0.545 0.04 330.99 0.17 70.13' 86.18 0.028 0.00 16.76 0.01 0.235 0.009 0.000 0.000 0.005 0.000 0.02 142.80 0.07 0.00 99228 84.16 0.010 0.00 6.18 86,18 0.000 0.116 0.012 0.00 0.01 0.00 0.00 0.00 0.04 0.00 100.21. 70.39 9', 7.21 0.002 0.000 0.00 0.98 0.00 7812 92.15 0.008 0.000 0.00 4.81 0.00 0.008 0.000 0,00 4.69 0.00 0,004771224 06.17 0.005 0.000 0.00 3.08 0.00 106.17 0.006 0.000 0.00 3.66 0.00 '116 0.011 0.000 0.00 6.68 0.00 Notes Total VOC (Uncontrolled) 2.70 Mole %, MW, and mass fractions are based on a representative gas.sample Emissions are based on 24 inlet compressor blowdown events per year. The MW of C8+ used for calculations is based on the operator designated value of 114. This is within the expected range and therefore acceptable. Section 05 - Emissions Inventory Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 225.33 lb/event 11.27 lb/event 2.70 tpy 0.14 tpy Gas Analysis Benzene 0.200 lb/event 0.010 lb/event 4.8 lb/yr 0.2 lb/yr Mass Balance Toluene 0.196 lb/event 0.010 lb/event 4.69 lb/yr 0.23 lb/yr Mass Balance Ethylbenzene 0.128 lb/event 0.006 lb/event 3.08 lb/yr 0.15 lb/yr Mass Balance Xylenes 0.153 lb/event 0.008Ib/event 3.66 lb/yr ' 0.18 lb/yr Mass Balance n -Hexane 5.950 lb/event 0.298 lb/event 142.80 lb/yr 7.14 lb/yr Mass Balance 2,2,4-TMP 0.041 lb/event . 0.002 lb/event 0.98 lb/yr 0.05 lb/yr Mass Balance 0.000763640 0.000865686 0.00405189 0.00756841. 0.00140827 0.000510579 Section 06 - Regulatory Summary Analysis 18WE0777.CP1.xlsm AQCC Regulation 1 Section II.A.1 - Except asprovided 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 H. A and B of this regulation. - - AQCC Regulation 2 - - Section I.A applies to all emission sources. "No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such astoresultin detectable odors.;', which are measured in excess of the following,limits: For areas used predominantly for residential or commercial purposes it isa violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air." - - - - - - - i` - r• Section 07 - Technical Analysis Notes -'The operator' expressed that to demonstratecompliance. with blowdown permit !(m its, each blowdown event will be recorded and em!ss ens will be estimated by multiplying the number of events by the emission factor provided in the notes to permit holder (lb/event). This supports the use of an event basis for the process limit contained in the perit. Permit₹ee has coin = ttv lyeshs(, wdow emissions, Rlowdowr, event limits as requested are considered conservative. 18WE0777.CP1'.xlsm Section 01- Adminstrative Information Facility AIRs ID: County Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Nattrat'go ,,: vented idt' Emissions from:this sour€e. co . ...o nt.roll__,. ... _._._. e rolled by plant figta:, Section 03 - Processing Rate Information for Emissions Estimates Compressor Blowdown Volume= Requested Compressor Blowdown Events= Actual Compressor Blowdown Events= Actual Gas Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput = MMscf events/year vents/year 0 MMscf per year 1.06E+00 MMscf per year 1.06E+00 MMscf per year Actual Gas Throughput While Emissions Controls Operating= Section 04 - Emissions Factors & Methodologies Emission Calculation Method EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10- Displacement Equation (10.4-3) Ex=Q*MW*Xx/C Ex = emissions of pollutant x Q= Volumetric flow rate/volume of gas processed MW = Molecular weight of gas = 5G of gas * MW of air Xx = mass fraction of x in gas C = molar volume of ideal gas (379 scf/lb-mol) at 60F and 1 atm Throughput (a) MW 1.06E+00 MMscf/yr Ib/Ih-mol 1.22E+02 scf/yr MMscf/d 8.9 0.002916905 mole MW Ibx/Ibmol mass fraction lb/hr lb/yr 0.00 tpy 0.00 Helium 0.000 0.000 0.00 1.60 CO2 =:2.585427406 1.138 0.128 0.36 3196.39 N2 methane ethane 'it N:2._35048213 ... :.64.57099177 e 0.612 10.358 0.069 1.163 0.446 0.20 3.32 1719.48 29096.77 0.86 14.55 propane isobutane n -butane _`,#3.20360218. 0.44221814 %1:275:' 3;5029095: 30.D63 _. .44:092. 3.969 4.604 0.517 L27 1.48 11150.66 12933.87 5.58 6,47 58.118 5 0.741 0.083 0.24 2082.79 1.04 10 2.068 0.232 0.66 5810.37 2.91 isopentane n -pentane cyclopentane n -Hexane .' 0.639864905 72.114 0.505 0.057 0.16 1417.78 1530.80 0.71 0.755654252 0.039338964 ;72..114 0.545 0.061 0.003 0.026 0.17 0.77 0.04 7 86.18 3 0.028 0.01 0.08 77.50 0.27280916 0.235 660.45 0.33 0.01 0.00 0.16 0.02 cyclohexane Other hexanes heptaens methylcyclohexane 224-TMP Benzene Toluene Ethylbenzene Xylenes C8+ Heavies VOC mass fractio 1.0000 MW 8.903 0..032099228 0.010 0.000 0.116 0.012 0.001 0.00 28.60 0 ;"'36.13 100:21 0.000 0.013 0.001 0.00 0.04 0.00 0.00 0,115649983 0.012095466. 325.56 90.19. 4.23 78.12 92.15- 33.36 ...-..0.0014'. 76 0.002 0.000 0.00 4.53 0.00 29679 0.008 0.001 0.00 22.23 0.01 0.008388134 0.008 0.001 0.00 21.71 0.01 4771224 106.13. 0.005 0.001 0.00 14.23 0.01 001 0.01 0.006 0.001 0.00 0.00 16.94 0.01 114 0.011 0.001 3038 0.02 Notes Total VOC (Uncontrolled) 12.51 Mole %, MW, and mass fractions are based on a representative gas sample . Emissions are based on 728 NGL pigging blowdown events per year. The MW of C8+ used for calculations is based on the operator designated value of 114. This is within the expected range and therefore acceptable. Section 05 - Emissions Inventory Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 34.36 lb/event 1.72 lb/event 12.51 tpy 0.63 tpy Gas Analysis Benzene 0.031 lb/event 0.002 lb/event 22.2 lb/yr 1.1 lb/yr Mass Balance Toluene 0.030 lb/event 0.001 lb/event 21.71 lb/yr 1.09 lb/yr.. Mass Balance Ethylbenzene 0.020 lb/event 0.001 lb/event 14.23 lb/yr 0.71 lb/yr Mass Balance Xylenes 0.023 lb/event 0.001 lb/event 16.94 lb/yr 0.85 lb/yr Mass Balance n -Hexane 0.907 lb/event 0.045 lb/event 660.45 lb/yr 33.02 lb/yr Mass Balance 2,2,4-TMP 0.006 lb/event 0.000 lb/event 4.53 lb/yr 0.23 lb/yr Mass Balance Section 06 - Regulatory Summary Analysis 18WE0777.CP1.xlsm AQCC Regulation 1 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. AQCC Regulation 2 Section I.A applies to all emission sources. "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." Section 07 - Technical Analysis Notes ...The -000 sed that to demonstrate eompliance.witlt blowdciwn permit limits, each blowdown event will be recorded and emissions will by estimated by multiplyingtdie;ntftnber of ' ovided in the notes t6 parmit hodder {lhjevent). This supports the use of ail event basi3f«ariChe process limit contained sn the permit ' - Permitkee has conservatively estimated blowdown emissions. Slowdown event limits as requested are considered conservative. • -Thispoint specifically addresses biowdown venting accociated with NGI. pigging operations -The emissions were derived from a composite nt the various blowdown operations. Limits in the permit reflect the different blowdown operations. Hence limitof.728 for some operation, and limit of 1 for other operations anticipated to Detour less than once per year. 1BWE0777.CP1.xlsm Permit number: Date issued: Issued to: COLORAD+II► Air Pollution Control Division Department of Public Health b Environment CONSTRUCTION PERMIT 18WE0777 DRAFT REP Processing, LLC Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Pierce Gas Processing Plant 123/9FDB SW SEC 21 T8N R66W Weld County Natural Gas Processing Plant Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description C-1 003 One (1) Waukesha, Model L7044 GSI 55, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1,897 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Catalyst and Air -Fuel Ratio Controller C-2 004 One (1) Waukesha, Model L7044 GSI S5, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1,897 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Catalyst and Air -Fuel Ratio Controller C-3 005 One (1) Waukesha, Model L7044 GSI 55, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal Catalyst and Air -Fuel Ratio Controller Page 1 of 39 ,COLORADO Mr Pollution Control Envision arsrr' - cwt, CDPHE COLORADO Air Pollution Control Division Department of Public Health Et Environment combustion engine, site rated at 1,897 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. C-4 006 One (1) Waukesha, Model L7044 GSI S5, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1,897 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Catalyst and Air -Fuel Ratio Controller C-5 007 One (1) Waukesha, Model L7044 GSI 55, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1,897 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Catalyst and Air -Fuel Ratio Controller C-6 008 One (1) Waukesha, Model L7044 GSI S5, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1,897 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Catalyst and Air -Fuel Ratio Controller FUG 010 Equipment leaks (fugitive V0Cs) from a natural gas processing facility. LDAR D-1 011 One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: TBD, Model: TBD, Serial Number: TBD) with a design capacity of 60 MMscf per day. This emissions unit is equipped with 1 (Make: tbd, Model: tbd), electric driven glycol pump with a design capacity of 7 gallons per minute. This dehydration unit is equipped with a still vent, Emissions from the still vent are routed to an air-cooled condenser and then to an enclosed combustor. Emissions from the flash tank are routed recycled to plant inlet. Page 2 of 39 COLORADO Air Pollution Control Division ₹ Ir ^*n a Th i;wc 'ream £ F.rvrrnr-',nza t COLORADO Air Pollution Control Division Department of Public Health & Environment flash tank, and reboiler burner. A-1 012 One (1) Methyldiethanolamine (MDEA) natural gas sweetening unit (Make: TBD, Model: TBD, Serial Number: TBD) with a design capacity of 200 MMscf per day . This emissions unit is equipped with 3 (Make: TBD, Model: TBD) electric driven amine pump(s) with a design capacity of 800 gallons per minute combined. This amine 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 recycled to the fuel -gas system. LD-1 013 Hydrocarbon Liquid Loadout Into Trucks Enclosed Flare MSS -1 014 Natural gas venting from overhead compressor blowdowns. Open Flare HTR1 015 One (1) natural gas fired regenerator heater (Make: TBD, Model: TBD, Serial Number: TBD). The heater has a design rate of 63 MMBtu/hr. This heater is equipped with a low NOx combustion system for minimizing emissions of nitrogen oxides. The heater provides heat for amine regeneration. None HTR2 016 One (1) natural gas fired regenerator heater (Make: TBD, Model: TBD, Serial Number: TBD). The heater has a design rate of 17 MMBtu/hr. This heater is equipped with a low NOx combustion system for minimizing emissions of nitrogen oxides. The heater provides heat for mole sieve regeneration. None HTR3 017 One (1) natural gas fired heater (Make: TBD, Model: TBD, Serial Number: TBD). The heater has a design rate of 25 MMBtu/hr. This heater is equipped with a low NOx combustion system for minimizing emissions of nitrogen oxides. The heater provides heat for trim recovery HMO. None HTR4 018 One (1) natural gas fired heater (Make: TBD, Model: TBD, Serial Number: TBD). The heater has a design rate of 24 MMBtu/hr. This heater is equipped with a low NOx combustion system for minimizing emissions of nitrogen None Page 3 of 39 CDPME COLORADO Air Pollution Control Division Department of Public Health £- Environment. oxides. The heater provides heat for oil stabilization. MSS -2 020 Natural gas venting from inlet compressor blowdowns. Open Flare MSS -3 021 Natural gas venting from maintenance and pigging blowdowns. Open Flare Point(s) 003, 004, 005, 006, 007, 008: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another «Make» «Model» 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.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for 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. Point(s) 003, 004, 005, 006, 007, 008: 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. Page 4 of 39 COLORADO Pxstlutto cs:atres1 Division COLOR AIE<O Air Pollution Control Division Department of Public Health & Environment • manufacture date • construction date • order date • date of relocation into Colorado • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, III.E.) Point(s) 011: 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. • The dehydrator manufacturer name, model number and serial number • The glycol circulation pump manufacturer name and model number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation Number 3, Part B, III.E.) 6. Point(s) 012: 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. • The amine unit manufacturer name, model number and serial number • The amine circulation pump manufacturer name and model number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation Number 3, Part B, III.E.) 7. Point(s) 015, 016, 017, 018: 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. • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation Number 3, Part B, III.E.) 8. 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 9. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Monthly Limits: Page 5 of 39 COLORADO Pollution Contrvi D video COLORADO Air Pollution Control Division Department of Public Health 8 Environment. Facility Equipment ID AIRS Point Pounds per Month Emission Type PM2.5 SOX H2S NO, V0C CO C-1 003 --- --- --- 937 215 1,249 Point C-2 004 --- --- --- 937 215 1,249 Point C-3 005 --- --- --- 937 215 1,249 Point C-4 006 --- --- --- 937 215 1,249 Point C-5 007 --- --- --- 937 215 1,249 Point C-6 008 --- --- --- 937 215 1,249 Point D-1 011 --- --- --- --- 929 259 Point A-1 012 --- 1,120 14 1113 933 279 Point LD-1 013 --- --- --- --- 3819 --- Point HTR1 015 --- --- --- 2298 253 3860 Point MSS -1 014 --- --- --- --- 293 --- Point HTR2 016 --- --- --- 620 --- 1042 Point HTR3 017 --- --- --- 912 --- 1532 Point HTR4 018 --- --- --- 875 --- 1470 Point MSS -2 020 --- --- --- --- 91 --- Point MSS -3 021 --- --- --- --- 1563 --- 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. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility., Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type pM2.5 SOX H2S NO, V0C CO Page 6 of 39 COLORADO Pollution Control Division o Puotic FAvw,r,r ' C LORADs; Air Pollution Control Division Department of Public Health & Environment C-1 003 --- --- --- 5.5 1.3 7.4 Point C-2 004 --- --- --- 5.5 1.3 7.4 Point C-3 005 --- --- --- 5.5 1.3 7.4 Point C-4 006 --- --- --- 5.5 1.3 7.4 Point C-5 007 --- --- --- 5.5 1.3 7.4 Point C-6 008 --- --- --- 5.5 1.3 7.4 Point D-1 011 --- --- --- --- 5.5 1.5 Point A-1 012 --- 6.6 0.1 6.6 5.6 1.7 Point LD-1 013 --- --- --- --- 21.8 --- Point MSS -1 014 --- --- --- --- 1.8 --- Point HTR1 015 2.1 --- --- 13.6 1.5 22.8 Point HTR2 016 0.6 --- --- 3.7 --- 6.2 Point HTR3 017 --- --- --- 5.4 --- 9.1 Point HTR4 018 --- --- --- 5.2 --- 8.7 Point MSS -2 020 --- --- --- --- 0.6 --- Point MSS -3 021 --- --- --- --- 9.2 --- 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. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. During the first twelve (12) months of operation, compliance with both the monthly and annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual limits, for 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. Page 7 of 39- COLORADO Air Pollution Control Dion i rat ar rnn of Put COLORADO Air Pollution Control Division Department of Public Wealth b Environment. 10. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility potential emission limitations as indicated below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities are defined as any activity or equipment, which emits any amount but does not require an Air Pollution Emission Notice (APEN) or is permit exempt. (Reference: Regulation 3, Part C. II. E. ) Total potential emissions from the facility, including all permitted emissions and potential to emit from all insignificant activities, shall be less than: • 100 tons per year of CO 11. Point 010: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas and liquids analyses, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. 12. Point(s) 011: Compliance with the emission limits in this permit shall be demonstrated by running the GRI GlyCalc model version 4.0 or higher or PROMAX version 4.0 on a monthly basis using the most recent extended wet gas analysis and recorded operational values, including: dry gas throughput, lean glycol recirculation rate, condenser outlet temperature, 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. 13. Point(s) 011: On a monthly basis, the owner or operator shall monitor and record operational values including: condenser outlet temperature, flash tank temperature and pressure, wet gas inlet temperature and pressure. These records shall be maintained for a period of five years. 14. Point 012: Compliance with the emission limits in this permit shall be demonstrated by running the ProMax model version 4.0 or higher on a monthly basis using the most recent amine unit inlet extended sour gas analysis and recorded operational values, including: gas throughput, lean amine circulation rate, MDEA weight concentration in the lean amine stream, flash tank temperature and pressure, sour gas inlet temperature, and sour gas inlet pressure. Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into the ProMax model and be provided to the Division upon request. 15. The owner or operator shall operate and maintain the emission points in the table below with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. The owner or operator shall operate this dehydration unit so as to prevent any emissions directly to the atmosphere. (Regulation Number 3, Part B, Section III. E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled C-1 003 Oxidation catalyst and air/fuel ratio controller NOx Ft CO Page 8 of 39 COLORADO Air Pollution 'Control Division on: of F.rinid' Em tF'Yk .a'? C COLORADO Air Pollution Control Division Department of Public Health & Environment C-2 004 Oxidation catalyst and air/fuel ratio controller NOx £t CO C-3 005 Oxidation catalyst and air/fuel ratio controller NOx a CO C-4 006 Oxidation catalyst and air/fuel ratio controller NOx Et CO C-5 007 Oxidation catalyst and air/fuel ratio controller NOx £t CO C-6 008 Oxidation catalyst and air/fuel ratio controller NOx Et CO FUG 010 Implementing LDAR program as specified in NSPS 0000a VOC Ft HAP D-1 011 Still Vent: Enclosed Flare Et Condenser VOC Et HAP A-1 012 Thermal oxidizer VOC Ft HAP LD-1 013 Enclosed Combustor VOC Ft HAP MSS -1 014 Open Flare VOC £t HAP MSS -2 020 Open Flare VOC a HAP MSS -3 021 Open Flare VOC Et HAP 16. Point(s) 011: The owner or operator shall operate and maintain the emission points in the table below as a closed loop system and shall recycle 100% of emissions as described in the table below. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Emissions Recycling Description Pollutants Recovered D-1 011 Flash Tank: Recycled to Plant Inlet VOC a HAP PROCESS LIMITATIONS AND RECORDS 17. 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) C-1 003 Consumption of natural gas as a fuel 117 MMscf/yr 9.94 MMscf/month COLORADO it Psaatutio Control Dion Page 9 of 39 COLORADO Air Pollution Control Division Department of Public Health Er Environment C-2 004 Consumption of natural gas as a fuel 117 MMscf/yr 9.94 MMscf/month C-3 005 Consumption of natural gas as a fuel 117 MMscf/yr 9.94 MMscf/month C-4 006 Consumption of natural gas as a fuel 117 MMscf/yr 9.94 MMscf/month C-5 007 Consumption of natural gas as a fuel 117 MMscf/yr 9.94 MMscf/month C-6 008 Consumption of natural gas as a fuel 117 MMscf/yr 9.94 MMscf/month D-1 011 Dry Gas Throughput 21,900 MMscf/yr 1,860 MMscf/month A-1 012 Natural Gas Throughput 73,000,200 MMscf/yr Mscf/y 6f/m MMscf/month LD-1 013 Condensate Loading 389,975 Bbl/yr 33,121 Bbl/month MSS -1 014 Number of Events 24 3 HTR1 015 Consumption of natural gas as a fuel 541.1 MMscf/yr 46 MMscf/month HTR2 016 Consumption of natural gas as a fuel 146.0 MMscf/yr 12 MMscf/month HTR3 017 Consumption of natural gas as a fuel 214.8 MMscf/yr 18 MMscf/month HTR4 018 Consumption of natural gas as a fuel 206.2 MMscf/yr 18 MMscf/month MSS -2 020 Number of Events 24 3 MSS -3 021 Number of Residue/Inlet Pigging Events 728 62 Number of NGL Pigging Events 1 1 The owner or operator shall monitor monthly process rates based on the calendar month. The volume of dry gas throughput shall be measured by gas meter at the outlet of the dehydrator. 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. Point(s) 003, 004, 005, 006, 007, 008: Fuel consumption shall be measured by one of the following methods: individual engine fuel meter; facilty-wide fuel meter attributed to fuel consumption rating and hours of operation; or manufacturer -provided fuel consumption rate. Point(s) 012: The owner or operator shall monitor monthly process rates based on the calendar month. The volume of gas processed by each unit shall be measured by gas meter or by assuming the maximum design rate of each amine unit to be 200 MMscf/d. COLORADO Aix Pollution, Control Division ,rya Page 10 of 39 COLORADO Air Pollution Control Division Department of Public Health Et Environment 18. Point(s) 011: This unit shall be limited to the maximum lean glycol circulation rate of 7 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 glycol flow meter(s), or recording strokes per minute and converting to circulation rate. This maximum glycol circulation rate does not preclude compliance with the optimal glycol circulation rate (Loft) provisions under MACT HH. (Reference: Regulation Number 3, Part B, II.A.4) 19. Point(s) 012: This point shall be limited to the maximum lean amine circulation rate of 800 gallons per minute total. The lean amine circulation rate shall be recorded daily in a log maintained on site and made available to the Division for inspection upon request. Amine circulation rate shall be monitored by one of the following methods: assuming maximum design pump rate, using amine flow meter(s), or recording strokes per minute and converting to circulation rate. (Reference: Regulation Number 3, Part B, II.A.4) 20. Point(s) 012: On a weekly basis, the owner or operator shall monitor and record operational values including: flash tank temperature and pressure, MDEA weight concentration in the lean amine stream, and sour gas inlet temperature and pressure. These records shall be maintained for a period of five years. 21. Point(s) 015, 016, 017, 018: The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas combusted as fuel for each heater using an operational continuous flow meter. A single meter may be used to show fuel usage for multiple heaters. The owner or operator shall use monthly throughput records, operating hours, and design fuel use rates to demonstrate compliance with individual unit process limits contained in this permit and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 22. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 23. 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. (Reference: Regulation No. 1, Section II.A.1. Et 4.) 24. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 25. This source is located in an ozone non -attainment or attainment -maintenance area and subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2. The following requirements were determined to be RACT for this source: Facility Equipment ID AIRS Point RACT Pollutants FUG 010 LDAR as provided at 40 CFR Part 60 Subpart OOOOa VOC A-1 012 Routing amine still and flash tank waste -gas to thermal oxidizer. VOC, HAPs Page 11 of 39 COLORADO Air TPsttcttftrsat Division COLORADO Air Pollution Control Division Department of Public Health & Environment LD-1 013 Enclosed Combustor VOC, HAPs MSS -1 014 Open Flare VOC, HAPs HTR1 015 HTR2 016 Natural gas as fuel, low NOX burners, good combustion practices NOx HTR3 017 HTR4 018 MSS -2 020 Open Flare VOC, HAPs MSS -3 021 Open Flare VOC, HAPs 26. Point(s) 003, 004, 005, 006, 007, 008: 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. 27. Point(s) 003, 004, 005, 006, 007, 008: This equipment is subject to the control requirements for natural gas -fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas -fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: 1 deration. Note: Per Regulation No. 7, Section XVII.B.5, internal combustion engines that are subject to an emission standard or an emissions control requirement in a federal maximum achievable control technology ("MACT") standard under 40 CFR Part 63, a Best Available Control Technology ("BACT") limit, or a New Source Performance Standard under 40 CFR Part 60 are not subject to this Section XVII. Maximum' Engine HP Construction or Relocation Date Emission Standard in g/hp-hr NOx CO VOC <100HP Any N/A N/A N/A ≥100HP and <500HP January 1, 2008 January 1, 2011 2.0 1.0 4.0 2.0 1.0 0.7 ≥500HP July 1, 2007 July 1, 2010 2.0 1.0 4.0 2.0 1.0 0.7 Page 12 of 39 COLORADO Air Po€€ution Control Division C RADO Air Pollution Control Division Department of Public Health & Environment 28. Point(s) 010: This source is subject to Regulation Number 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and handling operations, 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. The operator shall comply with all applicable requirements of Section XII. 29. Point(s) 010: This source is subject to Regulation No. 7, Section XII.G.1 (State only enforceable). For fugitive V0C emissions from leaking equipment, the leak detection and repair (LDAR) program as provided at 40 CFR Part 60, Subpart 0000(July 1, 2017) shall apply, regardless of the date of construction of the affected facility, unless subject to applicable LDAR program as provided at 40 CFR Part 60, Subpart 0000a (July 1, 2017). The operator shall comply with all applicable requirements of Section XII.G. • This facility is subject to 40 C.F.R. Part 60, Subpart 0000a, and compliance with that rule shall satisfy the requirements of Regulation No. 7, Section XII.G.1. 30. Point(s) 011: 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: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for glycol natural gas dehydrators; and • Ensure uncontrolled actual emissions of volatile organic compounds from the still vent and vent from any gas -condensate -glycol (GCG) separator (flash separator or flash tank), if present, shall be reduced by at least 90 percent on a rolling twelve-month basis through the use of a condenser or air pollution control equipment. (Regulation Number 7, Section XII.H.1.) 31. Point(s) 011: 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) Page 13 of 39 COLORADO Air Pollution Control Division COLORADO Air Pollution Control Division Department of Public Health & Environment. MACT HH Applicable Requirements Area Source Within UA/UC boundary §63.760 - Applicability and designation of affected source §63.760 (f) - The owner or operator of an affected major source shall achieve compliance with the provisions of this subpart by the dates specified in paragraphs (f)(1) and (f)(2) of this section. The owner or operator of an affected area source shall achieve compliance with the provisions of this subpart by the dates specified in paragraphs (f)(3) through (f)(6) of this section. §63.762 - Startups, Shutdowns, and Malfunctions §63.762(a) - The provisions set forth in this subpart shall apply at all times. §63.764 - General Standards §63.764(a) - Table 2 of this subpart specifies the provisions of subpart A (General Provisions) of this part that apply and those that do not apply to owners and operators of affected sources subject to this subpart. §63.764(b) - All reports required under this subpart shall be sent to the Administrator at the appropriate address listed in §63.13. Reports may be submitted on electronic media. §63.764(d)(1) - Each owner or operator of an area source located within an UA plus offset and UC boundary shall comply with the requirements specified in paragraphs (d)(1)(i) through (iii) of this section. §63.764(d)(1)(i) - The owner or operator shall comply with the control requirements for glycol dehydration unit process vents specified in §63.765; §63.764(d)(1)(ii) - The owner or operator shall comply with the monitoring requirements specified in §63.773; and §63.764(d)(1)(iii) - The owner or operator shall comply with the recordkeeping and reporting requirements specified in §§63.774 and 63.775. §63.764(i) - In all cases where the provisions of this subpart require an owner or operator to repair leaks by a specified time after the leak is detected, it is a violation of this standard to fail to take action to repair the leak(s) within the specified time. If action is taken to repair the leak(s) within the specified time, failure of that action to successfully repair the leak(s) is not a violation of this standard. However, if the repairs are unsuccessful, a leak is detected and the owner or operator shall take further action as required by the applicable provisions of this subpart. Page 14 of 39 COLORADO Air Pollution Control Division C • LORAD Air Pollution Control Division Department of Public Health b Environment MACT HH Applicable Requirements Area Source Within UA/UC boundary §63.765 - Glycol Dehydration Unit Process Vent Standards §63.765(b)(1) - For each glycol dehydration unit process vent, the owner or operator shall control air emissions by either paragraph (b)(1)(i) or (b)(1)(ii) of this section. §63.765(b)(1)(i) - The owner or operator shall connect the process vent to a control device or a combination of control devices through a closed -vent system. The closed -vent system shall be designed and operated in accordance with the requirements of §63.771(c). The control device(s) shall be designed and operated in accordance with the requirements of §63.771(d). §63.765(b)(2) - One or more safety devices that vent directly to the atmosphere may be used on the air emission control equipment installed to comply with §63.765(b)(1). §63.771 - Control Equipment Requirements §63.771(c) - The closed -vent system shall route all gases, vapors, and fumes emitted from the material in an emissions unit to a control device that meets the requirements specified in paragraph (d) of this section. §63.771(d) - Owners and operators of small glycol dehydration units, shall comply with the control device requirements in paragraph (f) of this section. §63.772 - Test Methods, Compliance Procedures and Compliance Demonstration §63.772(c) - The source shall comply with the no detectable emissions test procedure per §63.772(c). §63.772(e) - Per §63.772(e)(1)(i), a flare that is designed and operated in accordance with §63.11(b) is exempt from the requirements to conduct performance tests and design analyses under §63.772(e) except as specified in §63.772(e)(2): §63.772(e)(2) - An owner or operator shall design and operate each flare in accordance with the requirements specified in §63.11(b) and in paragraphs (e)(2)(i) and (e)(2)(ii) of this section. §63.772(e)(2)(i) - The compliance determination shall be conducted using Method 22 of 40 CFR part 60, appendix A, to determine visible emissions. §63.772(e)(2)(ii) - An owner or operator is not required to conduct a performance test to determine percent emission reduction or outlet organic HAP or TOC concentration when a flare is used. Page 15 of 39 COLORADO luticsn Control Division COLO-- Air Pollution Control Division Department of Public Health & Environment MACT HH Applicable Requirements Area Source Within UA/UC boundary §63.773 - Inspection and Monitoring Requirements 563.773(c) - For each closed -vent system required to comply with this section, the owner or operator shall comply with the requirements of §63.773(c). §63.773(d) - For each control device, the owner or operator shall install and operate a continuous parameter monitoring system in accordance with the requirements of §63.773(d). Per §63.773(d)(3)(i)(C), the continuous monitoring system for a flare shall be a heat sensing monitoring device equipped with a continuous recorder that indicates the continuous ignition of the pilot flame. Owners or operators that install and operate a flare in accordance with §63.771(d)(1)(iii) are exempt from the requirements of §63.773 (d)(4) and §63.773(d)(5). §63.774 - Recordkeeping Requirements §63.774(b) - Each owner or operator of a facility subject to this subpart shall maintain the records specified in §63.774(b). §63.774(e) - When using a flare to comply with §63.771(d), the records required under §63.774(e) must be maintained. 563.775 - Reporting Requirements 563.775(c) - Each owner or operator of an area source located within a UA plus offset and UC boundary shall submit the information listed in §63.775(c)(1) through (6). 563.775(d) - Each owner or operator of a source subject to this subpart shall submit a Notification of Compliance Status Report as required under §63.9(h) within 180 days after the compliance date specified in §63.760(f). In addition to the information required under 563.9(h), the Notification of Compliance Status Report shall include the information specified in 563.775(d). 563.775(e) - An owner or operator of an area source located inside a UA plus offset and UC boundary shall prepare Periodic Reports in accordance with paragraph §63.775(e)(3) and submit them to the Administrator. 563.775(f) - Whenever a process change is made, or a change in any of the information submitted in the Notification of Compliance Status Report, the owner or operator shall submit a report within 180 days after the process change is made or as a part of the next Periodic Report as required under §63.775(e), whichever is sooner. The report shall include the information specified in §63.775(f). 32. Point(s) 012: The inlet gas stream to the amine unit shall have a total sulfurs concentration, including H2S, of less than or equal to 4.0 ppm. 33. Point(s) 012: 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 Page 16 of 39 COLORADO Air Pollution' Control Division COL Air Pollution Control Division Department of Public Health & Environment. excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Reference: Regulation Number 1, Section II.A.5.) 34. Point(s) 013: 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; • All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 35. Point(s) 013: 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, I'II.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Regulation Number 3, Part B, III.D.2.) 36. Point(s) 013: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere induding, but not limited to (Regulation Number 3, Part B, III.E.): a) Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. 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) The owner or operator shall inspect onsite loading equipment during loading operations to monitor compliance with above conditions. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 37. Point(s) 013: All hydrocarbon liquid loading operations, 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. 38. Point(s) 013: The owner or operator shall: 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 not in use. c. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. Page 17 of 39 Co ORADO ilk Pollution Control Divition Meal. ^ ra,%I ,At"lieAthb rwtror `.mrt C LORADO Air Pollution Control Division Department of Public Health & Environment Operate all recovery and disposal equipment at a back -pressure less than the pressure relief valve setting of transport vehicles. 39. Point(s) 015, 016, 017, 018: This source is subject to the Particulate Matter and Sulfur Dioxide Emission Regulations of Regulation 1 including, but not limited to, the following (Regulation 1, Section I I I.A.1 and VI. B.5. ): a. No owner or operator shall cause or permit to be emitted into the atmosphere from any fuel -burning equipment, particulate matter in the flue gases which exceeds the following (Regulation 1, Section III.A.1): (i) For fuel burning equipment with designed heat inputs greater than 1x106 BTU per hour, but less than or equal to 500x106 BTU per hour, the following equation will be used to determine the allowable particulate emission limitation. PE=0.5(FI ).0 26 Where: PE = Particulate Emission in Pounds per million BTU heat input. Fl = Fuel Input in Million BTU per hour. b. New sources of sulfur dioxide shall not emit or cause to be emitted sulfur dioxide in excess of the following process -specific limitations: (i) Limit emissions to not more than two (2) tons per day of sulfur dioxide. (Regulation 1 Section VI.B.5.a.) 40. Point(s) 015, 016, 017, 018: This source is subject to the New Source Performance Standards requirements of Regulation 6, Part B including, but not limited to, the following (Regulation 6, Part B, Section II): a. Standard for Particulate Matter - On and after the date on which the required performance test is completed, no owner or operator subject to the provisions of this regulation may discharge, or cause the discharge into the atmosphere of any particulate matter which is: (I) For fuel burning equipment generating greater than one million but less than 250 million Btu per hour heat input, the following equation will be used to determine the allowable particulate emission limitation: PE=0.5(FI )-0.26 Where: PE is the allowable particulate emission in pounds per million Btu heat input. Fl is the fuel input in million Btu per hour. If two or more units connect to any opening, the maximum allowable emission rate shall be the sum of the individual emission rates. (ii) Greater than 20 percent opacity. 41. Point(s) 015, 016, 017, 018: This source is subject to the New Source Performance Standards requirements of Regulation Number 6, Part A Subpart Dc, Standards of Performance for Small Industrial -Commercial -Institutional Steam Generating Units including, but not limited to, the following: a. 40 CFR, Part 60, Subpart A - General Provisions Page 18 of 39 COLORADO Air Pollution Control Division Department of Public Health 8- Environment b. 40 CFR 60.48c(a) The owner or operator of each affected facility shall submit notification of the date of construction or reconstruction and actual startup, as provided by 560.7 of this part. c. 40 CFR Part 60.48c(g) The owner or operator of the facility shall record and maintain records of the amount of fuel combusted during each month. d. 40 CFR Part 60.48c(i) 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. 42. Point(s) 014, 020, 021: 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; • All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. OPERATING & MAINTENANCE REQUIREMENTS 43. Point(s) 003, 004, 005, 006, 007, 008, 011, 012, 013, 014, 015, 016, 017, 018, 020, 021: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 44. Point(s) 010: 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 of NGL (light oil service) that are representative of volatile organic compound (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. These extended gas and liquids analyses 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 liquids analyses and emission calculations to the Division as part of the self -certification process to ensure compliance with emissions limits. 45. Point(s) 010: Within one hundred and eighty 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 source and establish the number of components that are operated in "heavy liquid service", "condensate light liquid service", "NGL light liquid 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. Page 19 of 39 COLORADO Air Pollution Control Division COLORADO Air Pollution Control Division Department of Public Health & Environment 46. Point(s) 011: The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 9, 40 C.F.R. Part 60, Appendix A, to measure opacity from the flare for one continuous hour. (Regulation Number 1, Section II.A.5) 47. Point(s) 011: The owner or operator shall complete the 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.) 48. Point(s) 012: The owner or operator shall complete an initial extended sour gas analysis from the inlet to the amine unit 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.) 49. Point(s) 012: Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, the operator shall complete an initial sample of the inlet gas to the amine unit to determine the concentration of hydrogen sulfide (H2S) in the gas stream. The owner or operator shall use the sample results to calculate actual emissions, as prescribed in the Emission Limitations and Records section of this permit, to verify initial compliance with the emission limits. The sample results shall also be monitored to demonstrate that this amine unit qualifies for the exemption from the Standards of Performance for Crude Oil and Natural Gas Facilities (560.5365a(g)(3)) and to demonstrate compliance with the limit for total sulfurs concentration, including H25. The owner or operator shall submit the analysis and the emission calculation results to the Division as part of the self -certification process. The testing required by the condition above may be used for this demonstration. 50. Point(s) 012: A source initial compliance test shall be conducted on this emissions point to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emissions limits in this permit. The operator shall also demonstrate the thermal oxidizer (TO) achieves a minimum destruction efficiency of 98% for VOC. The operator shall measure and record, using EPA approved methods, VOC mass emission rates at the thermal oxidizer inlet and outlet to determine the destruction and removal efficiency of the thermal oxidizer (process models shall not be used to determine the flow rate or composition of waste gas (waste gas stream from the still vent and flash tank) sent to the thermal oxidizer for the purposes of this test). The natural gas throughput, lean amine recirculation rate, MDEA concentration, sulfur content of the sour gas entering the amine unit, and thermal oxidizer combustion chamber temperature shall be monitored and recorded during this test. This test shall be run with the thermal oxidizer operating at the minimum combustion chamber temperature of 1,400°F as indicated in the O&M plan for this point. 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 Number 3, Part B., Section III.G.3) Page 20 of 39 COLORADO Air Pollution Control Division COLORADO Air Pollution Control Division Department of Public Health b Environment Sulfur Dioxide using EPA approved methods. Oxides of Nitrogen using EPA approved methods. Volatile Organic Compounds using EPA approved methods. Carbon Monoxide using EPA approved methods. Periodic Testing Requirements 51. Point(s) 003, 004, 005, 006, 007, 008: This engine is subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. 52. Point(s) 010: 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 NGL (light oil service) that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. These extended gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. 53. Point(s) 011: 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(s) 011, 012: On a daily basis, the owner or operator shall conduct an inspection for presence or absence of smoke, and, if smoke is observed, the operator has the option to (1) immediately conduct repairs and maintain records of the specific repairs completed; (2) shut-in the equipment to investigate the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed; or (3) conduct a formal EPA Method 9 observation to determine the opacity of the visible emissions, and conduct repairs if necessary. 55. Point(s) 012: 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 exemption from the Standards of Performance for Crude Oil and Natural Gas Facilities (560.5365a(g)(3)). The testing required the following condition may be used for this demonstration. 56. Point(s) 012: 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. ADDITIONAL REQUIREMENTS 57. 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 (NOx) in ozone nonattainment areas emitting less than 100 tons of VOC or NOx 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 Page 21 of 39 COLORADO Air Pollution Control Division COLORADO? Air Pollution Control Division Department of Public Health & Environment 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 For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • 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. 58. The exhaust stack(s) for the following emission point(s) shall vent emissions at a point greater than or equal to the height specified in the table below: Facility Equipment ID AIRS Point Minimum 5taCl� height above grounevel°(ft).. Base Elevation (feet)... C-1 003 39 1552 C-2 004 39 1552 C-3 005 39 1552 C-4 006 39 1552 C-5 007 39 1552 C-6 008 39 1552 D-1 011 __ 22 1552 A-1 012 30 1552 LD-1 013 25 1552 HTR-1 015 25 1552 HTR-2 016 24 1552 HTR-3 017 20 1552 HTR-4 018 20 1552 MSS -1 014 115 1552 - MSS -2 020 115 1552 MSS -3 021 115 1552 59. This facility shall be completely enclosed by a fence line and posted with no trespassing signs that preclude public access to this site. The fence line shall match that depicted in the "Air Dispersion Modeling Report" submitted by the operator in June 2018 (Revised September 2018). This requirement is imposed as a result of the modeled ambient air NOx and CO impacts that result from the facility operations. (Regulation Number 3, Part B, Section 111.8.5.) 60. This facility shall be constructed with the building and equipment dimensions listed below and as detailed in the "Air Dispersion Modeling Report" submitted by the operator in June 2018 (Revised September 2018). This requirement is imposed as a result of the modeled ambient air Page 22 of 39 COLORADO notion Control Division n: Sf tlwar a kr E.nv :rmr„n: BLG-1 COLORADO Air Pollution Control Division Department of Public Health fr Environment. NOx and CO impacts that result from the facility operations. (Reference: Regulation No. 3, Part B, Section III.B.5) Building Height and Base Elevation Building. Height (ft)" ease evation feet) 1552 17 BLG-1A 30 1552 BLG-2 39 1552 BLG-3 39 1552 BLG-5 18 1552 TKS 20 1552 61. Point(s) 015, 016, 017, 018: MACT DDDDD - National Emission Standards for Hazardous Air Pollutants for Major Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters requirements shall apply to this source at any such time that this source becomes a major source of hazardous air pollutants (HAP) 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 Number 8, Part E) GENERAL TERMS AND CONDITIONS 62. 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. 63. 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. 64. 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 and with 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. 65. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. Page 23 of 39 COLORADO Air Pollution. Control Division Gt; alt 6 Er+vr*,x ^..o.,. COLORADO Air Pollution Control Division Department of Public Health & Environment 66. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the 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. 67. 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. 68. 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: DRAFT Timothy Sharp Permit Engineer Permit Histo Issuance Date Description Issuance 1 This Issuance Issued to REP Processing, LLC for a synthetic minor natural gas processing facility. Page 24 of 39 COLORADO Air Pollution Control Division fl'on. 01. Pl x ^ £r Erkvsrr .:eat COLORADO Air Pollution Control Division Department of Public Health Er Environment Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (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. Facility Equipment ID AIRS Point Pollutant CAS # Uncontrolled Emissions (Ib/yr) Controlled Emissions (Ib/yr) C-1 through C-6 003- 008 Formaldehyde 50000 1,941 1,941 Methanol 67561 365 365 Acetaldehyde 75070 333 333 Acrolein 107028 314 314 Benzene 71432 189 189 1,3 -Butadiene 106990 79 79 Toluene 108883 67 67 FUG 010 Benzene 71432 932 135 Toluene 108883 355 57 Ethylbenzene 100414 55 12 Xylenes 1330207 97 19 n -Hexane 110543 15,074 2,133 2,2,4- Trimethylpentane 540841 151 20 D-1 011 Benzene 71432 23,351 1,161 Toluene 108883 21,561 1,075 Page 25 of 39 COLORADO Pollutions Control Divasicazi CDPE COLORADO Air Pollution Control Division Department of Public Health €t Environment Ethylbenzene 100414 13,981 698 Xylenes 1330207 24,468 1,222 n -Hexane 110543 9,979 405 2,2,4- Trimethylpentane 540841 30 1 A-1 012 Benzene 71432 38,955 779 Toluene 108883 24,002 480 Ethylbenzene 100414 6,937 139 Xylenes 1330207 12,439 249 n -Hexane 110543 420 8 LD-1 013 Benzene 71432 894 257 Toluene 108883 298 86 Ethylbenzene 100414 18 5 Xylenes 1330207 482 139 n -Hexane 110543 29,766 8,558 2,2,4- Trimethylpentane 540841 158 45 MSS -1 014 Benzene 71432 4 0 n -Hexane 110543 25 2 HTR1 015 Formaldehyde 50000 41 41 Benzene 71432 1 1 Toluene 108883 2 2 n -Hexane 110543 974 974 HTR2 016 Formaldehyde 50000 11 11 Benzene 71432 0 0 Toluene 108883 0 0 n -Hexane 110543 263 263 HTR3 017 Formaldehyde 50000 16 16 Benzene 71432 0 0 Toluene 108883 1 1 n -Hexane 110543 386 386 HTR4 018 Formaldehyde 50000 15 15 Benzene 71432 0 0 Page 26 of 39 COLORADO Pollution Control Division COLORADO Air Pollution Control Division Department of Public Health & Ervironment. Toluene 108883 1 1 n -Hexane 110543 371 371 MSS -2 020 Benzene 71432 12 1 n -Hexane 110543 28 2 MSS -3 021 Benzene 71432 207 11 n -Hexane 110543 1780 89 Note: All non-cnter'a 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: Point(s) 003, 004, 005, 006, 007, 008: CAS Pollutant Emission Factors Ib/MMBtu - Uncontrolled g/bhp-hr Emission Factors lb/MMBtu — Controlled g/bhp-hr NOx 3.5666 11.58 0.0924 0.30 CO 3.0615 9.94 0.1232 0.40 VOC 0.0049 0.02 0.0049 0.02 50000 Formaedehyd 0.0163 0.05 0.0163 0.05 67561 Methanol 0.0031 0.01 0.0031 0.01 75070 Acetaldehyde 0.0028 0.01 0.0028 0.01 107028 Acrolein 0.0026 0.01 0.0026 0.01 Emission factors are based on a Brake -Specific Fuel Consumption Factor of 7158 Btu/hp-hr, a site -rated horsepower value of 1897, and a fuel heat value of 1020 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer CO Manufacturer VOC Manufacturer 50000 Formaldehyde Manufacturer 67561 Methanol AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 75070 Acetaldehyde AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 107028 Acrolein AP -42; Table 3.2-3 (7/2000); Natural Gas No Control Point 010: This facility is 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 (Effective August 2, 2016). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. Page 27 of 39 COLORADO Air Pollution Control Division L,1 rt; . n 5i kw:ar- Hmtrhb E wr r Tivr COLORADO Air Pollution Control Division Department of Public Health b Environment The emission control percentages for fugitive emission leaks contained in this permit are granted on the basis of implementation and ongoing compliance with an LDAR program meeting the requirements of 40 CFR, Part 60, Subpart OOOOa. In the event that this facility becomes a major source of hazardous air pollutants (HAPs), this source will be subject to the requirements of 40 CFR Part 63, subpart HH, for fugitive equipment leaks at facilities not subject to 40 CFR Part 60, Subpart OOOO, including, but not limited to, 5 63.769 (a) - (c). Component Gas Service Heavy Oil Condensate (Light Oil) Water/Oil Service Connectors 5346 0 5680 0 Flanges 1619 DO 1639 0 Open-ended Lines 0 0 0 0 Pump Seals 0 0 50 0 Valves 1500 0 1981 0 Other* 170 0 24 0 VOC Content (wt. fraction) 2.66E-01 1.00E+00 1.00E+00 1.00E+00 Benzene Content (wt. fraction) 6.90E-04 0.00E+00 5.89E-03 0.00E+00 Toluene Content (wt. fraction) 4.80E-04 0.00E+00 1.98E-03 0.00E+00 Ethylbenzene (wt. fraction) 2.40E-04 0.00E+00 1.04E-04 0.00E+00 Xylenes Content (wt. fraction) 3.00E-04 0.00E+00 3.31 E-04 0.00E+00 n -Hexane Content (wt. fraction) 8.63E-03 0.00E+00 9.84E-02 0.00E+00 2,2,4- Trimethylpentane Content (wt. fraction) 4.00E-05 0.00E+00 1.05E-03 0.00E+00 *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors (kg/hr-component): Component Gas Service Heavy Oil Light Oil Servi Water/Oil ervi Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04. Pump Seals 2.4E-03 NA J 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Page 28 of 39 COLORADO Air Pollution Control Division C LOA Air Pollution Control Division Department of Public Health & Environment Source: EPA -453/R95-017 Table 2-4 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas and liquids analyses. Control Percentages Granted for Compliance with OOOOa, LDAR Program: Component Gas Service Heavy Oil Light Oil Connectors 81% 81% 81% Flanges 81% 81% 81% Pump Seals - - 88% Valves 96% - 95% Point(s) 011: The emission levels contained in this permit are based on information provided in the application and the GRI GlyCalc 4.0 model. Controlled emissions are based on a flare control efficiency of 95%. Total still vent combustion emissions are based on the sum of the emissions for the still vent primary control. Total combustion emissions are based on the following emission factors: Still Vent Primary Control: Pollutant Uncontrolled Emission Factors lb/MMBtu Waste Gas Combusted Source PMtp 0.0075 AP -42 PM2,5 0.0075 AP -42 SOx 0.0006 AP -42 NOx 0.068 AP -42 CO O.3100 AP -42 Note: The combustion emission factors are based on a heating value of 1122 Btu/scf. Actual emissions are calculated by multiplying the emission factors in the table above by the waste gas flow from the regenerator overheads stream in the monthly GlyCalc report and by the hours per month the waste gas was routed to this control device. Point 012: The emission levels contained in this permit are based on information provided in the application and the ProMax simulation. Controlled flash tank emissions are based on 98% control when emissions are routed to the thermal oxidizer. Controlled still vent emissions are based on 99% control efficiency when emissions are routed to the thermal oxidizer. The following table summarizes the control efficiency for each scenario: Page 29 of 39 COLORADO Aix Pollution Control Iizvxfsitsz COLORAD Air Pollution Control Division Department of Public Health Er Environment Control Scenario VOC Control Efficiency Still vent emissions routed to the thermal oxidizer 98% Flash tank emissions routed to the thermal oxidizer. SO2 emissions resulting from the combustion of H2S in the waste gas are based on the SO2 emission factor presented in table 5.3.1 in AP -42 Chapter 5.3. The SO2 emission factor is as follows: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf gas processed Source SO2 0.674 AP -42 Chapter 5.3 Table 5.3.1 Note: The SO2 emission factor is based on the amine unit inlet H2S concentration of 4 ppm. Point 013: Pollutant CAS # Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 3.88E-01 1.12E-01 CDPHE PS Memo 14-02 Benzene 71432 2.29E-03 6.59E-04 CDPHE PS Memo 14-02 Toluene 108883 7.64E-04 2.20E-04 n -Hexane 110543 1.24E-03 3.55E-04 n -Hexane 110543 7.63E-02 2.19E-02 Note: Controlled emission factors are based on the enclosed flare efficiency of 95% and a collection efficiency of 75%. Point 015: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Source PM�p 7.6 AP -42 Chapter 1 Table 1.4-2 PM2.5 7.6 AP -42 Chapter 1 Table 1.4-2 NOX 100 AP -42 Chapter 1 Table 1.4-1 CO 50 AP -42 Chapter 1 Table 1.4-1 VOC 84 AP -42 Chapter 1 Table 1.4-2 Page 30 of 39 COLORADO Air Pt ttu₹icrt Control Division COLORA Air Pollution Control Division Department of Public Health Er Environment CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Source 110543 n -Hexane 1.8 AP 42 Chapter 1 Table 1.4-3 Note: Emissions factors are based on a rated heat input of 48 MMBtu/hr, a higher heating value of 1,020Btu/scf and 8,760 hours of operation per year. Point 016: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Source PM�o 7.6 AP -42 Chapter 1 Table 1.4-2 PMz 5 7.6 AP -42 Chapter 1 Table 1.4-2 NO, 100 AP -42 Chapter 1 Table 1.4-1 CO 50 AP -42 Chapter 1 Table 1.4-1 VOC 84 AP -42 Chapter 1 Table 1.4-2 110543 n -Hexane 1.8 AP 42 Chapter 1 Table 1.4-3 Note: Emissions factors are based on a rated heat input of 17 MMBtu/hr, a higher heating value of 1,020Btu/scf and 8,760 hours of operation per year. Point 017: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Source PM10 7.6 AP -42 Chapter 1 Table 1.4-2 PM2.5 7.6 AP -42 Chapter 1 Table 1.4-2 NO, 100 AP -42 Chapter 1 Table 1.4-1 CO 50 AP -42 Chapter 1 Table 1.4-1 VOC 84 AP -42 Chapter 1 Table 1.4-2 110543 n -Hexane 1.8 AP 42 Chapter 1 Table 1.4-3 Note: Emissions factors are based on a rated heat input of 25 MMBtu/hr, a higher heating value of 1,020Btu/scf and 8,760 hours of operation per year. Page 31 of 39 COLORADO ax Potts tion ContDivision Point 018: COLORADO Air Pollution Control Division Department of Public Health Er Environment CAS. # Pollutant Uncontrolled Emission Factors lb/MMscf Source PM,o 7.6 AP -42 Chapter 1 Table 1.4-2 PMZ s 7.6 AP -42 Chapter 1 Table 1.4-2 N0 100 AP -42 Chapter 1 Table 1.4-1 CO 50 AP -42 Chapter 1 Table 1.4-1 V0C 84 AP -42 Chapter 1 Table 1.4-2 110543 n -Hexane 1.8 AP 42 Chapter 1 Table 1.4-3 Note: Emissions factors are based on a rated heat input of 24 MMBtu/hr, a higher heating value of 1,020Btu/scf and 8,760 hours of operation per year. 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) Point(s) 003, 004, 005, 006, 007, 008: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 complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ja08.pdf Delete if not subject to JJJJ 8) Point(s) 003, 004, 005, 006, 007, 008:This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.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) Point 012: This amine unit is 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 02, 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 on the EPA website at: https://www.gpo.gov/fdsys/pkg/FR-2016-06-03/pdf/2016-11971.pdf Page 32 of 39 COLOR ADO Air Pollution. Control Division C.LORAD Air Pollution Control Division Department of Public Health & Environment 10) This permit fulfills the requirement to hold a valid permit reflecting the glycol dehydration unit and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(B) when applicable. 11) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: NOx, CO, VOC, HAPs PSD or NANSR Synthetic Minor Source of: NOx, CO, VOC, HAPs MACT HH Area Source Requirements: 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 MACT 63.1440-63.6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX Page 33 of 39 COLORADO Air Pollution Control Division Department of Public Health t Environment ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. Alternative Operating Scenarios 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 shall 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. Page 34 of 39 COLORADO it Pollution Control Envision COLORADO Air Pollution Control Division Department of Public Health b Environment 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. 2.1.2 The owner or operator may permanently replace the existing engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the ;permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the 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. Page 35 of 39 'COLORADO Aix Pollution Control Division COLORADO Air Pollution Control Division Department of Public Health & Environment 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. For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit iscurrently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above -mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B 5 II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel Page 36 of 39 COLORADO Air Palliation Control Division L"a..';a Nas Ana Y W,C,C +Y;,7X £r E..Mfnr:'?l X COLORADO Air Pollution Control Division Department of Public Health 8 Environment As defined in 40 CFR Part 60 Subparts GG (S 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. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVII.E - State -only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr N0x CO V0C 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 Page 37 of 39 COLORADO Air Pollution Control Division COLORADO Air Pollution Control Division Department of Public Health b Environment 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, § 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 requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation Page 38 of 39 COLORADO Air Pollution Control Division COLORADO Air Pollution Control Division Department of Public Health & Environment COLORADO Air Pollution Control Division Page 1 of 39 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, cludin updates. An application with missing information may be determined incomplete and may be ret ned ore longer application processing times. You may be charged an additional APEN fee if the APEN is filled t incorrectly or is missing information and requires re -submittal. JUN 292018 I) This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.cotorado.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: NE 0111 AIRS ID Number: 123 /4Fp(3/003 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Site Location: REP Processing, LLC Pierce Gas Processing Plant 517930E 4500068N Zone 13T S Mailing Address: (Include Zip Code) 1611 N. Broadway Ave Portable Source Home Base: Oklahoma City, OK 73101 PA 1'17 p1:r a i+a tht a erna' I Site Location County: Weld NAICS or SIC Code: 211130 Permit Contact: James Fleak Phone Number: 720-889-9955 E -Mail Address2: JFleak@KahunaVentures.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. 384846 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 1 I coroaAoo 1 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action 0 NEW permit OR newly -reported emission source (check one below) O STATIONARY source O PORTABLE source O Request coverage under a Construction Permit ❑ 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 O Change company name ❑ Add point to existing permit O Change permit limit O Transfer of ownership4 O Other (describe below) - OR • APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Et Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. C-1 General description of equipment and purpose: Waukesha L7044 GSI S5 Compressor 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 hours/day 7 February 2019 0 Yes ❑ No Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 days/week 52 June -Aug: 25 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 weeks/year Sept -Nov: 25 COLORADO 2 I V Vv `-'1,iwnvwxi^ Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit ii and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump O Water Pump O Emergency Back-up ❑ Other: Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha Engine Model: L7044 GSI S5 Serial Number6: TBD What is the maximum designed horsepower rating? 1,900 hp What is the engine displacement? 1/cyl What is the maximum manufacturer's site -rating? 1,897 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,158 BTU/hp-hr hours/year Engine Features: Cycle Type: O 2 -Stroke 0 4 -Stroke Combustion: ❑ Lean Burn 0 Rich Bum Ignition Source: 0 Spark ❑ Compression Aspiration: ❑ Natural O Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes ❑ No If yes, what type of AFRC is in use? 0 OZ Sensor (mV) ❑NOx Sensor (ppm) Is this engine equipped with a Low-NOx design? ❑ Yes 0 No Engine Dates: What is the manufactured date of this engine? TBD What date was this engine ordered? TBD ❑ Other: What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 3 COLORADO 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) 517907E 4500042N Zone 13T Operator Stack ID No. Discharge Height" Above Ground Level (F*et) Temp ( F) Fiow Rate i CFM) Velocity (ftlsec) C-1 39 1,110 8,245 98.91 Indicate the direction of the Stack outlet: (check one) 0 Upward ❑ Horizontal ❑ Downward O Other (describe): Indicate the stack opening and size: (check one) 0 Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 16 ❑ Upward with obstructing raincap interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 10096 Load_ (SCF/hour)ti... Actual Annual Fuel Use (MMSCFtyear) _ Requested Annual Permit„Limit' (MMSGF/year)` 13,356.164 117 117 From what year is the actual annual amount? NA Indicate the type of fuel used': ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 8TU/scf) ❑r Field Natural Gas Heating value: 1,020 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 4 IAVI COLORADO Permit Number: AIRS ID Number: [Leave hhnk unless APCD has ahcaely Liss!;ned a permit anri All,5 IDi 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? O 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) PMto PM2.5 SOS NOX Nonselective Catalytic Reduction 97.4 VOC CO Nonselective Catalytic Reduction 96.0 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? NA Criteria Pollutant Emissions Inventory Emission Factor Actual Annual Emissions e Requested Annual Permit 7 Emission Limit(s) Pollutant 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) 0.00999 Ib/mmbtu AP -42 0.594 0.594 PMio D.00999 lb/mmbtu AP -42 0.594 0.594 PM2.5 0.00999 lb/mmbtu AP -42 0.594 0.594 SOX 0.000588 lb/mmblu AP -42 0.035 0.035 NOX 0.3 g/hp-hr Mfg Info 212.121 5.495 VOC 0 0 643-9.143 g/hp-hr Mfg Info 1.209 1.209 CO 0.400 [ glhp-hr Mfg Info 162.077 7.327 aw.4 Does the emissions source have any uncontrolled actual emissions of non-criteriaEl Yes pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? ❑ No If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions9 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds/year) Formaldehyde 50000 0O526 g/hp-h Mfg Acetaldehyde 75070 0.00636 Iblmmbtu AP -42 Acrolein 107028 0,00514 Ib/mmblu AP -42 Benzene 71432 0000440 Iblmmbtu AP -42 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. COLOR ADO Fore !U'_D-201 R_r.iprocartn hire real Combustion Encino /.0Eli - Revision '1/2017 5 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and MRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. Signature of Legally Auth rized Person (not a vendor or consultant) Date Kevin Bailey Chief Operating Officer 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 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 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 6 Ia COEORADO 7/17/2018 State.co.us Executive Branch Mail - Site Location for Pierce Gas Processing Plant STATE OF COLORADO Underriner - CDPHE, Katherine <katherine.underriner@state.co.us> Site Location for Pierce Gas Processing Plant 2 messages Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Mon, Jul 16, 2018 at 12:30 PM To: jfleak@kahunaventures.com Hi James, While looking at the APENs further I noticed that the site location lists coordinates. These coordinates are listed as 417930E 4500068N Zone 13T which is not a format I have seen before. Based on Google Earth, it looks like this is located around 40.650871, -104.787540. Can you please send me the site location is Section, Township, Range format? Thanks, Katherine Underriner Application Completeness Technician Stationary Sources Program COLORADO Air Pollution Control Division Department of Public Health &Environment P 303.692.6381 I F 303.782.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 katherine.underriner@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. As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete APENs. Additional fees may apply if an APEN is submitted without the necessary information. An application with missing information may result in longer processing times. Please note that all APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section II.A). Current APEN forms can be found at: https://www.colorado.gov/cdphe/APENforms James Fleak <JFleak@kahunausa.com> Mon, Jul 16, 2018 at 2:56 PM To: Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Hi Katherine, The UTM coordinates were utilized by the consultant that was initially working with REP Processing and he used those values since he put together the dispersion model. The site is located in the SW/4 of S21 T8N R66W. Hope that helps. I received your message about the tanks to be listed individually. I will call to make sure I'm clear how that Form 102 should state the emissions. James James Fleak, P.E. 720-889-9955 Direct https://mail.google.com/mail/u/0?ik=e82d6de00d&view=pt&search=all&permthid=thread-a%3Ar5610759831789739182&simpl=msg-a%3Ar372031820... 1/2 12/18/2018 State.co.us Executive Branch Mail - Pierce Gas Processing Plant -Status STATE OF COLORADO Sharp - CDPHE, Timothy <timothy.sharp@state.co.us> Pierce Gas Processing Plant -Status James Fleak <JFleak@kahunausa.com> Tue, Sep 25, 2018 at 2:05 PM To: "Sharp - CDPHE, Timothy" <timothy.sharp@state.co.us> Cc: "Ron Sober (rsober@rfsconsulting.com)" <rsober@rfsconsulting.com>, Jesse Warman <JWarman@kahunausa.com> Timothy, Please see responses to your queries below. Thank you for your patience. James Fleak, P.E. 720-889-9955 Direct 720-235-2288 cell From: Sharp - CDPHE, Timothy[mailto:timothy.sharp@state.co.us] Sent: Monday, September 24, 2018 4:28 PM To: James Fleak <JFleak@KahunaUSA.com> Subject: Re: Pierce Gas Processing Plant -Status Hello James, I'm in the process of compiling all the permit conditions into a single facility -wide. I expect to have the draft completed by noon tomorrow. In the mean time I wanted to compile and communicate some areas of note on the APENs: - The VOC emission factor in the engine APENs is listed as 0.330 g/hp-hr. I was unable to verify this factor. The spec sheet indicates VOC EF = 0.016 g/hp-hr. Also, resultant VOC emissions (TPY) seem to have a source other than any emission factor I was able to find or deduce. Please indicate what corrections need to be made in the form of authorizing a red -line to the APEN. I checked with RFS Consulting (RFS), the consultant that initially prepared that document, and he agrees that the APEN needs to be corrected to 0.016g/hp-hr for the VOC emission factor. RFS then added the 0.05 formaldehyde factor that was noted in the DCL catalyst spec -sheet for a total VOC factor of 0.066 used in the Tables 5 and 6 of the emission calculation spreadsheets. _ - Glycol Dehy: Please confirm the following typo -error. The requested throughput limit in section 3 is listed as 60 MMSCF/YR; Please confirm this needs to be corrected to 12,900 MMSCF/YR (=60*365) Yes, a correction is necessary to correct that value...60mmscfd x 365 = 21,900mmscfy. Please correct the APEN to 21,900 mmscf/yr. - Glycol Dehy: It appears that 98% was used for the "condenser and combustion device" control efficiency in GlyCalc page 4, please re-evaluate using 95% control. This seems to only have affected the VOC Controlled Emissions Limit. The APEN, section 7, lists 2.726 tpy, and the Division has calculated a value of 5.5 tpy. Please advise if you would like to make a red -line change for this value. A revised GRI GLYCALC report is attached to this email that used the 95% https://mail.google.corn/mail/u/0?ik=01917fb514&view=pt&search=all&permmsgid=msg-f%3A1612611285837132437&simpl=msg-f%3A16126112858... 1/2 Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/aped. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: JUN 292018 nary t vuE o -r t AIRS ID Number: ! j'3 /q FI/R/O(4- [Leave blank unless APCD has already assigned a permit N and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Site Location: Mailing Address: (Include Zip Code) Portable Source Home Base: REP Processing, LLC Pierce Gas Processing Plant 517930E 4500068N Zone 13T Sw44 S21 rtN Rutiw 1611 N. Broadway Ave Oklahoma City, OK 73101 Ka.+ 1i1is p(' a11-ach emit' I Site Location County: NAICS or SIC Code: Weld 211130 Permit Contact: James Fleak Phone Number: 720-889-9955 E -Mail Address2• JFIeak@KahunaVentures.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-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 384847 COLORADO 1 I lir Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit k and AIRS ID] Section 2 - Requested Action 0 NEW permit OR newly -reported emission source (check one below) O STATIONARY source O PORTABLE source • Request coverage under a Construction Permit O Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O Change company name O Add point to existing permit ❑ Change permit limit O Transfer of ownership4 O Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ID APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info £t Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. C-2 General description of equipment and purpose: Waukesha L7044 GSI S5 Compressor 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.qov/cdphe/attainment) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 25 February 2019 0 Yes ❑ No hours/day 7 days/week52 weeks/year Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 2ycoLoaaoo 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 O Pump O Water Pump ❑ Emergency Back-up ❑ Other: 0 Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha Engine Model: L7044 GSI S5 Serial Number6: TBD What is the maximum designed horsepower rating? 1,900 hp What is the engine displacement? l/cyl What is the maximum manufacturer's site -rating? 1,897 hp kW BTU/hp-hr What is the engine Brake Specific Fuel Consumption at 100% Load? 7,158 hours/year Engine Features: Cycle Type: ❑ 2 -Stroke 0 4 -Stroke Combustion: O Lean Burn 0 Rich Burn Ignition Source: 0 Spark ❑ Compression Aspiration: O Natural O Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes O 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 0 No Engine Dates: What is the manufactured date of this engine? TBD What date was this engine ordered? TBD What is the date this engine was first located to Colorado? TBD O Other: What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 3 ©r COLORADO Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longl tude or UTM) 517907E 4500030 Zone 13T Operator Stack ID No. Discharge:Height. Above Ground Level (Fee₹) Temp, ( F) Flow Rate �(ACFM) Velocity (fusee) C-2 39 1,110 8,245 98.91 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): Interior stack diameter (inches): Interior stack diameter (inches): 16 ❑ Upward with obstructing raincap Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Ilse Rate @ 100% Load (5CF/hour.) Actual Annual Fuel Use (MMSEF/year) ` Requested Annual Permit Limit' IMMSCF/year); 13,356.164 117 117 From what year is the actual annual amount? NA Indicate the type of fuel used': ❑ Pipeline Natural Gas 2 Field Natural Gas ❑ Propane ❑ Landfill Gas ❑ Other (describe): (assumed fuel heating value of 1,020 BTU/scf) Heating value: 1,020 BTU/scf (assumed fuel heating value of 2,300 BTU/scf) Heating Value: BTU/scf Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. COLORADO Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 4 I -• Permit Number: AIRS ID Number: [Leave blank Imes; APCD hnr; nit endy ns; rt td -/ ;1Crmit it and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? 2 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) PM 10 PM2.5 SOX NO Nonselective Catalytic Reduction 97.4 VOC CO Nonselective Catalytic Reduction 96.0 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? NA Criteria Pollutant Emissions Inventory Pollutant • Emission Factor 9 Actual Annual Emissions. Requested Annual ; Permit 7 - Emission Limit(s) Uncontrolled Basis Units Source (AP -42, Mfg; etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tanslyear) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) 0.00999 Ib/mmblu AP -42 0.594 0.594 PM 10 0.00999 lb/mmbtu AP -42 0.594 0.594 PMz5 0.00999 lb/mmbtu AP -42 0.594 0.594 SOX 0.000588 Ib/mmblu AP -42 0.035 0.035 NOX 0.3 gPorrhr Mfg Info 212.121 5.495 VOC -946/66.01„‘ g/hp-hr Mfg Info 1.209 1.209 Co 0.400 \ g/hp-hr Mfg Info 162.077 7.327 e,,.,.'f a(k / y/asll8 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 Emiss on Factor Actual Annual Emissions9 Uncontrolled Basis Units __ . Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions, (Pounds/year) Formaldehyde 50000 0.0526 g/1 -h Mfg Acetaldehyde 75070 0,00836 Ib/mmblu AP -42 Acrolein 107028 0.00514 Ib/mmblu AP -42 Benzene 71432 0.000440 Ib/mmblu 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. Form APCD-201 - Reciprocating Internal Combustion Engine APED - Revision 1 /2017 vCOLORADO b - Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] i''' Section 8 - Applicant Certification hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. /44) a /z71/S Signature of Legally orized Person (not a vendor or consultant) Date Kevin Bailey Chief Operating Officer 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 , Revision 1/2017 l COLORADO 6 7/17/2018 State.co.us Executive Branch Mail - Site Location for Pierce Gas Processing Plant S l'AT E O F COLORADO Underriner - CDPHE, Katherine <katherine.underriner@state.co.us> Site Location for Pierce Gas Processing Plant 2 messages Katherine Underriner - CDPHE <katherine.underriner@state.co.us> To: jfleak@kahunaventures.com Hi James, Mon, Jul 16, 2018 at 12:30 PM While looking at the APENs further I noticed that the site location lists coordinates. These coordinates are listed as 417930E 4500068N Zone 13T which is not a format I have seen before. Based on Google Earth, it looks like this is located around 40.650871, -104.787540. Can you please send me the site location is Section, Township, Range format? Thanks, Katherine Underriner Application Completeness Technician Stationary Sources Program COLORADO I Air Pollution Control Division Department of Public Heath fr Enionmen; P 303.692.6381 I F 303.782.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 katherine.underriner@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. As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete APENs. Additional fees may apply if an APEN is submitted without the necessary information. An application with missing information may result in longer processing times. Please note that all APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section II.A). Current APEN forms can be found at: https://www.colorado.gov/cdphe/APENforms James Fleak <JFleak@kahunausa.com> Mon, Jul 16, 2018 at 2:56 PM To: Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Hi Katherine, The UTM coordinates were utilized by the consultant that was initially working with REP Processing and he used those values since he put together the dispersion model. The site is located in the SW/4 of S21 T8N R66W. Hope that helps. I received your message about the tanks to be listed individually. I will call to make sure I'm clear how that Form 102 should state the emissions. James James Fieak, P.E. 720-889-9955 Direct https://mail.google.com/mail/u/0?ik=e82d6de00d&view=pt&search=all&permthid=thread-a%3Ar5610759831789739182&simpl=msg-a%3Ar372031820... 1/2 12/18/2018 State.co.us Executive Branch Mail - Pierce Gas Processing Plant -Status STATE OF COLORADO Sharp - CDPHE, Timothy <timothy.sharp@state.co.us> Pierce Gas Processing Plant -Status James Fleak <JFleak@kahunausa.com> Tue, Sep 25, 2018 at 2:05 PM To: "Sharp - CDPHE, Timothy" <timothy.sharp@state.co.us> Cc: "Ron Sober (rsober@rfsconsulting.com)" <rsober@rfsconsulting.com>, Jesse Warman <JWarman@kahunausa.com> Timothy, Please see responses to your queries below. Thank you for your patience. James Fleak, P.E. 720-889-9955 Direct 720-235-2288 cell From: Sharp - CDPHE, Timothy[mailto:timothy.sharp@State.Co.Us] Sent: Monday, September 24, 2018 4:28 PM To: James Fleak <JFleak@KahunaUSA.com> Subject: Re: Pierce Gas Processing Plant -Status Hello James, I'm in the process of compiling all the permit conditions into a single facility -wide. I expect to have the draft completed by noon tomorrow. In the mean time I wanted to compile and communicate some areas of note on the APENs: - The VOC emission factor in the engine APENs is listed as 0.330 g/hp-hr. I was unable to verify this factor. The spec sheet indicates VOC EF = 0.016 g/hp-hr. Also, resultant VOC emissions (TPY) seem to have a source other than any emission factor I was able to find or deduce. Please indicate what corrections need to be made in the form of authorizing a red -line to the APEN. I checked with RFS Consulting (RFS), the consultant that initially prepared that document, and he agrees that the APEN needs to be corrected to 0.016g/hp-hr for the VOC emission factor. RFS then added the 0.05 formaldehyde factor that was noted in the DCL catalyst spec sheet for a total VOC factor of 0.066 used in the Tables 5 and 6 of the emission calculation spreadsheets. - Glycol Dehy: Please confirm the following typo -error. The requested throughput limit in section 3 is listed as 60 MMSCF/YR; Please confirm this needs to be corrected to 12,900 MMSCF/YR (=60*365) Yes, a correction is necessary to correct that value...60mmscfd x 365 = 21,900mmscfy. Please correct the APEN to 21,900 mmscf/yr. - Glycol Dehy: It appears that 98% was used for the "condenser and combustion device" control efficiency in GlyCalc page 4, please re-evaluate using 95% control. This seems to only have affected the VOC Controlled Emissions Limit. The APEN, section 7, lists 2.726 tpy, and the Division has calculated a value of 5.5 tpy. Please advise if you would like to make a red -line change for this value. A revised GRI GLYCALC report is attached to this email that used the 95% https://mail.google.com/mail/u/0?ik=01917fb514&view=pt&search=all&permmsgid=msg-f%3A1612611285837132437&simpl=msg-f%3A16126112858... 1/2 Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit Alt sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. L; li Jiit4 2 9 2018 I' Permit Number: 18NE0111 AIRS ID Number: i Z3 foFDIS/006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Site Name: Site Location: REP Processing, LLC Pierce Gas Processing Plant to -A per att-aClu4 (man 517930E 4500068N Zone 13T SIN 4- S2.1 1-81\1 RItUW Mailing Address: (Include Zip Code) 1611 N. Broadway Ave Portable Source Home Base: Oklahoma City, OK 73101 Site Location County: Weld NAICS or SIC Code: 211130 Permit Contact: James Fleak Phone Number: 720-889-9955 E -Mail AddressZ• JFleak©KahunaVentures.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. 384848 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit k and AIRS ID] Section 2 - Requested Action El NEW permit OR newly -reported emission source (check one below) El O STATIONARY source O PORTABLE source O Request coverage under a Construction Permit O Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR- MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O Change company name O 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 O Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Et Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. C-3 General description of equipment and purpose: Waukesha L7O44 GSI S5 Compressor 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.goy/cdphe/attainment) Normal Flours of Source Operation: 24 hours/day 7 February 2019 OYes ON Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 days/week52 June -Aug: 25 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 weeks/year Sept -Nov: 25 /`W COLORADO 2 I Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit ft and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump O Water Pump o Emergency Back-up ❑ Other: 0 Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha Engine Model: L7044 GSI S5 Serial Number6: TBD What is the maximum designed horsepower rating? 1,900 hp What is the engine displacement? l/cyl What is the maximum manufacturer's site -rating? 1,897 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,158 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke El 4 -Stroke Combustion: ❑ Lean Burn 0 Rich Burn Ignition Source: 0 Spark ❑ Compression Aspiration: ❑ Natural O Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes ❑ No hours/year If yes, what type of AFRC is in use? 0 O2 Sensor (mV) ❑NOx Sensor (ppm) Is this engine equipped with a Low-NOx design? ❑ Yes 0 No Engine Dates: What is the manufactured date of this engine? TBD What date was this engine ordered? TBD O Other: What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? O Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN • Revision 1 /2017 J _ COLOR&DO 3 M�;r.."" 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) 517907E 4500018N Zone 13T operator Stack ID No. a DischargeLHeight Above Ground Level (eet) Temp ( F) Flow. Rate (ACFM) Velocity r' (f 1 C-3 39 1,110 8,245 98.91 Indicate the direction of the Stack outlet: (check one) I] Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑i Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): Interior stack diameter (inches): ❑ Upward with obstructing raincap 16 Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate 1OO% Load (SCF/hour) Actual Annual Fuel Use. ; (MMSCF/year) - Requested Annual Permit Limit1 ` (MMSCF/year) 13,356.164 117 117 From what year is the actual annual amount? NA Indicate the type of fuel used': ❑ Pipeline Natural Gas Field Natural Gas ❑ Propane ❑ Landfill Gas ❑ Other (describe): (assumed fuel heating value of 1,0208TU/scf) Heating value: 1,020 BTU/scf (assumed fuel heating value of 2,300 8TU/scf) Heating Value: BTU/scf Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 if fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 AV cocaReoo r; Permit Number: AIRS ID Number: / / [Leave f.tlanl< ante.;; APCD has all eddy 7i , Rned .1 pct reit. /1 and AIRS IIJ) 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? O 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 5Ox NOx Nonselective Catalytic Reduction 97.4 VOC CO Nonselective Catalytic Reduction 96.0 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? NA Criteria Pollutant Emissions Inventory Pollutant Emission Factor 9 - Actual Annual Emissions Requested AnnualPermit — -- -- .— 7 - Emission Limit(s) 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) 0.00999 Ib/mmbtu AP -42 0.594 0.594 PM10 0.00999 lb/mmbtu AP -42 0.594 0.594 PML5 0.00999 lb/mmbtu AP -42 0.594 0.594 SOx 0.000588 Iblmmbtu AP -42 0.035 0.035 NOx 0.3 glhp-hr Mfg Info 212.121 5 495 VOC 0.0380.016 g/hp-hr Mfg Info 1.209 1.209 CO 0.400 I g/hp-hr Mfg Info _ - 1 182 077 7,327 Does the emissions source have any uncc {trolled actual emission's of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? D Yes ❑ No If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number - Emission Factor Actual Annual Emissions' . Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) o Controlled Emissions (Pounds/year) Formaldehyde 50000 acme g/hp-h Mfg Acetaldehyde 75070 0.00838 Iblmmbtu AP -42 Acrolein 107028 000514 lb/mmblu AP -42 Benzene 71432 0,000440 lb/mmblu 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. Form APCD-201 - Reciprocating Intel nal Combustion Engine APEPI - P,evi sien 1 /2017 AvTy CGLOR. Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS IDl Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. 6127/18 Signature of Legally Autho zed Person (not a vendor or consultant) Date Kevin Bailey Chief Operating Officer Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance D Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 AV coy anaoo 6 7/17/2018 State.co.us Executive Branch Mail - Site Location for Pierce Gas Processing Plant STATE OF COLORADO Underriner - CDPHE, Katherine <katherine.underriner@state.co.us> Site Location for Pierce Gas Processing Plant 2 messages Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Mon, Jul 16, 2018 at 12:30 PM To: jfleak@kahunaventures.com Hi James, While looking at the APENs further I noticed that the site location lists coordinates. These coordinates are listed as 417930E 4500068N Zone 13T which is not a format I have seen before. Based on Google Earth, it looks like this is located around 40.650871, -104.787540. Can you please send me the site location is Section, Township, Range format? Thanks, Katherine Underriner Application Completeness Technician Stationary Sources Program COLORADO I Air Pollution Control Division Deparanent of Pubhc HeaLt a Environment P 303.692.6381 I F 303.782.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 katherine.underriner@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. As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete APENs. Additional fees may apply if an APEN is submitted without the necessary information. An application with missing information may result in longer processing times. Please note that all APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section II.A). Current APEN forms can be found at: https://www.colorado.gov/cdphe/APENforms James Fleak <JFleak@kahunausa.com> Mon, Jul 16, 2018 at 2:56 PM To: Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Hi Katherine, The UTM coordinates were utilized by the consultant that was initially working with REP Processing and he used those values since he put together the dispersion model. The site is located in the SW/4 of S21 T8N R66W. Hope that helps. I received your message about the tanks to be listed individually. I will call to make sure I'm clear how that Form 102 should state the emissions. James James Fleak, P.E. 720-889-9955 Direct https://mail.google.com/mail/u/0?ik=e82d6de00d&view=pt&search=all&permthid=thread-a%3Ar5610759831789739182&simpl=msg-a%3Ar372031820... 1/2 12/18/2018 State.co.us Executive Branch Mail - Pierce Gas Processing Plant -Status STATE OF COLORADO Sharp - CDPHE, Timothy <timothy.sharp@state.co.us> Pierce Gas Processing Plant -Status James Fleak <JFleak@kahunausa.com> Tue, Sep 25, 2018 at 2:05 PM To: "Sharp-- CDPHE, Timothy" <timothy.sharp@state.co.us> Cc: "Ron Sober (rsober@rfsconsulting.com)" <rsober@rfsconsulting.com>, Jesse Warman <JWarman@kahunausa.com> Timothy, Please see responses to your queries below. Thank you for your patience. James Fleak, P.E. 720-889-9955 Direct 720-235-2288 cell From: Sharp - CDPHE, Timothy[mailto:timothy.sharp@state.co.us] Sent: Monday, September 24, 2018 4:28 PM To: James Fleak <JFleak@KahunaUSA.com> Subject: Re: Pierce Gas Processing Plant -Status Hello James, I'm in the process of compiling all the permit conditions into a single facility -wide. I expect to have the draft completed by noon tomorrow. In the mean time I wanted to compile and communicate some areas of note on the APENs: - The VOC emission factor in the engine APENs is listed as 0.330 g/hp-hr. I was unable to verify this factor. The spec sheet indicates VOC EF = 0.016 g/hp-hr. Also, resultant VOC emissions (TPY) seem to have a source other than any emission factor I was able to find or deduce. Please indicate what corrections need to be made in the form of authorizing a red -line to the APEN. I checked with RFS Consulting (RFS), the consultant that initially prepared that document, and he agrees that the APEN needs to be corrected to 0.016g/hp-hr for the VOC emission factor. RFS then added the 0.05 formaldehyde factor that was noted in the DCL catalyst spec sheet for a total VOC factor of -0.066 used in the Tables 5 and 6 of the emission calculation spreadsheets. - Glycol Dehy: Please confirm the following typo -error. The requested throughput limit in section 3 is listed as 60 MMSCF/YR; Please confirm this needs to be corrected to 12,900 MMSCF/YR (=60"365) Yes, a correction is necessary to correct that value...60mmscfd x 365 = 21,900mmscfy. Please correct the APEN to 21,900 mmscf/yr. - Glycol Dehy: It appears that 98% was used for the "condenser and combustion device" control efficiency in GlyCalc page 4, please re-evaluate using 95% control. This seems to only have affected the VOC Controlled Emissions Limit. The APEN, section 7, lists 2.726 tpy, and the Division has calculated a value of 5.5 tpy. Please advise if you would like to make a red -line change for this value. A revised GRI GLYCALC report is attached to this email that used the 95% https://mail.google.com/mail/u/0?ik=01917fb514&view=pt&search=all&permmsgid=msg-P/03A1612611285837132437&simpl=msg-f%3A16126112858... 1/2 Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apod. 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: JIM 292018 8YV6Q11 AIRS ID Number: 12,3 /61FDB/oO(P [Leave blank unless APCD has already assigned a permit II and AIRS 10] Section 1 - Administrative Information Company Name: Site Name: Site Location: Mailing Address: (Include Zip Code) Portable Source Home Base: REP Processing, LLC Pierce Gas Processing Plant 517930E 4500068N Zone 13T Swk- S2I 1-3N 9-tItUw 1611 N. Broadway Ave Oklahoma City, OK 73101 K.tA 111-O Pt r attucad emat t Site Location County: NAICS or SIC Code: Weld 211130 Permit Contact: James Fleak Phone Number: 720-889-9955 E -Mail AddressZ- JFleak@KahunaVentures.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on alt documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 384849 Form APCD-2O1 Reciprocating Internal Combustion Engine APEN - Revision 1/2017 1 IA COLORADO 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) O STATIONARY source ❑ PORTABLE source O Request coverage under a Construction Permit O Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O Change company name O Add point to existing permit O Change permit limit ❑ Transfer of ownership4 O Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info & Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. C-4 General description of equipment and purpose: Waukesha L7044 GSI S5 Compressor 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: 25 February 2019 0 Yes ❑ No hours/day 7 days/week52 weeks/year Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Reciprocating Internal Combustion Engine APEN • Revision 112017 ^� COLORADO 2 l 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 O Water Pump ❑ Emergency Back-up ❑ Other: s Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha Engine Model: L7044 GSI S5 Serial Number6: TBD What is the maximum designed horsepower rating? What is the maximum manufacturer's site -rating? What is the engine Brake Specific Fuel Consumption Engine Features: Cycle Type: Ignition Source: 1,900 hp What is the engine displacement? kW 7,158 BTU/hp-hr 1,897 hp at 100% Load? ❑ 2 -Stroke 0 4 -Stroke Combustion: O Lean Burn [j Spark O Compression Aspiration: O Natural Is this engine equipped with an Air/Fuel ratio controller (AFRC)? j] Yes O 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? O Yes 0 No Engine Dates: What is the manufactured date of this engine? What date was this engine ordered? TBD TBD ❑ Other: hours/year l/cyl 0 Rich Burn ❑ Turbocharged What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? D Yes @] No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN . Revision 1/2017 3 COLORADO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information 517907E 4500006N Zone 13T Tem '� p' Flo Rate � '{' Ue o tty -I (� ator=- Discha[geHe,gh Abo Ground+lYeve 1 Op re Pte Staac ID'No "_ ,, F ,_ � s;� (AGF 8,245 (ftsec) 98.91 Fee C-4 39 1,110 Indicate the direction of the Stack outlet: (check one) 0 Upward O Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): Interior stack diameter (inches): O Upward with obstructing raincap 16 Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information atualrAnnua Fuel_�Use years nLte§uestediAnnual l erm_rt�Lvnrt-. 9 CF°.yea .._ FPGe G e'�`Itat :el;00%Loa• v SCI,pub ' - '!l 13,356.164 _ ..-� 117 117 From what year is the actual annual amount? NA Indicate the type of fuel used': ❑ Pipeline Natural Gas 0 Field Natural Gas ❑ Propane ❑ Landfill Gas O Other (describe): (assumed fuel heating value of 1,020 BTU/scf) Heating value: 1,020 BTU/scf (assumed fuel heating value of 2,300 BTU/scf) Heating Value: BTU/scf Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. S If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 'COLORADO 4 I "wIW FEwllnnm�nl li! Permit Number: AIRS ID Number: [Leave blink unit.e;; APCD has call; nssli_liv ci o prrmit. (/ anri 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? 2 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 Nonselective Catalytic Reduction 97.4 VOC CO Nonselective Catalytic Reduction 96.0 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? NA Criteria Pollutant Emissions Inventory Pollutant -. -Requested Emission Factor - Actual Annual Emissions 9 = _ Annual Permit .. 7 -, - _ Emission Limits) Uncontrolled Basis > Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emission (Tonslyeo r) TSP (PM) 0.00999 Ib/mmblu AP -42 0.594 0.594 PMio 0.00999 Ib/mmbtu AP -42 0.594 0.594 PM2.50.00999 Ib/mmbtu AP -42 0.594 0.594 SOx 0.000588 lb/mmblo AP -42 0.035 0.035 NOx 0,3 g/hp-hr Mfg Info 212.121 5495 VOC 8,836, 0,at b g/hp-hr Mfg Info 1.209 1.209 CO 0.400 g/hp-hr Mfg Info 182,077 7.327 fl!'lAlz +WRLGI�O y/e✓f(d 'id Does the emissions source ha a any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? (] Yes ❑ No If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number` Emission Factor Actual Annual Emissions' Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled . Emissions (Pounds/year) Controlled Emissions (Pounds/year) Formaldehyde 50000 0,0528 gmp-h Mfg Acetaldehyde 75070 0.00838 Ib/mmhtu AP -42 Acrolein 107028 0,00514 Ib/mmbtu AP -42 Benzene 71432 0.000440 lb/mmbto 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. Ferro APCD-201 - Reciprocating Internal Cn'nbustion Engine APEN - Revision 1/2017 ®V co�orsnoo 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 GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. Signature of Legally Auth ized Person (not a vendor or consultant) Date Kevin Bailey Name (please print) Chief Operating Officer Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance ID Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South 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 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692.3148 Form APCD-"201 - Reciprocating Internal Combustion Engine APEN • Revision 1/2017 IL11 COLORADO 7/17/2018 State.co.us Executive Branch Mail - Site Location for Pierce Gas Processing Plant STATE OF COLORADO Underriner - CDPHE, Katherine <katherine.underriner@state.co.us> Site Location for Pierce Gas Processing Plant 2 messages Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Mon, Jul 16, 2018 at 12:30 PM To: jfleak@kahunaventures.com Hi James, While looking at the APENs further I noticed that the site location lists coordinates. These coordinates are listed as 417930E 4500068N Zone 13T which is not a format I have seen before. Based on Google Earth, it looks like this is located around 40.650871, -104.787540. Can you please send me the site location is Section, Township, Range format? Thanks, Katherine Underriner Application Completeness Technician Stationary Sources Program COLORADO Air Pollution Control Division Department of Pubdc Health & Environment P 303.692.6381 I F 303.782.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 katherine.underriner@state.co.us I www.colorado.gov/cdphe/aped Are you curious about ground -level ozone in Colorado? Visit our ozone webpage to learn more. As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete APENs. Additional fees may apply if an APEN is submitted without the necessary information. An application with missing information may result in longer processing times. Please note that alt APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section II.A). Current APEN forms can be found at: https://www.colorado.gov/cdphe/APENforms James Fleak <JFleak@kahunausa.com> Mon, Jul 16, 2018 at 2:56 PM To: Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Hi Katherine, The UTM coordinates were utilized by the consultant that was initially working with REP Processing and he used those values since he put together the dispersion model. The site is located in the SW/4 of S21 TSN R66W. Hope that helps. I received your message about the tanks to be listed individually. I will call to make sure I'm clear how that Form 102 should state the emissions. James James Fleak, P.E. 720-889-9955 Direct https://mail.google.com/mail/u/0?ik=e82d6de00d&view=pt&search=all&permthid=thread-a%3Ar5610759831789739182&simpl=msg-a%3Ar372031820... 1/2 12/18/2018 State.co.us Executive Branch Mail - Pierce Gas Processing Plant -Status STATE OF COLORADO Sharp - CDPHE, Timothy <timothy.sharp@state.co.us> Pierce Gas Processing Plant -Status James Fleak <JFleak@kahunausa.com> Tue, Sep 25, 2018 at 2:05 PM To: "Sharp - CDPHE, Timothy" <timothy.sharp@state.co.us> Cc: "Ron Sober (rsober@rfsconsulting.com)" <rsober@rfsconsulting.com>, Jesse Warman <JWarman@kahunausa.com> Timothy, Please see responses to your queries below. Thank you for your patience. James Fleak, P.E. 720-889-9955 Direct 720-235-2288 cell From: Sharp - CDPHE, Timothy[mailto:timothy.sharp@state.co.us] Sent: Monday, September 24, 2018 4:28 PM To: James Fleak <JFleak@KahunaUSA.com> Subject: Re: Pierce Gas Processing Plant -Status Hello James, I'm in the process of compiling all the permit conditions into a single facility -wide. I expect to have the draft completed by noon tomorrow. In the mean time I wanted to compile and communicate some areas of note on the APENs: - The VOC emission factor in the engine APENs is listed as 0.330 g/hp-hr. I was unable to verify this factor. The spec sheet indicates VOC EF = 0.016 g/hp-hr. Also, resultant VOC emissions (TPY) seem to have a source other than any emission factor I was able to find or deduce. Please indicate what corrections need to be made in the form of authorizing a red -line to the'APEN. I checked with RFS Consulting (RFS), the consultant that initially prepared that document, and he agrees that the APEN needs to be corrected to 0.016g/hp-hr for the VOC emission factor. RFS then added the 0.05 formaldehyde factor that was noted in the DCL catalyst spec sheet for a total VOC factor of 0.066 used in the Tables 5 and 6 of the emission calculation spreadsheets. - Glycol Dehy: Please confirm the following typo -error. The requested throughput limit in section 3 is listed as 60 MMSCF/YR; Please confirm this needs to be corrected to 12,900 MMSCF/YR (=60*365) Yes, a correction is necessary to correct that value...60mmscfd x 365 = 21,900mmscfy. Please correct the APEN to 21,900 mmscf/yr. - Glycol Dehy: It appears that 98% was used for the "condenser and combustion device" control efficiency in GlyCalc page 4, please re-evaluate using 95% control. This seems to only have affected the VOC Controlled Emissions Limit. The APEN, section 7, lists 2.726 tpy, and the Division has calculated a value of 5.5 tpy. Please advise if you would like to make a red -line change for this value. A revised GRI GLYCALC report is attached to this email that used the 95% https://mail.google.com/mail/u/0?ik=01917fb514&view=pt&search=all&permmsgid=msg-f%3A1612611285837132437&simpl=msg-f%3A16126112858... 1/2 Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit ALL sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.cotorado.gov/cdphe/aped. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: ligE0"!11 AIRS ID Number: (23 /gFDP)001 [Leave blank unless APCD has already assigned a permit N and AIRS ID] Section 1 - Administrative Information p{E/ Company Name': REP Processing, LLC attoichtd emac i Site Name: Pierce Gas Processing Plant Site Location Site Location: 517930E 4500068N Zone 13T County: Weld S i!4 set TSN R-WJVJ NAICS or SIC Code: 211130 Mailing Address: (Include Zip Code) 1611 N. Broadway Ave Oklahoma City, OK 73101 Permit Contact: James Fleak Phone Number: 720-889-9955 Portable Source Home Base: E -Mail Address2: JFleak@KahunaVentures.com 1 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-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 384.850 1 ItV coLOR&.oa Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action [r] NEW permit OR newly -reported emission source (check one below) • STATIONARY source 0 PORTABLE source O Request coverage under a Construction Permit O Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 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 O Change permit limit 0 Transfer of ownership" 0 Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info & Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. General description of equipment and purpose: C-5 Waukesha L7044 GSI S5 Compressor For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: February 2019 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: 25 hours/day 7 Mar -May: 25 0 Yes ❑ No days/week 52 June -Aug: 25 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 weeks/year Sept -Nov: 25 I'vW COLORADO Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit rY and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump O Water Pump ❑ Emergency Back-up ❑ Other: 0 Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha Engine Model: L7044 GSI S5 Serial Number6: TBD What is the maximum designed horsepower rating? 1,900 hp What is the engine displacement? l/cyl What is the maximum manufacturer's site -rating? 1,897 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,158 BTU/hp-hr Engine Features: Cycle Type: O 2 -Stroke 0 4 -Stroke Combustion: O Lean Burn 0 Rich Burn Ignition Source: 0 Spark O Compression Aspiration: ❑ Natural ❑ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? I] Yes O No If yes, what type of AFRC is in use? ID OZ Sensor (mV) ONOx Sensor (ppm) ❑ Other: Is this engine equipped with a Low-NOx design? O Yes 0 No Engine Dates: What is the manufactured date of this engine? TBD What date was this engine ordered? TBD What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD hours/year What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? O Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLOR D O 3 L,f3M41'CC_fY 0 Upward 0 Horizontal Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates, (Latitude/Lonsitude or UTM) 517907E 4499993N Zone 13T Operator Stack ID NO Discharge Height Above Ground Level (Feet) Temp ( F) Flow Rate fACFM}y Ve)ac�ty (ftrsec) C-5 39 1,110 8,245 98.91 Indicate the direction of the Stack outlet: (check one) ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) r❑ Circular Interior stack diameter (inches): ❑ Square/Rectangle Interior stack diameter (inches): ❑ Other (describe): 0 Upward with obstructing raincap 16 Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate ® 100% Load (SCFlhai,rf __ � Actual Annual Fuel Use - Requested Annual Permit Limits (MMSCF/year) 13,356.164 117 117 From what year is the actual annual amount? NA Indicate the type of fuel used': ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑r Field Natural Gas Heating value: 1,020 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 4 I p�( iJ{C0L0RAD.D Permit Number: AIRS ID Number: [Lcavc blank unless APCD has already n:,::sii eel a pertnit If and AIRS IUi 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? El 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 /n emissions) TSP (PM) PM10 PM2.5 SOx NOx Nonselective Catalytic Reduction 97.4 VOC CO Nonselective Catalytic Reduction 96.0 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? NA Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions s - Requested Annual Permit - , 7 '..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) 0.594 TSP (PM) 0.00999 Ib/mmbtu AP -42 0.594 PM10 0.00999 lb/mmbtu AP -42 0.594 0.594 PM2-5 0.00999 lb/mmbtu AP -42 - 0.594 0.594 SO 0.000588 lb/mmbtu AP -42 0.035 0.035 NOx 0.3 glhp-hr Mfg Info 212.121 5.495 VOC -9,2°300,ot b g/hp-hr- Mfg Info 1.209 1.209 CO t 0.400 1 g/hp-hr Mfg Info - 162.077 7.327 Does the emissions source have anyancontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: I Yes ❑ No Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions' Uncontrolled Basis Units Source P-42 Mfg. etc) Uncontrolled": Emissions (Pounds/year) Controlled Emissions (pounds/year} Formaldehyde 50000 0.0528 9/hp-h Mfg Acetaldehyde 75070 0.00838 Ib/mmblu AP -42 Acrolein 107028 0.00514 Ib/mmbtu AP -42 Benzene 71432 0.000440 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. Form APCD-201 Reciprocating Internal Combustion Engine APEN - Revision 1/2017 5 ' Y co�arsnoo Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] h Section 8 - Applicant Certification hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP0Z. K-livt%adia e/ 7/ft Signature of Legally Kevin Bailey Name (please print) Chief Operating Officer 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/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 Combustion Engine APEN - Revision 1/2017 coLoaa4o 6i�...,„ 7/17/2018 State.co.us Executive Branch Mail - Site Location for Pierce Gas Processing Plant STATE OF COLORADO Underriner - CDPHE, Katherine <katherine.underriner@state.co.us> Site Location for Pierce Gas Processing Plant 2 messages Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Mon, Jul 16, 2018 at 12:30 PM To: jfleak@kahunaventures.com Hi James, While looking at the APENs further I noticed that the site location lists coordinates. These coordinates are listed as 417930E 4500068N Zone 13T which is not a format I have seen before. Based on Google Earth, it looks like this is located around 40.650871, -104.787540. Can you please send me the site location is Section, Township, Range format? Thanks, Katherine Underriner Application Completeness Technician Stationary Sources Program ICOLORADO Air Pollution Control Division Department of Rbtic Hawn fr Ernircnment P 303.692.6381 I F 303.782.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 katherine.underriner@state.co.us ,l www.colorado.gov/cdphe/apcd Are you curious about ground -level ozone in Colorado? Visit our ozone webpage to learn more. As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete APENs. Additional fees may apply if an APEN is submitted without the necessary information. An application with missing information may result in longer processing times. Please note that all APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section II.A). Current APEN forms can, be found at: https://www.colorado.gov/cdphe/APENforms James Fleak <JFleak@kahunausa.com> Mon, Jul 16, 2018 at 2:56 PM To: Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Hi Katherine, The UTM coordinates were utilized by the consultant that was initially working with REP Processing and he used those values since he put together the dispersion model. The site is located in the SW/4 of S21 TEN R66W. Hope that helps. I received your message about the tanks to be listed individually. I will call to make sure I'm clear how that_ Form 102 should state the emissions. James James Fleak, P.E. 720-889-9955 Direct https://mail.google.com/mail/u/0?ik=e82d6de00d&view=pt&search=all&permthid=thread-a%3Ar5610759831789739182&simpl=msg-a%3Ar372031820... 1/2 12/18/2018 State.co.us Executive Branch Mail - Pierce Gas Processing Plant -Status STATE OF COLORADO? Sharp - CDPHE, Timothy <timothy.sharp@state.co.us> Pierce Gas Processing Plant -Status James Fleak <JFleak@kahunausa.com> To: "Sharp - CDPHE, Timothy" <timothy.sharp@state.co.us> Cc: "Ron Sober (rsober@rfsconsulting.com)" <rsober@rfsconsulting.com>, Jesse Warman <JWarman@kahunausa.com> Timothy, Please see responses to your queries below. Thank you for your patience. James Fleak, P.E. 720-889-9955 Direct 720-235-2288 cell From: Sharp - CDPHE, Timothy[mailto:timothy.sharp@state.co.us] Sent: Monday, September 24, 2018 4:28 PM To: James Fleak <JFleak@KahunaUSA.com> Subject: Re: Pierce Gas Processing Plant -Status Hello James, Tue, Sep 25, 2018 at 2:05 PM I'm in the process of compiling all the permit conditions into a single facility -wide. I expect to have the draft completed by noon tomorrow. In the mean time I wanted to compile and communicate some areas of note on the APENs: - The VOC emission factor in the engine APENs is listed as 0.330 g/hp-hr. I was unable to verify this factor. The spec sheet indicates VOC EF = 0.016 g/hp-hr. Also, resultant VOC emissions (TPY) seem to have a "source other than any emission factor I was able to find or deduce. Please indicate what corrections need to be made in the form of authorizing a red -line to the APEN. I checked with RFS Consulting (RFS), the consultant that initially prepared that document, and he agrees that the APEN needs to be corrected to 0.016g/hp-hr for the VOC emission factor. RFS then added the 0.05 formaldehyde factor that was noted in the DCL catalyst spec sheet for a total VOC factor of 0.066 used in the Tables 5 and 6 of the emission calculation spreadsheets. - Glycol Dehy: Please confirm the following typo -error. The requested throughput limit in section 3 is listed as 60 MMSCF/YR; Please confirm this needs to be corrected to 12,900 MMSCF/YR (=60*365) Yes, a correction is necessary to correct that value...60mmscfd x 365 = 21,900mmscfy. Please correct the APEN to 21,900 mmscf/yr. - Glycol Dehy: It appears that 98% was used for the "condenser and combustion device" control efficiency in GlyCalc page 4, please re-evaluate using 95% control. This seems to only have affected the VOC Controlled Emissions Limit. The APEN, section 7, lists 2.726 tpy, and the Division has calculated a value of 5.5 tpy. Please advise if you would like to make a red -line change for this value. A revised GRI GLYCALC report is attached to this email that used the 95% https://mail.google.corn/mail/u/0?ik=01917fb514&view=pt&search=all&permmsgid=msg-f%3A1612611285837132437&simpl=msg-f%3A16126112858... 1/2 Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating 'internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-2.OO) 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: I g W 011"1 AIRS ID Number: 123 Wotal 0Qg [Leave blank unless APCD has already assigned a permit. x and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Site Location: Mailing Address: (Include Zip Code) Portable Source Home Base: REP Processing, LLC Pierce Gas Processing Plant 517930E 4500068N Zone 13T SW1 - S2-! T'{i PAPW 1611 N. Broadway Ave Oklahoma City, OK 73101 Kam- 111111k re a -t1 zocf ttn t t Site Location County: Weld NAICS or SIC Code: 211130 Permit Contact: James Fleak Phone Number: 720-889-9955 E -Mail Address2: JFleak@KahunaVentures.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. 384852 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 1 I A�COLORADO AV- Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit N and AIRS ID] Section 2 - Requested Action EI NEW permit OR newly -reported emission source (check one below) ID STATIONARY source O PORTABLE source ▪ Request coverage under a Construction Permit O Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O Change company name O Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership" ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Et Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. General description of equipment and purpose: C-6 Waukesha L7044 GSI S5 Compressor For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: February 2019 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: 25 Li Yes ❑ No hours/day 7 days/week52 weeks/year Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD-201 Reciprocating Internal Combustion Engine APEN - Revision 1/2017 "W COLORADO 2 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine ❑ Primary and/or Peaking ❑ Emergency Back-up Function: ❑ Pump 0 Water Pump 0 Other: 0 Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha Engine Model: L7044 GSI S5 Serial Number6: TBD What is the maximum designed horsepower rating? 1,900 hp What is the engine displacement? 1/cyl hours/year What is the maximum manufacturer's site -rating? 1,897 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,158 BTU/hp-hr Engine Features: Cycle Type: 0 2 -Stroke 0 4 -Stroke Combustion: ❑ Lean Burn 0 Rich Burn Ignition Source: D Spark ❑ Compression Aspiration: 0 Natural ❑ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 9 Yes ❑ No If yes, what type of AFRC is in use? 9 OZ Sensor (mV) ❑NOx Sensor (ppm) ❑ Other: Is this engine equipped with a Low-NOx design? ❑ Yes 0 No Engine Dates: What is the manufactured date of this engine? TBD What date was this engine ordered? TBD What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? ❑ Yes 9 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 AV COLORADO 3 �/.1ydi , 13,356.164 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) 517907E 4499981N Zone 13T Operator.' Stack ID No Discharge HeightTemp. ove Ground Level ' (Feet) ( F) Flow Rate (aCFM) " Velocity (ftlaecf C-6 39 1,110 8,245 98.91 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 ❑ Square/Rectangle Interior stack diameter (inches): ❑ Other (describe): Interior stack diameter (inches): O Upward with obstructing raincap 16 Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Actual Annual Fuel Use: (MMSCF/ year) 117 equested Annual Permit Limit (MMSCFYyear)' 117 From what year is the actual annual amount? NA Indicate the type of fuel used': O Pipeline Natural Gas Ej Field Natural Gas O Propane ❑ Landfill Gas ❑ Other (describe): (assumed fuel heating value of 1,020 BTU/scf) Heating value: 1,020 BTU/scf (assumed fuel heating value of 2,300 BTU/scf) Heating Value: BTU /scf Heating Value (give units): Requested values will become permit limitations. Requested limit(s) should consider future process growth. e 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 L�I CEO LORADO i!I Permit Number: AIRS ID Number: [Leavc Wank unlcs.; APCD has ah cady assil;nr_d a permit It and AIRS I01 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) PM 10 PM25 SOX NOx Nonselective Catalytic Reduction 97.4 VOC CO Nonselective Catalytic Reduction 96.0 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? NA Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions' Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis e Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) 0.00999 Ib/mmbtu AP -42 0.594 0.594 PM10 0.00999 lb/rnmbtu AP -42 0.594 0.594 PM2,5 0.00999 Ib/mmbtu AP -42 0.594 0.594 SOx 0.000588 Ib/mmblu AP -42 0.035 0 035 NOx 0,3 g/hp-hr Mfg Info 212121 5.495 VOC -0330.016, 9/hp-hr Mfg Info 1.209 1.209 Co 0.400 B/hp-hr Mfg Info' r _ 182.077 7.327 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 If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical , Abstract Service (CAS) Number Emission Factor Actual Annual Emissions' Uncontrolled Basis Units Source (AP -42 Mfg. etc) Uncontrolled Emissions (Pounds/ year) Controlled Emissions (Pounds/year) Formaldehyde 50000 0.0528 g/hp-h Mfg Acetaldehyde 75070 0.00836 lb/mmbtu AP -42 Acrolein 107028 0.00514 Ib/mmbtu AP -42 Benzene 71432 0.000440 Iblmmbtu 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. Form APCD-201 Reciprocating Intel nal Combustion Engine APEN - Revision 1/2017 'AY COLD ItADO 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 GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. /lam � �f a 7//e Signature of Legally Au rized Person (not a vendor or consultant) Date Kevin Bailey Chief Operating Officer Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance Ei 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, H.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-B 1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Form APCD-201 Reciprocating Internal Combustion Engine APEN • Revision 1/2017 ',67 COLORADO 7/17/2018 State.co.us Executive Branch Mail - Site Location for Pierce Gas Processing Plant STATE OF COLORADO Underriner - CDPHE, Katherine <katherine.underriner@state.co.us> Site Location for Pierce Gas Processing Plant 2 messages Katherine Underriner - CDPHE <katherine.underriner@state.co.us> - Mon, Jul 16, 2018 at 12:30 PM To: jfleak@kahunaventures.com Hi James, While looking at the APENs further I noticed that the site location lists coordinates. These coordinates are listed as 417930E 4500068N Zone 13T which is not a format I have seen before. Based on Google Earth, it looks like this is located around 40.650871, -104.787540. Can you please send me the site location is Section, Township, Range format? Thanks, Katherine Underriner Application Completeness Technician Stationary Sources Program (COLORADO Air Pollution Control Division Department of Public Heaft &Em5ronrnent P 303.692.6381 I F 303.782.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 katherine.underriner@state.co.us I www.colorado.gov/cdphelapcd Are you curious about ground -level ozone in Colorado? Visit our ozone webpage to learn more. As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete APENs. Additional fees may apply if an APEN is submitted without the necessary. information. An application with missing information may result in longer processing times. Please note that all APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section II.A). Current APEN forms can be found at: https://www.colorado.gov/cdphe/APENforms James Fleak <JFleak@kahunausa.com> Mon, Jul 16, 2018 at 2:56 PM To: Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Hi Katherine, The UTM coordinates were utilized by the consultant that was initially working with REP Processing and he used those values since he put together the dispersion model. The site is located in the SW/4 of S21 T8N R66W. Hope that helps. I received your message about the tanks to be listed individually. I will call to make sure I'm clear how that Form 102 should state the emissions. James James Fleak, P.E. 720-889-9955 Direct https://mail.google.com/mail/u/0?ik=e82d6de00d&view=pt&search=all&permthid=thread-a%3Ar5610759831789739182&simpl=msg-a%3Ar372031820... 1/2 12/18/2018 State.co.us Executive Branch Mail - Pierce Gas Processing Plant -Status STATE OF COLORADO Sharp - CDPHE, Timothy <timothy.sharp@state.co.us> Pierce Gas Processing Plant -Status James Fleak <JFleak@kahunausa.com> Tue, Sep 25, 2018 at 2:05 PM To: "Sharp - CDPHE, Timothy" <timothy.sharp@state.co.us> Cc: "Ron Sober (rsober@rfsconsulting.com)" <rsober@rfsconsulting.com>, Jesse Warman <JWarman@kahunausa.com> Timothy, Please see responses to your queries below. Thank you for your patience. James Fleak, P.E. 720-889-9955 Direct 720-235-2288 cell From: Sharp - CDPHE, Timothy[mailto:timothy.sharp@state.co.us] Sent: Monday, September 24, 2018 4:28 PM To: James Fleak <JFleak@KahunaUSA.com> Subject: Re: Pierce Gas Processing Plant -Status Hello James, I'm in the process of compiling all the permit conditions into a single facility -wide. I expect to have the draft completed by noon tomorrow. In the mean time I wanted to compile and communicate some areas of note on the APENs: - The VOC emission factor in the engine APENs is listed as 0.330 g/hp-hr. I was unable to verify this factor. The spec sheet indicates VOC EF = 0.016 g/hp-hr. Also, resultant VOC emissions (TPY) seem to have a source other than any emission factor I was able to find or deduce. Please indicate what corrections need to be made in the form of authorizing a red -line to the APEN. I checked with RFS Consulting (RFS), the consultant that initially prepared that document, and he agrees that the APEN needs to be corrected to 0.016g/hp-hr for the VOC emission factor. RFS then added the 0.05 formaldehyde factor that was noted in the DCL catalyst spec sheet for a total VOC factor of 0.066 used in the Tables 5 and 6 of the emission calculation spreadsheets. - Glycol Dehy: Please confirm the following typo -error. The requested throughput limit in section 3 is listed as 60 MMSCF/YR; Please confirm this needs to be corrected to 12,900 MMSCF/YR (=60*365) Yes, a correction is necessary to correct that value...60mmscfd x 365 = 21,900mmscfy. Please correct the APEN to 21,900 mmscf/yr. - Glycol Dehy: It appears that 98% was used for the "condenser and combustion device" control efficiency in GlyCalc page 4, please re-evaluate using 95% control. This seems to only have affected the VOC Controlled Emissions Limit. The APEN, section 7, lists 2.726 tpy, and the Division has calculated a value of 5.5 tpy. Please advise if you would like to make a red -line change for this value. A revised GRI GLYCALC report is attached to this email that used the 95% httos://mail.aooale.com/mail/u/0?ik=01917fb514&view=pt&search=all&permmsgid=msg-f%3A1612611285837132437&simpl=msg-f%3A16126112858... 1/2 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: AIRS ID Number: 123 ti Fi) O I O [Leave blank unless APCD has already assigned a permit if and AIRS ID] Section 1 - Administrative Information Company Name': REP Processing, LLC Site Name: Pierce Gas Processing Plant Site Location: 517930E 4500068N Zone 13T Mailing Address: (include Zip Code) SW I4 .S2.1 Tw N P-ItLP IN 1611 N. Broadway Ave Oklahoma City, OK 73101 Permit Contact: James Fleak E -Mail Address2: JFleak@KahunaVentures.com 4 -TOO ()tie l-achecd Cm4i•i Site Location Weld County: NAICS or SIC Code: 211130 Phone Number: 720-889-9955 I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 384854 1 I Q.T,[ COLORADO a/-4-i.CVS Permit Number: AIRS ID Number: / / [I eave 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) -OR - ❑ MODIFICATION to existing permit (check each box below that applies) O Change process or equipment 0 Change company name 0 Add point to existing permit O Change permit limit 0 Transfer of ownership' 0 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 ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info E Notes: 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: February 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: Facility Type: ❑ Well Production Facility4 ❑ Natural Gas Compressor Station4 Natural Gas Processing Plant4 ❑ Other (describe): 24 hours/day 7 days/week 52 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 COLORADO 2I 11I Permit Number: AIRS ID Number: / / [Leave blank ureiess APCD has already assigned a permit , and AIRS ID] Section 4 - Regulatory Information What is the date that the equipment commenced construction? TB D Will this equipment be operated in any NAAQS nonattainment area?5 0 Yes ❑ No Will this equipment be located at a stationary source that is considered a O Yes (] No Major Source of Hazardous Air Pollutant (HAP) emissions? Are there wet seal centrifugal compressors or reciprocating compressors 0 Yes ❑ No located at this facility? Is this equipment subject to 40 CFR Part 60, Subpart KKK? O Yes 0 No Is this equipment subject to 40 CFR Part 60, Subpart OOOO? ❑ Yes 0 No Is this equipment subject to 40 CFR Part 60, Subpart OOOOa? 0 Yes ❑ No Is this equipment subject to 40 CFR Part 63, Subpart NH? O Yes 0 No Is this equipment subject to Colorado Regulation No. 7, Section XII.G? 0 Yes O No Is this equipment subject to Colorado Regulation No. 7, Section XVII.F? ❑ Yes 0 No Is this equipment subject to Colorado Regulation No. 7, Section XVII.B.3? ❑ Yes 0 No 5 See http://www.colorado.gov/cdphe/state-tmplementation-otans-sips for which areas are designated as attainment/non- attainment. Section 5 - Stream Constituents 0 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 ( %) Toluene (wt %) Ethylbenzene (wt %) Xylene (wt %) n -Hexane (wt %) 2,2, Trimethylpe4 ntane (wt %) Gas 26.55 0.069 0.048 0.024 0.030 0.863 0.004 Heavy Oil (or Heavy Liquid) NA NA NA NA NA NA NA (or Light Liquid) Light oquid) 100.00 0.589 0.198 0.0104 0.0331 9.838 0.105 Water/Oil NA NA NA NA NA NA NA Form APCD-203 - Fugitive Component Leak. Emissions APEN - Revision 7/2017 Aviv COLORADO 3 I Inte Permit Number: AIRS ID Number: / / [leave blank unless APCD has already assigned a permit If and AIRS ID] Section 6 - Geographical Information Geographical Coordinates (Latltude/Longltude or U7M) 517930E 4500068N Zone 13T 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: ❑ 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% tight liquid valve, 45% light liquid pump Q LDAR per 40 CFR Part 60, Subpart OOOO/OOOOa 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: ❑ No WAR Program 6 Attach other supplemental plan to APEN form if needed. Form APCD-203 - Fugitive Component Leak Emissions APEN - Revision 7/2017 4l COLORADO Permit Number: AIRS ID Number: / / (leave blank unless APCD has already assignrrd a pci mit " 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. 0 Table 2-4 was used to estimate emissions7. ❑ Table 2-8 (< 10,000ppmv) was used to estimate emissions7. Use the following table to report the component count used to calculate emissions. The component counts listed in the following table are representative of: El Estimated Component Count ❑ Actual Component Count conducted on the following date: NA Service Equipment Type Connectors Flanges Open -Ended Lines Pump Seals Valves Other9 Gas Counts s 3c(6 1,619 0 0 1,500 170 Emission Factor 0.000441 0.000860 0.004409 0.005291 0.009921 0.019400 Units lb/hr/source lb/hr/source lb/hr/source lb/hr/source lb/hr/source lb/hr/source Heavy Oil (or Heavy Liquid) Counts 0 0 0 0 0 0 Emission Factor NA NA NA NA NA NA Units NA NA NA NA NA Light Oil (or Light Liquid) Counts 5,680 1,639 50 1,981 24 Emission Factor 0.000463 0.000243 0.003086 0.028660 0.005510 0.016534 Units lb/hr/source lb/hr/source lb/hr/source lb/hr/source lb/hr/source lb/hr/source Water/Oil Counts 0 0 0 0 0 0 Emission Factor NA NA NA NA NA Units NA NA NA NA NA NA 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). s 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 Fu itivr Cciinponent Leak Einissions APEN - Revision 7?017 5I Ai r COLORADO Permit Number: AIRS ID Number: / / [Leave blank unless \PCD has already assigned a permit A and AIRS I01 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? NA Use the following table to report the criteria pollutant emissions and non -criteria pollutant (HAP) emissions from source: ons. Chemical Name CAS Number Actual Annual Emissions Requested Annual Permit Emission Limit(s) Uncontrolled (tons/year) Controlled1° (tons/year) Uncontrolled (tons/year) Controlled" - (tons/year) voc NA 93.310 16.425 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 ❑ Yes ® No lbs/year? criteria pollutant (HAP) emissions from source: Chemical Name CAS Number Actual Annual Emissions Requested Annual Permit Emission Limit(s) Uncontrolled (lbs/year) Controlled9 (lbs/year) Uncontrolled (lbs/year) Controlled10 (Ibs/year) Benzene 71432 834.023 101.032 Toluene 108883 293.560 38.456 Ethylbenzene 100414 26.235 5.793 Xylene 1330207 60.204 10.331 n -Hexane 110543 13,781.841 1,636.524 2,2,4 Trimethvloentane 540841 145.229 16.668 Other: 10 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 ry !.c-'-"."6 I ., ..,.,..,�,. 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. 6l- 7lrf Signature of Legally Aut rized Person (not a vendor or consultant) Date Kevin Bailey Chief Operating Officer Name (print) Title Check the appropriate box to request a copy of the: Draft permit prior to issuance Q Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $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 7/2.017 COLORADO r:r,: 7/17/2018 State.co.us Executive Branch Mail - Site Location for Pierce Gas Processing Plant STATE O F COLORADO fi Underriner - CDPHE, Katherine <katherine.underriner@state.co.us> Site Location for Pierce Gas Processing Plant 2 messages Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Mon, Jul 16, 2018 at 12:30 PM To: jfleak@kahunaventures.com Hi James, While looking at the APENs further I noticed that the site location lists coordinates. These coordinates are listed as 417930E 4500068N Zone 13T which is not a format I have seen before. Based on Google Earth, it looks like this is located around 40.650871, -104.787540. Can you please send me the site location is Section, Township, Range format? Thanks, Katherine Underriner Application Completeness Technician Stationary Sources Program (COLORADO Air Pollution Control Division i Department of Vubitc Heath &Environment P 303.692.6381 I F. 303.782.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 katherine.underriner@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. As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete APENs. Additional fees may apply if an APEN is submitted without the necessary information. An application with missing information may result in longer processing times. Please note that all APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section II.A). Current APEN forms can be found at: https://www.colorado.gov/cdphe/APENforms James Fleak <JFleak@kahunausa.com> To: Katherine Underriner - CDPHE<katherine.underriner@state.co.us> Hi Katherine, Mon, Jul 16, 2018 at 2:56 PM The UTM coordinates were utilized by the consultant that was initially working with REP Processing and he used those values since he put together the dispersion model. The site is located in the SW/4 of 521 T8N R66W. Hope that helps. I received your message about the tanks to be listed individually. I will call to make sure I'm clear how that Form 102 should state the emissions. James James Fleak, P.E. 720-889-9955 Direct https://mail.google.com/mail/u/0?ik=e82d6de00d&view=pt&search=all&permthid=thread-a%3Ar5610759831789739182&simpl=msg-a%3Ar372031820... 1/2 5 -r eo /dry•" Glycol Dehydration Unit APEN - Form APCD-202 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Glycol Dehydration (Dehy) Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.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: � VVE 0111 AIRS ID Number: 12.3 MFD(3/ O f( [Leave blank unless APCD has already assigned a permit a and AIRS ID] 4 Company equipment Identification: [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Site Name: Site Location: Mailing Address: (Include Zip Code) E -Mail Address2: REP Processing, LLC Pierce Gas Processing Plant 517930R 4500068N Zone 13T Sv c k- S ZI Tg 19-1e(i k/ 1611 N. Broadway Ave Oklahoma City, OK 73101 JFleak@KahunaVentures.com 1„, -dor pa aitucneQ email Site Location County: Weld NAICS or SIC Code: Permit Contact: James Fleak Phone Number: 720-889-9955 '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-202 - Glycol Dehydration Unit APEN - Revision 02/2017 384853 i I tzl� COLORADO r,. i; l;. Permit Number: AIRS ID Number: [Leave blank unless APCO has already assigned a permit it 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 O Add point to existing permit ❑ Change permit limit O Transfer of ownership' O Other (describe below) OR ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - O Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: Unit controlled with BTEX condenser with condenser routed to tank combustor (CO) For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: TEG Dehydration Unit Facility equipment Identification: D-1 For existing sources, operation began on: / / For new or reconstructed sources, the projected start-up date is: February 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 unit located at a stationary source that is considered a Major Source of (HAP) Emissions Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 7 O days/week Yes Yes 52 weeks/year No No COLORADO 2IAVI Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit :1 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: 0 Electric O Gas If Gas, injection pump ratio: Pump Make and Model: TBD Glycol Recirculation rate (gal/min): Max: 7 Lean Glycol Water Content: Wt.% Requested: MMBTU/hr ri ❑ - TEthylene Glycol (TEG) # of pumps: 7 Acfm/gpm 1 Dehydrator Gas Throughput: Design Capacity: 60 MMSCF/day Requested: 60 MMSCF/year Actual: MMSCF/year Inlet Gas: Pressure: Water Content: Wet Gas: Flash Tank: Pressure: Cold Separator: Pressure: 1014.7 40 psig Temperature: 60 lb/MMSCF 0 Saturated Dry gas: psig Temperature: 60 psig Temperature: Stripping Gas: (check one) El None ❑ Flash Gas O Dry Gas O Nitrogen Flow Rate: scfm `F 7.0 lb/MMSCF 'F ❑ NA 'F ❑ NA Additional Required Information: • Attach a Process Flow Diagram Q Attach GRI-GLYCaIc 4.0 Input Report a Aggregate Report (or equivalent simulation report/test results) El Attach the extended gas analysis (including BTEX ft n -Hexane, temperature, and pressure) Form APCD-202 Glycol Dehydration Unit APEN - Revision 02/2017 Cloa AC C"3 i b�cC" Permit Number: AIRS ID Number: [Leave blank unle4 APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UM) 517854E 4499984N Zone 13T Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. (`� Flow Rate (ACFM) " Velocity (ft(sec) CO 25 1,273 665 7.98 Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): El Upward ❑ Horizontal O Upward with obstructing raincap Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): 16 O Square/rectangle Interior stack width (inches): Interior stack depth (inches): O Other (describe): Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 17COLORADO 4 Lfw Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit l9 and AIRS IN Section 6 - Control Device Information Condenser: Used for control of: Type: Make/Model: • Maximum Temp Average Temp Requested Control Efficiency % VRU: Used for control of: Size: Make/Model: • Requested Control Efficiency % VRU Downtime or Bypassed % Combustion Device: Used for control of: VOC Rating: 1.00 MMBtu/hr Type: TBD Make/Model: TBD Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: 1,273° F 95 % 1,121.8 Btu/scf MMBtu/hr © % Waste Gas Heat Content No Pilot burner Rating 0.005 Constant Pilot Light: ■ Yes O Closed Loop System: Used for control of: Description: • System Downtime Other: Used for control of: Description: ■ Control Efficiency o� Requested Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 5 I Ay COIDR VDU Permit Number: AIRS ID Number: / / [I save til.'mk unit's APC:Ii ha : 1r-:3<Sy ass,irgiled 1 poi mit imd AIRS ID1 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? Q Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM S0x NO. CO V0C Tank Combustor (CO) 95 HAPs Other: From what year is the following reported actual annual emissions data? NA Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) - - - -_ _ _ - Actual Annual Emissions Requested Annual Permit 4 Emission Limit(s) Uncontrolled (Tons/year) Controlled5 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM NA NA NA NA NA S0x NA NA NA NA NA N0x NA NA NA NA NA CO NA NA NA NA NA VOC 24.9746 lb/hr Simulation 54.525 See Tank Combustor (CO) Benzene 2.6511 lb/hr Simulation 11.612 See Tank Combustor (CO) Toluene 2.4542 lb/hr Simulation 10.749 See Tank Combustor(co) Ethylbenzene 1.5938 lb/hr Simulation 6.981 See Tank Combustor(CO) Xylenes 2.7907 lb/hr Simulation 12.223 See Tank Combustor (CO) n -Hexane 0.9255 lb/hr Simulation 4.054 See Tank Combunlor(Co) 2,2,4 Trimethylpentaner(CO) 0.0028 lb/hr Simulation 0.012 Iambus; Other: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-202 Glycol Dehydration Unit. APEN - Revision 02/2017 6 '7 COLORADO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned ape unit /t 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 Auth ed Person (not a vendor or consultant) Date g g Y Kevin Bailey Chief Operating Officer Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance Q Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2J'l7 AV cianRoo 7 I P•i 7/17/2018 State.co.us Executive Branch Mail - Site Location for Pierce Gas Processing Plant STATE OF COL0 RADO Underriner - CDPHE, Katherine <katherine.underriner@state.co.us> Ili Site Location for Pierce Gas Processing Plant 2 messages Katherine Underriner - CDPHE <katherine.under-iner@state.co.us> Mon, Jul 16, 2018 at 12:30 PM To: jfleak@kahunaventures.com Hi James, While looking at the APENs further I noticed that the site location lists coordinates. These coordinates are listed as 417930E 4500068N Zone 13T which is not a format I have seen before. Based on Google Earth, it looks like this is located around 40.650871, -104.787540. Can you please send me the site location is Section, Township, Range format? Thanks, Katherine Underriner Application Completeness Technician Stationary Sources Program COLORADO Air Pollution Control Division Depa?tmern of Publtc Heafnh & Environment P 303.692.6381 I F 303.782.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 katherine.underriner@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. As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete APENs. Additional fees may apply if an APEN is submitted without the necessary information. An application with missing information may result in longer processing times. Please note that all APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section II.A). Current APEN forms can be found at: https://www.colorado.gov/cdphe/APENforms James Fleak <JFleak@kahunausa.com> Mon, Jul 16, 2018 at 2:56 PM To: Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Hi Katherine, The UTM coordinates were utilized by the consultant that was initially working with REP Processing and he used those values since he put together the dispersion model. The site is located in the SW/4 of 521 T8N R66W. Hope that helps. I received your message about the tanks to be listed individually. I will call to make sure I'm clear how that Form 102 should state the emissions. James James Fleak, P.E. 720-889-9955 Direct https://mail.goog le.com/mail/u/0?ik=e82d6de00d&view=pt&search=all&permthid=thread-a %3Ar5610759831789739182&simpl=msg-a%3Ar372031820... 1/2 Glycol Dehydration Unit APEN - Form APCD-202 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Glycol Dehydration (Dehy) Units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.cotorado.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: 1gtUe v 3.? AIRS ID Number: I'. 3 / f FDc3/ v ) f [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': REP Processing, LLC Site Name: Pierce Gas Processing Plant Site Location: 517930E 4500068N Zone 13T Mailing Address: (Include Zip Code) 1611 N. Broadway Ave Oklahoma City, OK 73101 E -Mail Address2: L.King@RimrockEnergy.com Site Location County: Weld NAICS or SIC Code: Permit Contact: Lance King Phone Number: 405-317-9587 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-202 - Glycol Dehydration Unit APEN - Revision 02/2017 COLORADO 1 I Ay! nln,r u< S3f vYlmnrmnf Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: Dehydrator Serial Number: Glycol Used: TBD TBD. ❑ Ethylene Glycol (EG) Model Number: TBD Reboiler Rating: 0.5 ❑ Di Ethylene Glycol (DEG) Glycol Pump Drive: 0 Electric O Gas If Gas, injection pump ratio: Pump Make and Model: TBD Glycol Recirculation rate (gal/min): Max: 7 Lean Glycol Water Content: Wt.% Requested: MMBTU/hr ❑ TriEthylene Glycol (TEG) # of pumps: 7 Acfm/gpm 1 Dehydrator Gas Throughput: Design Capacity: 60 MMSCF/day Requested: 60 MMSCF/year Actual: MMSCF/year Inlet Gas: Pressure: 1014.7 Water Content: Wet Gas: Flash Tank: Pressure: 40 Cold Separator: Pressure: Stripping Gas: (check one) 0 None O Flash Gas O Dry Gas O Nitrogen Flow Rate: scfm psig lb/MMSCF psig psig Temperature: 0 Saturated Dry gas: Temperature: Temperature: 60 60 °F 7.0 lb/MMSCF °F O NA °F O NA Additional Required Information: Attach a Process Flow Diagram Attach GRI-GLYCaIc 4.0 Input Report a Aggregate Report (or equivalent simulation report/test results) Attach the extended gas analysis (including BTEX a n -Hexane, temperature, and pressure) Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 COLORADO 3I A FWlm bEmexnmmf Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information ❑ Condenser: Used for control of: Regenerator Still Vent Type: TB D Maximum Temp Requested Control Efficiency Make/Model: TBD Average Temp 42 % ❑ VRU: Used for control of: Size: Make/Model: Requested Control Efficiency VRU Downtime or Bypassed ❑ Combustion Device: Used for control of: VQC Rating: 1.00 Type: TBD Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: 1,200° F MMBtu/hr Make/Model: TBD 95 98 Waste Gas Heat Content Constant Pilot Light: 0 Yes 0 No Pilot burner Rating 1,121.8 0.005 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 COLORADO Ay I• De,>.�nev,_ NY4n 6 Envlronmvpl 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. `%(72 21/z 7/4 Signature Kevin Bailey Chief Operating Officer Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance ID Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-202 -Glycol Dehydration Unit APEN - Revision 02/2017 71 • COLORADO ucpammmieeeh ac h 029201a 9 2018 Amine Sweetening Unit - Form APCD-206 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 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.cotorado.gov/cdphetapcd. 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: O►vG 0'11'I AIRS ID Number: 123 'Fp8' ®!2 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Site Name: Site Location: Mailing Address: (Include Zip Code) REP Processing, LLC Pierce Gas Processing Plant 517930E 4500068N Zone 13T SWI+S21'i' tsJfaU1W 1611 N. Broadway Ave Oklahoma City, OK 73101 E -Mail Address': JFleak@KahunaVentures.com lext 1 ti tit p.c.( q{taChed trriait Site Location County: Weld NAICS or SIC Code: 211130 Permit Contact: James Fleak Phone Number: 720-889-9955 '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. 384856 AVIV COLORADO Form APCD-206 Amine Sweetening. Unit APEN - Revision 04/2017 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit t! and AIRS ID] Section 2- Requested Action E 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 O Add point to existing permit ❑ Change permit limit O Transfer of ownership' O 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 (FIAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: Acid gas routed to thermal oxidizer (TO1) a 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: Removal of CO2 from natural gas Facility equipment Identification: For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: A-1 / / February 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 Does this facility have a design capacity less than 2 long tons/day of H2S in the acid gas? Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 7 El days/week 52 weeks/year Yes ❑ No Yes 0 No COLORADO 2j A�.-..,e:., Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit ,N and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: TBD Model: TBD Reboiler Rating: 63 Amine Type: ❑ MEA Serial Number: MMBtu/hr Absorber Column Stages: TBD Pump Make and Model: TBD El DEA ❑ TEA TBD stages MDEA ❑ DGA # of pumps: 3 Sweet Gas Throughput': Design Capacity: 200 MMSCF/day Requested: 73,000 MMSCF/year Actual: MMSCF/year ' Requested values will become permit limitations. Requested limft(s) should consider future process growth Inlet Gas: Pressure: 1,000 psig Temperature: 75 Rich Amine Feed: Pressure: 1,007.2 Asia Flowrate: 800 Gal/min Temperature: 127 'F Lean Amine Stream: Pressure: 1,012.2 Asia Temperature: 121 Flowrate: 800 Gal/min Wt. % amine: 50 Mole Loading COz Mole loading H2S 1.2 X 10-5 0.008 °F Sour Gas Input: Pressure: 1,012.2 Asia Flowrate: 5 MMSCF/Day Temperature: 75 "F NGL Input: Pressure: Flowrate: psia Gal/min Temperature: `F Flash Tank: O No Flash Tank Pressure: 62.2 psia Temperature: 130 .F Additional Required Information: El Attach a Process Flow Diagram Q Attach the simulation model inputs a emission report ❑ Attach composition reports for the rich amine feed, sour gas feed, NGL feed, a outlet stream (emissions) ❑ Attach the extended gas analysis (including BTEX ft n -Hexane, HzS, CO2, temperature, and pressure) Form APCD-206 Amine Sweetening Unit APEN - Revision 04/2017 Al COLORADO 3� AV I; Permit Number: AIRS ID Number: / / [Leave blank urdess APCD has already assigned a permit H and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTh) 517980E 4500160N Zone 13T Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. (`F7 Flow Rate- . fACro. Velocity (frlsec) TO1 20.77 1,700 30,310.19 169.15 Indicate the direction of the stack outlet: (check one) 0 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): 23 O Square/rectangle Interior stack width (inches): Interior stack depth (inches): O Other (describe): Form APCD-206 Amine Sweetening Unit APEN - Revision 04/2017 '�w� cOIOAROO 4 L�$w.G- C./ Permit Number: AIRS II) Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information 0 VRU: Used for control of: Size: Make/Model: Requested Control Efficiency % VRU Downtime or Bypassed l=" Combustion Device: Used for control of: VOC Rating: 7 Type: TBD Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: 1,700 MMBtu/hr Make/Model: TBD 98 % TBD Waste Gas Heat Content 8.6 Btu/scf Constant Pilot Light: 0 Yes ❑ No Pilot burner Rating TBD MMBtu/hr 0 Other: Used for control of: Description: Control Efficiency Requested Form APCD-206 Amine Sweetening Unit APEN - Revision 04/2017 5 1 ' l7 co�arsaoo W�ui�nvn�VW l �u. Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit if and AIRS ID] Section 7 -Emissions Inventory 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, please describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (96 reduction In emissions) PM SOx H25 NOx VOC Combustion Device 98 CO HAPs Other: From what year is the following reported actual annual emissions data? NA 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.) Criteria Pollutant Emissions Inventory Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled (Tons/year) Controlleds (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM 7.60 lb/mmBtu AP -42 NA 0.228 SOx NA lb/mmBtu Simulation NA 6.588 HzS NA Ib/mmBtu Simulation 3.777 0.076 NOx 0.068 lb/mmBtu AP -42 NA 6.547 VOC 11.14 Ib/mmBtu Simulation 81.983 1.642 CO 0.31 lb/mmBtu AP -42 NA 5.488 a Requested values will becomepermit Limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. COLORADO Form APCD-206 - Amine Sweetening Unit APEN - Revision 04/2017 6 121.v Permit Number: AIRS ID Number: / / 1.1 btank unless APCD has aIr dy assigned a permit.:- and AIRS 'laJ Section 7 (continued) Non -Criteria Reportable Pollutant Emissions Inventory Pollutant Chemical Abstract Service (CAS) Number Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Uncontrolled (lbs year) Controlled5 (lbs/year) Benzene 71432 Eng Estimate lb/mmscf Simulation Toluene 108883 Eng Estimate lb/mmscf Simulation Ethylbenzene 100414 Eng Estimate lb/mmscf Simulation Xylenes 1330207 Eng Estimate lb/mmscf Simulation n -Hexane 110543 Eng Estimate lb/mmscf Simulation 2,2,4-540841 Trimethylpylpentane NA Other: 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 contained herein and information submitted with this application is complete, true and correct. Date Signature of Legally AutL+6rized Person (not a vendor or consultant) Kevin Bailey Chief Operating Officer Name (please print) Title Check the appropriate box to request a copy of the: Draft permit prior to issuance EJ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-206 Amine Sweetening, Unit APEN - Revision 04/2017 7 I AVcoiortaoo c .�z,,.4,t. 7/17/2018 State.co.us Executive Branch Mail - Site Location for Pierce Gas Processing Plant STATE OF COLORADO Underriner - CDPHE, Katherine <katherine.underriner@state.co.us> Site Location for Pierce Gas Processing Plant 2 messages Katherine Underriner - CDPHE <katherine.underriner@state.co.us> To: jfleak@kahunaventures.com Hi James, Mon, Jul 16, 2018 at 12:30 PM While looking at the APENs further I noticed that the site location lists coordinates. These coordinates are listed as 417930E 4500068N Zone 13T which is not a format I have seen before. Based on Google Earth, it looks like this is located around 40.650871, -104.787540. Can you please send me the site location is Section, Township, Range format? Thanks, Katherine Underriner Application Completeness Technician Stationary Sources Program COLORADO Air Pollution Control Division Department of Public Health &Environment P 303.692.6381 I F 303.782.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 katherine.underriner@state.co.us I www.colorado.gov/cdphe/aped Are you curious about ground -level ozone in Colorado? Visit our ozone webpage to learn more. As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete APENs. Additional fees may apply if an APEN is submitted without the necessary information. An application with missing information may result in longer processing times. Please note that all APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section II.A). Current APEN forms can be found at: https://www.colorado.gov/cdphe/APENforms James Fleak <JFleak@kahunausa.com> Mon, Jul 16, 2018 at 2:56 PM To: Katherine Underriner- CDPHE <katherine.underriner@state.co.us> Hi Katherine, The UTM coordinates were utilized by the consultant that was initially working with REP Processing and he used those values since he put together the dispersion model. The site is located in the SW/4 of 521 TSN R66W. Hope that helps. I received your message about the tanks to be listed individually. I will call to make sure I'm clear how that Form 102 should state the emissions. James James Fleak, P.E. 720-889-9955 Direct https://mail.google.com/mail/u/0?ik=e82d6de00d&view=pt&search=all&permthid=thread-a%3Ar5610759831789739182&simpl=msg-a%3Ar372031820... 1/2 AUG Amine Sweetening Unit - Form APCD-206 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 amine sweetening units only. If your emission unit does not fall into this category, there may be a more specific APEN available for your source (e.g. glycol dehydration unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: t�wG v 7-- AIRS ID Number: t/ q r:63/ c)) [Leave blank unless APCD has already assigned a permit rr and AIRS ID] Section 1 - Administrative Information Company Name': REP Processing, LLC Site Name: Pierce Gas Processing Plant Site Location: 517930E 4500068N Zone 13T Mailing Address: (include Zip Code) 1611 N. Broadway Ave Oklahoma City, OK 73101 Site Location County: Weld NAICS or SIC Code: 211130 Contact Person: ' Lance King Phone Number: 405-317-9587 E -Mail Address2: L.King@RimrockEnergy.com i 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 the APCD via e-mail to the address provided. ................ Form APCD-206 - Amine Sweetening Unit APEN - Revision 7/2018 ��jj-_ COLORADO 11A_ Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned -a permit # and AIRS ID] Section 4 - Amine Unit Equipment Information Manufacturer: TBD Absorber Column Stages: TBD Model No.: TBD Serial Number: TBD Amine Type: ❑ MEA Pump Make and Model: TB D stages D DEA O TEA MDEA ❑ DGA # of pumps: 3 Sour Gas Throughput: Design Capacity: 200 MMSCF/day Requested5: 73,000 MMSCF/year Actual: MMSCF/year Sour Gas: Pressure: 1,000 psig Temperature: 75 °F Lean Amine Stream: Pressure: 1012 psia Flowrate: 800 gal/min Mole loading H2S: 1.2XE-5 Temperature: 121 °F Wt. % amine: 50 Mole Loading 0.008 CO2: NGL Input: Pressure: Flowrate: psia Gal/min Temperature: °F Flash Tank: O No Flash Tank Pressure: 62 psia Temperature: 130 °F Additional Required Information: Attach a Process Flow Diagram ❑✓ Attach the simulation model inputs Ft emissions report ❑ Attach composition reports for the rich amine feed, sour gas feed, NGL feed, Et outlet stream (emissions) ❑ Attach the extended gas analysis (including BTEX a n -Hexane, H2S, CO2, temperature, and pressure) 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-206 - Amine Sweetening Unit APEN - Revision 7/2018 3 I COLDRADD Cgaxee.uel P.bti° Permit Number: AIRS ID Number: Benzene 71432 4.447 lb/hr Promax PM [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): verall Requested ontrol Efficient fut�'i`►on m:em►ss►oris, SOX HZS NOx CO VOC Thermal Oxidizer (T01) 98 HAPs Other: From what year is the following reported actual annual emissions data? NA ena Pollutant EmissionsInvento PM 7.6 lb/mmBtu AP -42 nested "Annual Perini mission Limit(s)5 Jncontrolled Emi'ss�ans 04 14.04 : 0.29 0.29 SOx 1.504 lb/hr Promax 6.59 6.59 H2S 0.85 lb/hr Promax 3.78 0.08 NOx 1.495 lb/hr Promax 6.55 6.55 CO 18.74 lb/hr Promax 81.98 1.64 VOC 0.31 lb/hr Promax 5.49 5.49 on-Cnteria Reportable Pollutant Emissions Inventor mission,Fac nual Emission Toluene 108883 2.740 lb/hr Promax Ethylbenzene 100414 0.792 lb/hr Promax Xylene 1330207 1.420 lb/hr Promax n -Hexane 110543 0.048 lb/hr Promax 2,2,4- Trimethylpentane 540841 0.000 lb/hr Promax Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-206 - Amine Sweetening Unit APEN - Revision 7/2018 5 'COLORADO xatmP QT*. Enwironniosu safe,fCe iQi1 /- irit-.v rw--- --' /-l' -- twv - 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/aocd. 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: 1g tr v 6 0111 AIRS ID Number: 12.3 "1 DB/ O I3 (Leave blank unless APCD has already assigned a permit It and AIRS ID] Company equipment Identification: (Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Site Name: Site Location: REP Processing, LLC Pierce Gas Processing Plant Site Location 517930R 4500068N Zone 13T County: Weld Mailing Address: (Include Zip Code) 1611 N. Broadway Ave Oklahoma City, OK 73101 E -Mail Address2: JFleak@KahunaVentures.com NAICS or SIC Code: 211130 Permit Contact: James Fleak Phone Number: 720-889-9955 '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 email to the address provided. Form APCD-208 Hydrocarbon Liquid Loading APEN - Rev 02/2017 384858 COLORADO t- Permit Number: AIRS ID Number: [I eave blank unless APCD has already assigned a permit N and AIRS ID] Section 2- Requested Action • NEW permit OR newly -reported emission source Request coverage under construction permit 0 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 ❑ Transfer of ownership' 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 a Notes: Captured loading losses plus storage tank emissions routed to tank combustor (CO) 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 loading of stabilized condensate and produced water For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: / / February 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? ❑ Yes 0 No ❑ Yes 0 No ❑ Yes El No ❑ Yes 0 No ❑ Yes ❑ No ❑ Yes ❑ No ❑ Yes 0 No Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 2 I Permit Number: AIRS ID Number: [I. cave blank unless APCD has already assigned a permit A and AIRS ID] Section 4 - Process Equipment Information Product Loaded: (] Condensate ❑ Crude Oil ❑ 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 389,975 Bbl/yr Bbl/yr Actual Volume Loaded: This product is loaded from tanks at this facility into: Tank Trucks (eg, "rail tank cars" or `tank trucks") If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: 0.6 Average temperature of bulk liquid loading: 70 F True Vapor Pressure V 9 , 06 Psia ® 60 "F Molecular weight of displaced vapors A 1 Q `�F CJ Lb/lb-mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Bbl/yr Actual Volume Loaded5: 388.429 Loaded: 4 Requested values will become permit limitations. Requested limits) should consider future process growth Bbl/yr 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 3 I AV coLoR4eo Permit Number: AIRS ID Number: [leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Geographical Information Geographical Coordinates (Latitude/Longltude or UT84) 517854E 4499984N Zone 13T Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. CO Flow Rate (ACM) Velocity (ft/sec) CO 25 1,273 665 7.98 Indicate the direction of the stack outlet: (check one) ❑ Downward D Other (describe): 0 Upward ❑ Horizontal Indicate the stack opening and size: (check one) [J Circular Interior stack diameter (inches): ❑ Other (describe): O Upward with obstructing raincap 16 Section 6 - Control Device Information ❑ Loading occurs using a vapor balance system: Requested Control Efficiency ❑ Combustion E Device: Pollutants Controlled: VOC Rating: 1 MMBtu/hr Type: TBD Make/Model: TBD Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency Minimum Temperature: Waste Gas Heat Content Constant Pilot Light: ❑ Yes O No Pilot burner Rating Btu/scf MMBtu/ hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 4 I L�El' ,co�oasoo ,�....,._ _ ., Permit Number: AIRS ID Number: I / (Leave blank unless APCD has ,;(ready assn ned a per rnil. # and AIRS IDl 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 eauipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (96 reduction in emissions) PM SOx NOx CO VOC Tank Combustor (CO) 95 HAPs Other: ❑ Using State Emission Factors (Required for GP07) VOC ❑ Condensate O Crude 0.236 Lbs/BBL 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? NA 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) _ Actual Annual Emissions —_-- Requested Annual Permit s ; Emission Limit(s) Uncontrolled (Tons/year) Controlled5 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM 7.6000 lb/mmscf AP -42 NA NA SO,, NA lb/mmBtu AP -42 NA NA NO„ 100.0 lb/mmBtu AP -42 NA NA VOC 5.5 lb/mmBtu Eng Estimate 75.710 18.927 CO 84.0 lb/mmBtu AP -42 NA NA Benzene 203.506 lb/hr Eng Estimate 891.355 See Tank Combustor (CO) Toluene 68.524 lb/hr Eng Estimate 300.136 Combustor(CO) Ethylbenzene 3.595 lb/hr Eng Estimate 15.748 See Tank Combustor (CO) Xylenes 110.589 Ib/hr Eng Estimate 484.377 Combusi r (CO) n -Hexane 6796.468 lb/hr Eng Estimate 29,768.463 Co mTbasr r (CO) 2,2,4- Trimethylpentane 36.429 lb/hr En Estimate Eng 159.557 SeeTank Combustor (CO) 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. n Fofn) APCD-208-Hydiocalbon Liquid Loading APEN - Rev 0212017 5 I iCOLD RADD s ,., , Permit Number: AIRS ID Number: / / [leave blank unlesr, APCD has already assigned a permit grand MRS 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 with each condition of the applicable General Permit. IC`s-i, 73 ‘/2-7/1, • Signature of Legally horized Person (not a vendor or consultant) Date Kevin Bailey Chief Operating Officer Name (print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance Q Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $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 02/201? 6 AV 7/17/2018 State.co.us Executive Branch Mail - Site Location for Pierce Gas Processing Plant STATE O F COLORADO Underriner - CDPHE, Katherine <katherine.underriner@state.co.us> Site Location for Pierce Gas Processing Plant 2 messages Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Mon, Jul 16, 2018 at 12:30 PM To: jfleak@kahunaventures.com Hi James, While looking at the APENs further I noticed that the site location lists coordinates. These coordinates are listed as 417930E 4500068N Zone 13T which is not a format I have seen before. Based on Google Earth, it looks like this is located around 40.650871, -104.787540. Can you please send me the site location is Section, Township, Range format? Thanks, Katherine Underriner Application Completeness Technician Stationary Sources Program COLORADO Air Pollution Control Division Departmert of Public Health &Environment P 303.692.6381 I F 303.782.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 katherine.underriner@state.co.us I www.colorado.gov/cdphe/aped Are you curious about ground -level ozone in Colorado? Visit our ozone webpage to learn more. As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete APENs. Additional fees may apply if an APEN is submitted without the necessary information. An application with missing information may result in longer processing times. Please note that all APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section II.A). Current APEN forms can be found at: https://www.colorado.gov/cdphe/APENforms James Fleak <JFleak@kahunausa.com> Mon, Jul 16, 2018 at 2:56 PM To: Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Hi Katherine, The UTM coordinates were utilized by the consultant that was initially working with REP Processing and he used those values since he put together the dispersion model. The site is located in the SW/4 of S21 T8N R66W. Hope that helps. I received your message about the tanks to be listed individually. I will call to make sure I'm clear how that Form 102 should state the emissions. James James Fleak, P.E. 720-889-9955 Direct https://mail.google.com/mail/u/0?ik=e82d6de00d&view=pt&search=all&permthid=thread-a%3Ar5610759831789739182&simpl=msg-a%3Ar372031820... 1/2 RECEWED AUG 302018 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 (e.g. amine sweetening unit, glycol dehydration unit, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/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: 1''W E 0777 AIRS ID Number: I a3 /gfD.3 / o 13 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': REP Processing, LLC Site Name: Pierce Gas Processing Plant Site Location: 517930E 4500068N Zone 13T Mailing Address: (Include Zip Code) 1611 N. Broadway Ave Oklahoma City, OK 73101 Site Location County: Weld NAICS or SIC Code: 211130 Contact Person: Lance King Phone Number: 405-317-9587 E -Mail Address2: L.King@RimrockEnergy.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 COLORADO oig.,eemta1 t.mt HtW1469nvgnanmat 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 0 Crude Oil ❑ Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded5: 389975 bbl/year This product is loaded from tanks at this facility into: (e.g. "rail tank cars" or "tank trucks") Actual Volume Loaded: bbl/year If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor:Average 0.6 temperature of bulk liquid loading: 7� F True Vapor Pressure: 9 . �6 Psia ® 60 °F Molecular weight of displaced vapors: `t V Z ^ .678 lb/lb mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: bbl/year Actual Volume Loaded: bbl/year Product Density: lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume: ft3/truckload 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-208 - Hydrocarbon Liquid Loading APEN Revision 7/2018 3I COLORADO G:pvbnmrt dPiMec Ma%6 F]fW.nm..M Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach alt emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): PM SO. NO. CO VOC Enclosed Flare - (CO) 95 HAPs Enclosed Flare - (CO) 95 Other: ❑ Using State Emission Factors (Required for GP07) ❑ Condensate ❑ Crude VOC Benzene n -Hexane 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL 0.104 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? NA rite aPollutant Emissions Invento ontrolled missionsf ors/year) PM 7.6 Ib/mmsef AP -42 1.4 75.709 21.767 ontrolled mss ons tonsfyear)' SOX NA NO. 0.068 lb/mmBtu AP -42 13.5 CO 0.31 lb/mmBtu AP -42 13.5 VOC 17.285 lb/hr Eng./AP-42 5.2 on= Benzene 71432 0.102 lb/hr Eng./AP-42 5.2 nteria.Reportable PollutantzEmissions Invento Emission F( mission Toluene 108883 0.034 lb/hr Eng./AP-42 5.2 Ethylbenzene 100414 0.002 lb/hr EngJAP-42 5.2 Xylene 1330207 D.055 lb/hr EngJAP-42 5.2 n -Hexane 110543 3.398 lb/hr Eng./AP-42 5.2 2,2,4- Trimethylpentane 540841 0.018 lb/hr EngJAP-42 5.2 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. if source has not yet started operating, leave blank. Form APCD-208.- Hydrocarbon Liquid Loading APEN - Revision 7/2018 5I COLORADO D.,.e.,ld Public XW%b Braleanmert 171" 4-•`" rrrrrv4n.r.A...... .. ,, �,• • mac, 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/cdohe/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: 02920 gWE AIRS ID Number: 113 /M FDB /0(4- [leave blank unless APCD has already assigned a permit H and AIRS ID] Company equipment Identification: [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Site Name: Site Location: Mailing Address: (include Zip Code) E -Mail Address2: REP Processing, LLC Pierce Gas Processing Plant Site Location 517930E 4500068N Zone 13T County: Weld p" otwochLO email SVti11� S 2 k T1N P. U(Q W 1611 N. Broadway Ave Oklahoma City, OK 73101 JFleak@KahunaVentures.com NAICS or SIC Code: 211130 Permit Contact:, James Fleak Phone Number: 720-889-9955 '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-205 Natural Gas Venting APEN - Rev 03/2017 384859 ,qW COLORA00 Permit Number: AIRS ID Number: I / [Leave blank unless APCD has already assigned a permit /! and AIRS ID] Section 2- Requested Action O NEW permit OR newly -reported emission source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name O Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' O Other (describe below) - OR • APEN submittal for update only Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info a Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: MSS -1 - Maintenance, Startup and Shutdown For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: / / February 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: 24 hours/day 7 days/week 52 weeks/year Will this equipment be operated in any NAAQS nonattainment 0 Yes O No area Is this equipment located at a stationary source that is ❑ Yes 2 No considered a Major Source of (HAP) Emissions Form APCD-205 Natural Gas Venting APEN • Rev 03/2017 2 I L Y uu.rw./i A O O .rtmss Permit Number: AIRS ID Number: [Leave blank ur.less APCD has already assigned a permit M and AIRS ID] Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ❑ Blowdown Events # of Events/year: ❑ Other Description: Serial #: # of Pistons: Volume per event: Capacity: Leak Rate: 0.3 Gal/min Scf/hr/pist 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 Parameters'°: Liquid Throughput Process Parameters4: No Maximum Vent Rate: SCF/hr Vent Gas Heating Value: 1 600 ' BTU/SCF Requested: 0.3 MMSCF/year Actual: MMSCF/year Requested: Bbl/yr Actual: Bbt/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Process Properties: Molecular Weight: 22.9 VOC (mole %) 12.164 VOC (Weight %) 26.548 Benzene (mote %) 0.005 Benzene (Weight %) 0.018 Toluene (mole %) 0.003 Toluene (Weight %) 0.013 Ethylbenzene (mole %) 0.001 Ethylbenzene (Weight %) 0.006 Xylene (mole %) 0.001 Xylene (Weight %) 0.008 n -Hexane (mole %) 0.122 n -Hexane (Weight %) 0.458 2,2,4-Trimethylpentane (mole %) 2,2,4-Trimethylpentane 0.001 (Weight %) 0.004 Additional Required Information: El Attach a representative gas analysis (including BTEX ft n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) El Form APCD-205 Natural Gas Venting APEN Rev 03/2017 � ca�oaAoo 3I 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) 517854E 4499984N Zone 13T Operator. Stack ID No. Discharge Height Above Ground Level (Feet) Temp. ('F) Flow Rate G►c o r. Velocity (ftf ) Indicate the direction of the stack outlet: (check one) ❑ Upward O Horizontal O Downward O Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑Other (describe): ❑ Upward with obstructing raincap Section 6 - Control Device Information ❑ VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency VRI.1 Downtime or Bypassed ❑ Combustion Device: Pollutants Controlled: Rating: MMBtu/hr Type: Make/Model: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: Waste Gas Heat Content Constant Pilot Light: O Yes O No Pilot burner Rating Btu/scf MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested Form APCD-205 Natural Gas Venting APEN • Rev 03/2017 41 07 COLORADO 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? ❑ Yes E] No If lease describe the control equipment AND state the overall control efficiency (% reduction): yes, p Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction In emissions) PM SO. NO. VOC CO HAPs Other: From what year is the following reported actual annual emissions data? NA Use the following table to report the criteria pollutant emissions from source: ✓- - -- r Pollutant Uncontrolled Emission Factor. Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions > '''...=.-_ Requested Annual Permit Emission ilmit, s s . -- ' T ) ,_- Uncontrolled (Tons/year) Controlled6 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM NA NA NA NA NA SOx NA NA NA NA NA NOx NA NA NA NA NA VOC 0.541553 lb/hr Simulation 2.372 2.372 CO NA NA NA NA NA Benzene 0.19758 lb/hr Simulation 0.8654 0.8654 Toluene 0.52089 lb/hr Simulation 2.2815 2.2815 Ethylbenzene 0.068311 lb/hr Simulation 0.2992 0.2992 Xylenes 0.086416 lb/hr Simulation 0.3785 0.3785 n -Hexane 2.48137 lb/hr Simulation 10.8684 10.8684 2,2,4- Trimethylpentane 0.046804 lb/hr Simulation 0.205 0.205 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. COLORADO - Farm APCD-205 Naturat Gas Venting APEN Rev 03/Z017 Permit Number: AIRS ID Number: / / [Leave blank unless APCD his already assigned a permit 5 and MRS MI Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. R Signature of Legally Authorized Person (not a vendor or consultant) Date Kevin Bailey Chief Operating Officer Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance B 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-205 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 Vr-o�o>tav 7 7/17/2018 State.co.us Executive Branch Mail - Site Location for Pierce Gas Processing Plant STATE OF COLORADO Underriner - CDPHE, Katherine <katherine.underriner@state.co.us> Site Location for Pierce Gas Processing Plant 2 messages Katherine Underriner - CDPHE <katherine.underriner@state.co.us> To: jfleak@kahunaventures.com Mon, Jul 16, 2018 at 12:30 PM Hi James, While looking at the APENs further I noticed that the site location lists coordinates. These coordinates are listed as 417930E 4500068N Zone 13T which is not a format I have seen before. Based on Google Earth, it looks like this is located around 40.650871, -104.787540. Can you please send me the site location is Section, Township, Range format? Thanks, Katherine Underriner Application Completeness Technician Stationary Sources Program COLORADO Air Pollution Control Division Department of publ,[ Heats, & E^.vvonrnent P 303.692.6381 I F 303.782.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 katherine.underriner@state.co.us I www.colorado.gov/cdphe/aped Are you curious about ground -level ozone in Colorado? Visit our ozone webpage to learn more. As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete,APENs. Additional fees may apply if an APEN is submitted without the necessary information. An application with missing information may result in longer processing times. Please note that all APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section II.A). Current APEN forms can be found at: https://www.colorado,gov/cdphe/APENforms James Fleak <JFleak@kahunausa.com> To: Katherine Underriner- CDPHE <katherine.underriner@state.co.us> Hi Katherine, Mon, Jul 16, 2018 at 2:56 PM The UTM coordinates were utilized by the consultant that was initially working with REP Processing and he used those values since he put together the dispersion model. The site is located in the SW/4 of 521 T8N R66W. Hope that helps. I received your message about the tanks to be listed individually. I will call to make sure I'm clear how that Form 102 should state the emissions. James James Fleak, P.E. 720-889-9955 Direct https://mail.google.com/mail/u/0?ik=e82d6de00d&view=pt&search=all&permthid=thread-a%3Ar5610759831789739182&simpl=msg-a%3Ar372031820... 1/2 Ai1G3c 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 gas venting only. Gas venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: CU -71-1 AIRS ID Number: (a. 3 / PTO 01(-1, [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': REP Processing, LLC Site Name: Pierce Gas Processing Plant Site Location: 517930E 4500068N Zone 13T Mailing Address: 1611 N. Broadway Ave (Include Zip Code) Site Location County: Weld NAICS or SIC Code: 211130 Oklahoma City, OK 73101 Contact Person: Lance King Phone Number: 405-317-9587 E -Mail Address2: L.King@RimrockEnergy.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-211 - Gas Venting APEN - Revision 7/2018 COLORADO Deparbaml el Public mam,. , rmmmru 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: ▪ Blowdown Events # of Events/year: ❑ Other Description: Serial #: Capacity: gal/min Model: # of Pistons: Leak Rate: Scf/hr/pist 24 Volume per event: 0.0139 MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? Gas Venting - Process Parameters5: Liquid Throughput Process Parameterss: Vented Gas Properties: O Yes ❑✓ No Vent Gas Heating Value: 1483 BTU/SCF Requested: 0.333 MMSCF/year Actual: MMSCF/year -OR- Requested: bbl/year Actual: bbl/year Molecular Weight: 29.18 VOC (Weight %) 45.401 Benzene (Weight %) 0.013 Toluene (Weight %) 0.004, Ethylbenzene (Weight %) 0.0003 Xylene (Weight %) 0.001 n -Hexane (Weight %) 0.367 2,2,4-Trimethylpentane (Weight %) 0.0002 Additional Required Information: ❑✓ Attach a representative gas analysis (including BTEX Et n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-211 - Gas Venting APEN - Revision 7/2018 3 cOLORADO pas.. um H.bie H f UM& g1YiMnnant Benzene 71432 1.465 lbs/event Eng. Est. PM NA NA NA NA NA PM Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): ontrol Meth_o SOX NO. CO VOC HAPs Other: From what year is the following reported actual annual emissions data? riteriaPollutant Emissions:'Invento mission SOX NA NA NA NA NA NO. NA NA NA NA NA CO NA NA NA NA NA VOC 2.6 tons/event Eng. Est. 62.4 3.12 nteria: Reportable, Pollutant Emissions lnvento mission Fac ua rnua1 mission Toluene 108883 0.425 lbs/event Eng. Est. Ethylbenzene 100414 0.034 lbs/event Eng. Est. Xylene 1330207 0.073 lbs/event Eng. Est. n -Hexane 110543 41.964 lbs/event Eng. Est. 2,2,4- Trimethylpentane 540841 0.019 lbs/event Eng. Est. Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 - Gas Venting APEN - Revision 7/2018 51 COLORADO bqpuraurne PtabEc 2 Hale.. eerronm , Overhead Compressor Blowdowns P1 (PSIA) V1 (ft^3) T2 (°R) P2 (PSIA) T1 (°R) Slowdown Volume (ft^3) Blowdown Density (Ibs/ft^3) VOC Density (lbs/ftA3) 162.2 935 579.67 12.2 VOC Mass (Ibs) / Content Tons of Uncontrolled Controlled Event (Ibs) / VOC / Tons / Year (24 Tons /Year 519.67 Event Event Events) (24 Events) 13866.15 11445.31025 5196.2773 2.598139 62.35532794 3.117766397 0.825414 VOC Volume - (ft^3) 1.533533 3388.434527 Mass VOC Fraction Composition (%) VOC Mass Propane 31.004485 3548.56 i-Butane 3.36E+00 384.1263 n -Butane 8.26E+00 945.3102 i-Pentane 1.15E+00 131.6231 n -Pentane 1.15E+00 131.3445 Cyclopentane 3.67E-02 4.195758 Hexane 0.3666514 41.96439 Cyclohexene 0.0145804 1.668776 Heptane 0.0333916 3.821768 Methylcyclohe) 0.006787 0.776796 2,2,4-Trimethyl 0.0001647 0.018854 Benzene 0.0127997 1.464968 Toluene 0.0037144 0.42512 Ethylbenzene 0.000295 0.033761 o-Xylene 8.49E-05 0.009719 m-Xylene 9.56E-05 0.010939 p-Xylene 0.0004598 0.052626 Octane 0.0068338 0.782154 Nonane 0.00039 0.044638 Decane 3.79E-04 0.043349 Total VOC 45.40093 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit N and AIRS ID] Section 2 - Requested Action ❑✓ NEW permit OR newly -reported emission source -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 0 Add point to existing permit O Change permit limit ❑ Transfer of ownership' 0 Other (describe below) OR ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: MSS -1 Maintenance, Startup & Shutdown Overhead Compressor Blowdown Company equipment Identification No. (optional): For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: Feb. 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: 24 hours/day 7 days/week 52 Will this equipment be operated in any NAAQS nonattainment area? Is this equipment located at astationary source that is considered a Major Source of (HAP) Emissions? Is this equipment subject to Colorado Regulation No. 7, Section XVII.G? Form APCD-211 - Gas Venting APEN - Revision 7/2018 Yes Yes Yes weeks/year ❑ No O No ❑ No Z i EV COLORADO C --,,men: el ... EAIli.'en+rl Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing O Pneumatic Pump Make: Model: Compressor Rod Packing Make: Blowdown Events # of Events/year: ❑ Other Description: Serial #: Capacity: gal/min Model: # of Pistons: Leak Rate: Scf/hr/pist 24 Volume per event: 0.0139 MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? Gas Venting Process Parameterss: Liquid Throughput Process Parameters5: Vented Gas Properties: ❑ Yes El No Vent Gas Heating Value: 148 BTU/SCF Requested: 0.333 MMSCF/year Actual: MMSCF/year -OR- Requested: bbl/year Actual: bbl/year Molecular Weight: 2L g . 7 ?) VOC (Weight %) 4,5.4O-1 25,5,77_ Benzene (Weight %) O.O-1-3 0.00(0 Toluene (Weight %) 0,,994 o,00i- Ethylbenzene (Weight %) 3D.000 Xylene (Weight %) (Wei O ,dam n -Hexane (Weight %) 0.2457 0, i 0 2,2,4-Trimethylpentane (Weight %) 0,0025 Additional Required Information: O Attach a representative gas analysis (including BTEX Et n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Ft n -Hexane, temperature, and pressure) s Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-211 - Gas Venting APEN - Revision 7/2018 3 I AMr COLORADO V =,==„ Permit Number: AIRS ID Number: Benzene PM [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): escnpti on of Control Method(s) Overall; Requested • Control Efficiency . , reduction in emissions) so. NO. CO VOC HAPs Other: From what year is the following reported actual annual emissions data? Pollutant Criteria Pollutant Emissions Inventory Emission Factor Actual Annual Emissions' Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (AP -42, Mfg,, etc.) • Uncontrolled Emissions (tons/year) Controlled Emissions6 (tons/year) Uncontrolled. Emissions (toot/year) Controlled Emissions (tons//year)_ PM NA NA NA NA NA SOX NA NA NA NA NA NO. NA NA NA NA NA CO NA NA NA NA NA VOC tons/event Eng. Est. 3-42 !. 34: S ion Critena Reortabie Pollutant Emissions inventory Chemical `. Abstract Service (CAS) Number 71432 Emission Factor Actual Annual.Emiss-ions Uncontrolled Bask Units JA6S-Og 01Ibs/event Source: (AP -42,_ Eng. Est. Uncontrolled Emissions , (pounds/year, Controlled Emissions6 ,(Pound`s/year) Toluene 108883 , )1fplbs/event Eng. Est. Ethylbenzene Xylene n -Hexane 2,2,4- Trimethylpentane Other: 100414 1330207 110543 540841 9,03'40, oplbs/event g o-? 040 lbs/event v.:•9641/4291s/event cum-Ibs/event Eng. Est. Eng. Est. Eng. Est. Eng. Est. 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 - Gas Venting APEN - Revision 7/2018 COLORADO 5 Iar .d NeLN i EnNmnTm� Overhead Compressor Blowdowns P1 (PSIA) V1 (ft^3) T2 (°R) P2 (PSIA) T1 (°R) Blowdown Volume (ft^3) Blowdown Density (Ibs/ft^3) VOC Density (lbs/ftA3) 162.2 935 579.67 12.2 VOC Mass (Ibs) / Content Tons of Uncontrolled Controlled Event (Ibs) / VOC / Tons / Year (24 Tons / Year 519.67 Event Event Events) (24 Events) 13866.15 11238.48404 2874.5226 1.437261 34.49427149 1.724713574 0.810498 VOC Volume (ftA3) 1.533533 1874.444163 ProMax Stream 18 on Tab LP Inlet Mass VOC Fraction Composition (%) VOC Mass Propane 18.581373 2088.265 i-Butane 1.7342049 194.8983 n -Butane 4.120419 463.0726 i-Pentane 0.4835085 54.33902 n -Pentane 0.487186 54.75232 Cyclopentane 0.036574 4.110367 Hexane 0.1000895 11.24854 Cyclohexene 0.0081523 0.9162 Heptane 0.0126328 1.419734 Methylcyclohe; 0.0029608 0.332745 2,2,4-Trimethyl 0.0007684 0.086359 Benzene 0.0061338 0.689351 Toluene 0.0015671 0.17612 Ethylbenzene 6.593E-05 0.00741 o-Xylene 2.638E-05 0.002965 m-Xylene 3.103E-05 0.003487 p-Xylene 0.0001516 0.017036 Octane 0.0012482 0.140278 Nonane 0.0003349 0.037634 Decane 6.587E-05 0.007403 Total VOC 25.577494 Boiler APEN -- Form APCD-220 Air Pollutant Emission Notice (APEN) and Application for Construction Permit ',��292019 AU sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. 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.ov/pacificicdphe/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: 3VE Ave111 AIRS ID Number: 1 7-3/C17-3/C1FVY a(5 v[Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Site Name: Site Location: REP Processing, LLC Pierce Gas Processing Plant Site Location 517930E 4500068N Zone 13T County: Weld KAA '1(I'► hr Ptv atautud taw( SwI+- S21 TAN Ru(PW Mailing Address: 1611 N. Broadway Ave (Include Zip Code) Oklahoma City, OK 73101 E -Mail Address2: JFleak@KahunaVentures.com NAICS or SIC Code: 211130 Permit Contact: James Fleak Phone Number: 720-889-9955 '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. 2Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 384860 Permit Number: AIRS ID Number: (Leave blank unless APCD has already assigned a permit N and AIRS ID) Section 2- Requested Action El NEW permit OR newly -reported emission source -OR - ❑ MODIFICATION to existing permit tcheck each box below that applies) O Change fuel or equipment ❑ Change company name O Add point to existing permit O Transfer of ownership' O Other (describe below) ❑ Change permit limit - 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) O APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: 3For 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: HMO for Amine Reboiler Manufacturer: TBD Model No.: Serial No.: Company equipment Identification No. (optional): HTR1 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: February 2019 El Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Are you reporting multiple identical boilers on this APEN? ❑Yes 0 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): COLORADO Form APCD-220 - Boiler APEN - Revision 7/2016 2 Permit Number: AIRS ID Number: / / (I.eave plank unless APC:I) has already assigned a permit. ' sad AIR ID] Section 4 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 518035E 4500009N Zone 13T Operator Stack ID No. Discharge Height Above Ground Level. (Feet) Temp. (°f7 Flow Rate (ACFM) Velocity (ft/sec) HTR1 25 644 23,652 36.04 Indicate the direction of the stack outlet: (check one) Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): O Other (describe): ❑ Upward with obstructing raincap 44.4 Interior stack depth (inches): Section 5 - Fuel Consumption Information Design Input Rate (MMBTU/hr) Actual Annual Fuel Use' (Specify Units) Requested Annual Permit Limits (Specify Units) 63.000 541.06 mmscfy 541.06 mmscfy From what year is the actual annua fuel use data? NA Fuel consumption values entered above are for: El Each Boiler ❑ All Boilers ❑ N/A Indicate the type(s) of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) El Field Natural Gas Heating value: 1,020 BTU/SCF O Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTUlgallon) ❑ Propane (assumed fuel heating value of 2,300 BTUISCF) ❑ Coal Heating value: BTU/lb Ash Content: Sulfur Content: ❑ Other (describe): Heating value (give units): 'If you are reporting multiple identical boilers on one APEN, be sure to clarify if thevalues in this section are on an individual boiler basis, or if the values represent total fuel usage for multiple boilers. 'Requested values will become permit limitations. Requested limit(s) should consider future process growth. elf fuel heating value is different than the listed assumed value, please provide this information in the "Other" field. Form APCD-220 - Boiler APEN - Revision 7/2016 3 I COLORADO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit II and AIRS ID1 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 El No • If please oescnoe the control yes, Pollutant Control Equipment Description Overall Control Efficiency (% reduction in emissions) TSP (PM) PMro PM2.5 Sax NOx Low NOx Burner 50 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 cne aacu r epui Primary Fuel Type (natural gas, #2 diesel, etc.) Pollutant Uncontrolled Emission Factor (Specify Units) Emission Factor Source a ( P -et ) Mfg. etc Actual Annual Emissions Requested Annual Permit Emission• Limit(s)s Uncontrolled (Tons/year) Controlled (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) Natural Gas TSP (PM) 7.60 AP -42 2.056 2.056 PM,o 7.6 AP -42 2.056 2.056 PM2.5 7.6 AP -42 2.056 2.056 SOx 0.60 AP -42 0.162 0.162 NOx 50.0 AP -42 27.053 13.526 CO 84.0 AP -42 22.724 22.724 VOC 5.50 AP -42 1.488 1.488 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave bl ank. Form APCD-22O - Boiler APEN - Revision 7/2016 COLORADO 4 1� Permit Number: AIRS ID Number: I I [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 sions table below: Secondary Fuel Type (#2 diesel, waste oil, etc.) Pollutant Uncontrolled Emission Factor (SpeclfyUnits) Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions_ Requested Annual Permit Emission Limit(s)s Uncontrolled (Tons/year) Controlled (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) TSP (PM) PM10 PM2.5 SOS NOx 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 Permit Emission Lim- it(s)s Uncontrolled (Tons/year) Controlled' (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) TSP (PM) PM10 PM2.5 SO, NO„ CO VOC Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave bl ank. Form APCD-220 - Boiler APEN - Revision 7/2016 m� COLORADO 5 I Permit Number: AIRS ID Number: [Leave bnank APCD has already assigned a permit n and AIRS ID.I 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 rce: If use the touowrng LaDte to repui I. Li IC iiuti-..i I«I ,4 r�.•vso... •- ,. •• •• ,—....--.___ yes, 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? (Ids/year) 'Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave bl ank. Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. K tla7/fS Signature of Legally Aut rized Person (not a vendor or consultant) Date Kevin Bailey Chief Operating Officer Name (please print) Title Check the appropriate box if you want: Copy of the Preliminary Analysis conducted by the Division Draft permit prior to public notice ❑ Draft of the permit prior to issuance (Checking any of these boxes may result in an increased fee and/or processing time) This notice is valid for five (5) years unless a significant change is made, such as an increased production, new equipment, change in fuel type, etc. A revised APEN shall be filed no less than 30 days prior to the expiration date of this APEN form. 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 Telephone: (303) 692-3150 Form APCD-2.20 BoilerAPEN - Revision 7/2016 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.Rov/cdphe/apcd coLoxno4 Nom, 7/17/201.8 State.co.us Executive Branch Mail - Site Location for Pierce Gas Processing Plant STATE OF COLORADO Underriner - CDPHE, Katherine <katherine.underriner@state.co.us> Site Location for Pierce Gas Processing Plant 2 messages Katherine Underriner - CDPHE <katherine.underriner@state.co.us> To: jfleak@kahunaventures.com Hi James, Mon, Jul 16, 2018 at 12:30 PM While looking at the APENs further I noticed that the site location lists coordinates. These coordinates are listed as 417930E 4500068N Zone 13T which is not a format I have seen before. Based on Google Earth, it looks like this is located around 40.650871, -104.787540. Can you please send me the site location is Section, Township, Range format? Thanks, Katherine Underriner Application Completeness Technician Stationary Sources Program COLORADO Mr Pollution Control Division Department of Wbhc Health & Environment P 303.692.6381 I F 303.782.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 katherine.underriner@state.co.us I www.colorado.gov/cdphe/aped Are you curious about ground -level ozone in Colorado? Visit our ozone webpage to learn more. As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete APENs. Additional fees may apply if an APEN is submitted without the necessary information. An application with missing information may result in longer processing times. Please note that all APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section II.A). Current APEN forms can be found at: https://www.colorado.gov/cdphe/APENforms James Fleak <JFleak@kahunausa.com> Mon, Jul 16, 2018 at 2:56 PM To: Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Hi Katherine, The UTM coordinates were utilized by the consultant that was initially working with REP Processing and he used those values since he put together the dispersion model. The site is located in the SW/4 of S21 T8N R66W. Hope that helps. I received your message about the tanks to be listed individually. I will call to make sure I'm clear how that Form 102 should state the emissions. James James Fleak, P.E. 720-889-9955 Direct https://mail.google.com/mail/u/0?ik=e82d6de00d&view=pt&search=all&permthid=thread-a%3Ar5610759831789739182&simpl=msg-a%3Ar372031820... 1/2 T_ 1 li itiI4 2 9 29%8 ,; Boiler APEN - Form APCD-220 Air Pollutant Emission Notice (APEN) and Application for Construction Permit Alt sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for 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 wilt 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. 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. gov/ 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: IgWE 0111 AIRS ID Number: t 23 /cox/ oI(D [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Site Location: Mailing Address: (include Zfp Code) REP Processing, LLC Pierce Gas Processing Plant 517930E 4500068N Zone 13T S{l J+ S i TS N -U12 W 1611 N. Broadway Ave Oklahoma City, OK 73101 E -Mail Address': JFleak@KahunaVentures.com Km 11 ti I ptr chtd -erne;�� Site Location County: Weld NAICS or SIC Code: 211130 Permit Contact: James Fleak Phone Number: 720-889-9955 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 'Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 384861 Permit Number: AIRS ID Number: I I [Leave blank unless APCD has already assigned a permit II and AIRS ID] Section 2- Requested Action El 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 0 Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' 0 Other (describe below) OR ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - O Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD -104) must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: Mole Sieve Regenerator Heater Manufacturer: TBD Model No.: Serial No.: Company equipment Identification No. (optional): HTR2 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: February 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 Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 days/week 52 weeks/year June -Aug: 25 Sept -Nov: 25 Are you reporting multiple identical boilers on this APEN? ❑Yes 0 No If yes, please describe how the fuel usage wilt be measured for each boiler (i.e., one meter for all boilers or separate meters for each unit): Form APCD-22O - Boiler APEN - Revision 7/2016 1CV COLORADO 2 I ie.IN Y inv.ron.+nl Permit Number: AIRS ID Number: (Leave blank unless APO) has already assigned a permit g and AIRS ID] Section 4 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 518089E 4500009N Zone 13T Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. CO Flow Rate ' (ACFM) Velocity (ft/sec) = HTR2 24 644 6,382 21.67 Indicate the direction of the stack outlet: (check one) 0 Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) El Circular Interior stack diameter (inches): O Square/rectangle Interior stack width (inches): ❑ Other (describe): 0 Upward with obstructing raincap 30 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) 17.000 146.00 mmscfy 146.00 mmscfy From what year is the actual annua fuel use data? NA Fuel consumption values entered above are for: 0 Each Boiler ❑ All Boilers ❑ N/A Indicate the type(s) of fuel used6: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) 0 Field Natural Gas Heating value: 1,020 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): Heating value (give units): if you are reporting multiple identical boilers on one APEN, be sure to clarify if thevalues in this section are on an individual boiler basis, or if the values represent total fuel usage for multiple boilers sRequested values will become permit limitations. Requested limit(s) should consider future process growth. 61f fuel heating value is different than the listed assumed value, please provide this information in the "Other" field. COLD R4D0 Form APCD-220 - Boiler APEN - Revision 712016 Permit Number: AIRS ID Number: i [Leave blank unless APCD has already assigned a permit 11 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? QYes El No erall control efficiency (% reduction): Pollutant Control Equipment Description Overall Control Efficiency (% reductioninemissions) TSP (PM) PM10 PM2.5 SO, NOx Low NOx Burner 50 CO VOC Other: From what year is the following reported actual annual emissions data? NA Use the following tables to report the criteria pollutant emissions from source: ection 5 to catrulate these emissions. Primary Fuel - Type• .„ (natural gas, #2 diesel, eft. Pollutant Uncontrolled Emission Factor (Specify Units) Emission_ Factor _ -' ry Actual Annual Emissions Requested Annual Permit" s Emission Limits) Source (AP -42, Mfg. etc) Uncontrolled (Tons/year) Controlled' (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) Natural Gas TSP (PM) 7.60 AP -42 0.555 0.555 PM,o 7.60 AP -42 0.555 0.555 PM2.5 7.60 AP -42 0.555 0.555 SOx 0.60 AP -42 0.044 0.044 NOx 50.0 AP -42 7.300 3.650 CO 84.0 AP -42 6.132 6.132 VOC 5.50 AP -42 0.402 0.402 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 'Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave bl ank. Form APCD-220 - Boiler APEN - Revision 712016 COLORADO 4I Lam` Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit E and AIRS ID] El 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 Factor (Specify Units) Emission Factor Source (AP -42, Mfg. 9 etc) Actual Annual Emissions -" Requested Annual Permit-- s Emission Limit(s)" _ Uncontrolled (Tons/year) Controlled (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) TSP (PM) PM10 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 Permit ; { - s Emission Limit(s) Uncontrolled (Tons/year) Controlled' (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) TSP (PM) PM10 PM2,5 SO. NO. CO VOC Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 'Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave bl ank. Form APCD-220 - Boiler APEN - Revision 7/2016 &I-If iCOLORADO 5 I�r Permit Number: AIRS ID Number: (Leave blank unless APCD has already assigned a permit. # and AIRS ID.I 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 f use the following table to report the non -Li liel id yes, CAS Number Chemical Name Overall Control Efficiency Uncontrolled Emission Factor (specify units) Emission Factor Source (AP -42, Mfg. etc) Uncontrolled Actual Emissions tbs/year) Controlled Actual Emissions' (!bs/year) 1 7Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave bl ank. Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. /Cz:, Signature of Legally Auth ized Person (not a vendor or consultant) Date Chief Operating Officer Kevin Bailey Name (please print) Title Check the appropriate box if you want: O Copy of the Preliminary Analysis conducted by the Division [J Draft permit prior to public notice D Draft of the permit prior to issuance (Checking any of these boxes may result in an increased fee and/or processing time) This notice is valid for five (5) years unless a significant change is made, such as an increased production, new equipment, change in fuel type, etc. A revised APEN shall be filed no less than 30 days prior to the expiration date of this APEN form. Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Telephone: (303) 692-3150 Form APCD-220 - Boiler APEN - Revision 7/2016 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: I /wwwcolorado. goy /cdphe/apcd OLORAR4 N�mK 7/17/2018 State.co.us Executive Branch Mail - Site Location for Pierce Gas Processing Plant STATE O F COLORADO Underriner - CDPHE, Katherine <katherine.underriner@state.co.us> Site Location for Pierce Gas Processing Plant 2 messages Katherine Underriner -. CDPHE <katherine.underriner@state.co.us> To: jfleak@kahunaventures.com Hi James, Mon, Jul 16, 2018 at 12:30 PM While looking at the APENs further I noticed that the site location lists coordinates. These coordinates are listed as 41.7930E 4500068N Zone 13T which is not a format I have seen before. Based on Google Earth, it looks like this is located around 40.650871, -104.787540. Can you please send me the site location is Section, Township, Range format? Thanks, Katherine Underriner Application Completeness Technician Stationary Sources Program COLORADO Air Pollution Control Division Department of Public Health & Environment P 303.692.6381 I F 303182.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 katherine.underriner@state.co.us I www.colorado.gov/cdphe/aped Are you curious about ground -level ozone in Colorado? Visit our ozone webpage to learn more. As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete APENs. Additional fees may apply if an APEN is submitted without the necessary information. An application with missing information may result in longer processing times. Please note that all APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section II.A). Current APEN forms can be found at: https://www,colorado.gov/cdphe/APENforms James Fleak <JFleak@kahunausa.com> Mon, Jul 16, 2018 at 2:56 PM To: Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Hi Katherine, The UTM coordinates were utilized by the consultant that was initially working with REP Processing and he used those values since he put together the dispersion model. The site is located in the SW/4 of S21 T8N R66W. Hope that helps. I received your message about the tanks to be listed individually. I will call to make sure I'm clear how that Form 102 should state the emissions. James James Fleak, P.E. 720-889-9955 Direct https://mail.google.com/mail/u/0?ik=e82d6de00d&view=pt&search=all&permthid=thread-a%3Ar5610759831789739182&simpl=msg-a%3Ar372031820... 1/2 :f) JUN 29 2018 Boiler APEN — Form APCD-22O Air Pollutant Emission Notice (APEN) and Application for Construction Permit Ali 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.9,ov/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. Rov/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: tgvEO111 AIRS ID Number: (22 'RFe16 /0/7 [Leave blank unless APCD has already assigned a permit # and AIRS ID] J Section 1 - Administrative Information Company Name': REP Processing, LLC Site Name: Pierce Gas Processing Plant Site Location: Mailing Address: (Include Zip Code) 517930E 4500068N Zone 13T swlt SZI -rgN 1611 N. Broadway Ave Oklahoma City, OK 73101 E -Mail Address2: JFIeak@KahunaVentures.com Qfr attach -td erYl�l Site Location County: Weld NAICS or SIC Code: 211130 Permit Contact: James Fleak Phone Number: 720_889.9955 '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. 2Permlts, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 384862 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit II and AIRS ID] Section 2- Requested Action El NEW permit OR newly -reported emission source OR- ❑ MODIFICATION to existing permit (check each box below that applies) o Change fuel or equipment 0 Change company name 0 Add point to existing permit ❑ Change permit limit 0 Transfer of ownership3 0 Other (describe below) OR ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD -104) must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: Trim Recovery HMO Manufacturer: TBD Model No.: Serial No.: Company equipment Identification No. (optional): HTR3 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: February 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 Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 weeks/year June -Aug: 25 Sept -Nov: 25 Are you reporting multiple identical boilers on this APEN? ❑Yes 0 No If yes, please describe how the fuel usage wilt be measured for each boiler (i.e., one meter for all boilers or separate meters for each unit): Form APCD-220 - Boiler APEN - Revision 7/2016 21 AV COLORADO Permit Number: AIRS ID Number: (Leave blank urilrns APCD has already assr;ri i ai permit: and AIRS ID] Section 4 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 518045E 4499969N Zone 13T Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. (•r - Flow Rate (ACFM) Velocity (ft/sec) HTR3 19.8 709 9,938 22.43 Indicate the direction of the stack outlet: (check one) El Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): ❑ Other (describe): ❑ Upward with obstructing raincap 36 Interior stack depth (inches): Section 5 - Fuel Consumption Information Design Input Rate (MMBTU/hr) Actual Annual Fuel Use' (Specify Units) Requested Annual Permit Limit (Specify Units) 25.000 214.71 mmscfy 214.71 mmscfy From what year is the actual annua fuel use data? NA Fuel consumption values entered above are for: 0 Each Boiler ❑ All Boilers O N/A Indicate the type(s) of fuel used': ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) Field Natural Gas Heating value: 1,020 BTU/SCF O 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): Heating value (give units): 4If you are reporting multiple identical boilers on one APEN, be sure to clarify if thevalues in this section are on an individual boiler basis, or if the values represent total fuel usage for multiple boilers '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, please provide this information in the "Other" field. COLORADO Form APCD-220 - Boiler APEN - Revision 7/1.016 3 Permit Number: AIRS ID Number: [Leave blink 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? E✓ 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) PMrp PM2.s SOx NO„ CO Low NOx Burner 50 VOC Other: From what year is the following reported actual annual emissions data? NA Use the following tables to report the criteria pollutant emissions from source: (use We OUL❑ rCpUI CCU In Jcl.tivn -, w .............- -.. _..• Primary Fuel TYPe (natural gas, #2 diesel, _. _.aped etc.) Pollutant t _ Uncontrolled Emission Factor Units) .' Emission Factor Source (AP -42, Mfg. etc); _ "F n Actual Annual Emissions xC Requested Annual Emission Limits Permit` _.. Uncontrolled (Tons/year) Controlled? (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) Natural Gas TSP (PM) 7.60 AP -42 0.816 0.816 PMia 7.60 AP -42 0.816 0.816 PM2.s 7.6D AP -42 0.816 0.816 SOX 0.60 AP -42 0.064 0.064 N0x 50.0 AP -42 10.735 5.368 CO 84.0 AP -42 9.O18 9.018 VOC 5.50 AP -42 0.590 0.590 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 'Anna( emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave bl ank. Form APCD-1.20 - Boiler APEN - Revision 7/2016 4 I 87 COLORADO cl Permit Number: AIRS ID Number: [Leave blank unlcas APCD has already assigned a permit r and AIRS ID] EI 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 Factor (Specify Units) Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions Requested Annual Permit s . , Emission Limit(s) - Uncontrolled (Tons/year) Controlled? (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) TSP (PM) PMto 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 TSP (PM) Actual -Annual Emissions Controlled' (Tons/year) Requested Annual Permit Emission Limit(s)5 Uncontrolled (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PMto PM2.5 SO, NO, CO VOC Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 'Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave bl ank. Form APCD-220 - Boiler APEIJ - Revision 7/2016 51 L 1r COLORADO Name (please print) Permit Number: AIRS ID Number: [Leave `dank unless APCD has already aimed a permit and AIRS IN 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 E] No e: f use the touowing tame Lo repot c we Bull-., ,«r ,A r.,,........._ ,....• , -•.••-- -.. yes, CAS Number Chemical Name Overall Control Efficiency Uncontrolled Emission Factor units) Emission Factor 4Mftc) (AP -42, g. e Uncontrolled Actual Emissions )(lbs/year) (lbs/year) X Controlled Actual Emissions (Ibs(specify y 'Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave bl ank. Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. /Lt�f u Signature of Legally Authori d Person (not a vendor or consultant) Date Kevin Bailey Chief Operating Officer Title Check the appropriate box if you want: ❑ Copy of the Preliminary Analysis conducted by the Division Draft permit prior to public notice ❑ Draft of the permit prior to issuance (Checking any of these boxes may result in an increased fee and/or processing time) This notice is valid for five (5) years unless a significant change is made, such as an increased production, new equipment, change in fuel type, etc. A revised APEN shall be filed no less than 30 days prior to the expiration date of this APEN form. Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B_1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Telephone: (303) 692-3150 Form APCD-220 - Boiler APEN - Revision 7/2016 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/aped [OlABk60 7/17/2018 State.co.us Executive Branch Mail - Site Location for Pierce Gas Processing Plant STATE OF COLO PADO Underriner - CDPHE, Katherine <katherine.underriner@state.co.us> Site Location for Pierce Gas Processing Plant 2 messages Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Mon, Jul 16, 2018 at 12:30 PM To: jfleak@kahunaventures.com Hi James, While looking at the APENs further I noticed that the site location lists coordinates. These coordinates are listed as 417930E 4500068N Zone 13T which is not a format I have seen before. Based on Google Earth, it looks like this is located around 40.650871, -104.787540. Can you please send me the site location is Section, Township, Range format? Thanks, Katherine Underriner Application Completeness Technician Stationary Sources Program COLORADO Air Pollution Control Division Department of Publtc Health & Environment P 303.692.6381 I F 303.782.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 katherine.underriner@state.co.us I www.colorado.gov/cdphelapcd - Are you curious about ground -level ozone in Colorado? Visit our ozone webpage to learn more. As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete APENs. Additional fees may apply if an APEN is submitted without the necessary information. An application with missing information may result in longer processing times. Please note that all APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section II.A). Current APEN forms can be found at: https://www.colorado.gov/cdphe/APENforms James Fleak <JFleak@kahunausa.com> Mon, Jul.16, 2018 at 2:56 PM To: Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Hi Katherine, The UTM coordinates were utilized by the consultant that was initially working with REP Processing and he used those values since he put together the dispersion model. The site is located in the SW/4 of 521 T8N R66W. Hope that helps. I received your message about the tanks to be listed individually. I will call to make sure I'm clear how that Form 102 should state the emissions. James James Fleak, P.E. 720-889-9955 Direct https://mail.google.com/mail/u/0?ik=e82d6de00d&view=pt&search=all&permthid=thread-a%3Ar5610759831789739182&simpl=msg-a%3Ar372031820... 1/2 ✓ E/3%tj 7 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-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.eov/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.eov/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: MATE 0111 AIRS ID Number: • r23 aquae/ 0 Et' [Leave blank unless APCD has already assigned a permit t/ and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Site Location: Mailing Address: (Include Zip Code) REP Processing, LLC Pierce Gas Processing Plant 517930E 4500068N Zone 13T SW L+ s2l TTNJ t? L 1 w 1611 N. Broadway Ave Oklahoma City, OK 73101 E -Mail Address2: JFleak@KahunaVentures.com Ku i 11LLc ptr thachal email Site Location County: Weld JUN 292018 NAICS or SIC Code: 211130 Permit Contact: James Fleak Phone Number: 720-889-9955 '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. My changes will require additional paperwork. Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 384863 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit H and AIRS (DI Section 2- Requested Action El 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 0 Change permit limit 0 Transfer of ownership' ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info a Notes: 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: Stabilizer 10,000bpd Manufacturer: TBD Model No.: Serial No.: Company equipment Identification No. (optional): HTR4 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: February 2019 El Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Are you reporting multiple identical boilers on this APEN? ❑Yes 0 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 7/2016 2 I lr cocoeaoa cam.,- a� Permit Number: AIRS ID Number: [I eave blank unless APC:D has already assigned a permit 9 and AIRS ID) Section 4 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 5 8 8 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp ('17 Flow Rate (ACFM) _.. Velocity (ft/sec) HTR4 19.8 709 9,541 22.5 Indicate the direction of the stack outlet: (check one) 0 Upward O Horizontal O Downward O Other (describe): Indicate the stack opening and size: (check one) El Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): O Other (describe): O Upward with obstructing raincap 36 Interior stack depth (inches): Section 5 - Fuel Consumption Information Design Input Rate (MMBTU/hr) Actual Annual Fuel Uses (Specify Units). Requested Annual Permit Limits (Specify Units) .000 206.12 mmscfy 06. From what year is the actual annua fuel use data? NA Fuel consumption values entered above are for: El Each Boiler ❑ All Boilers ❑ N/A Indicate the type(s) of fuel used6: O Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) O Field Natural Gas Heating value: 1,020 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): Heating value (give units): 41f 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. 5Requested values will become permit limitations. Requested limit(s) should consider future process growth. '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 7/2016 3I A GOLD RA30 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit 11 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 • i ment AND state the overall control efficiency 1% reduction): IT yes, please U SLI Pollutant wv a 1G <.�i mu .,. =.{u p Control Equipment Description Overall ra Control Efficiencyd (% reduction in emissions) TSP (PM) PM10 PM2.5 Sox NOx Low NOx Burner 50 CO VOC Other: From what year is the following reported actual annual emissions data? NA Use the following tables to report the criteria pollutant emissions from source: emissions. Primary Fuel Type (natural gas, #2 diesel, etc.) Pollutant Uncontrolled Emission Factor (Specify Units) Emission Factor Source (AP -42, Mfg. etc) , - °" Actual Annual Emissions �, -.. W._ . ___._ Requested Annual Permit;. Emission„Limit(s a Uncontrolled (Tons/year) Controlled' (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) Natural Gas TSP (PM) 7.60 AP -42 0.783 0.783 PM10 7.60 AP -42 0.783 0.783 PM2.5 7.60 AP -42 0.783 0.783 SOX 0.60 AP -42 0.062 0.062 NOx 50.0 AP -42 10.306 5.153 CO 84.0 AP -42 8.657 8.657 VOC 5.50 AP -42 0.567 0.567 Other: s Requested values will become permit limitations. Requested limit(s) should consider future process growth. 'Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave bl ank. Form APCD-220 - Boiler APEN - Revision 7/2016 ®i• COLORADO TSP (PM) Permit Number: AIRS ID Number: f / [Leave blank unless APCD has already assigned a permit n 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 ons table below: Secondary Fuel Fuel Type (#2 diesel waste oil,. etc.) Pollutant Emission Factor 5 cl Un s) (Specify Emission Factor Source AP -4Z. Mf g. etc) ; ' a `' Actual Annual Emissions Requested Annual Permit :- s Emission Limits) Uncontrolled (Tons/year) Controlled (fons/year)_ Uncontrolled (Tons/year) Controlled (Tons/year) TSP (PM) PM10 PM5_s SO), NOx 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: Actual Annual Emissions Requested Annual Permit Emission Limit(s)!:- Uncontrolled (Tons/year) Controlled' (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM10 PM2.s SOx NO), CO VOC Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 'Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave bl ank. Form APCD-220 - Boiler APEN - Revision 7/2016 5 I coLoeADo Permit Number: AIRS ID Number: / / [leave blank a nL, s APCD has already assig d a permit t rind AIRS I,r 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? Ei Yes ❑ No on -criteria pollutant (HAP) emissions from source: CAS Number Chemical Name Overall Control Efficiency Uncontrolled Emission Factor (specify wits) Emission Factor Source ( 42, Mfg etc) Uncontrolled Actual Emissions (lbs/year) Controlled Actual Emissions a (lbsiyear) 1Annuat emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave bttnk. Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. 6 r/2-7(It Signature of Legally Authoriz d Person (not a vendor or consultant) Date Kevin Bailey Chief Operating Officer Name (please print) Title Check the appropriate box if you want: O Copy of the Preliminary Analysis conducted by the Division 0 Draft permit prior to public notice ❑ Draft of the permit prior to issuance (Checking any of these boxes may result in an increased fee and/or processing time) This notice is valid for five (5) years unless a significant change is made, such as an increased production, new equipment, change in fuel type, etc. A revised APEN shall be filed no less than 30 days prior to the expiration date of this APEN form. 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 Telephone: (303) 692-3150 Form APC0-.220 l;oil_r APEN - Revision 7/2016 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: httos://www.colorado.gov/cdphe/apcd 61 AVCOLORADO w .,.R -- 7/17/2018 State.co.us Executive Branch Mail - Site Location for Pierce Gas Processing Plant STATE OF COLORADO Underriner - CDPHE, Katherine <katherine.underriner@state.co.us> Site Location for Pierce Gas Processing Plant 2 messages Katherine Underriner - CDPHE <katherine.underriner@state.co.us> To: jfleak@kahunaventures.com Hi James, Mon, Jul 16, 2018 at 12:30 PM While looking at the APENs further I noticed that the site location lists coordinates. These coordinates are listed as 417930E 4500068N Zone 13T which is not a format I have seen before. Based on Google Earth, it looks like this is located around 40.650871, -104.787540. Can you please send me the site location is Section, Township, Range format? Thanks, Katherine Underriner Application Completeness Technician Stationary Sources Program COLORADO Air Pollution Control Division Department of Public Health &Environment P 303.692.6381 I F 303.782.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 katherine.underriner@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. As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete APENs. Additional fees may apply if an APEN is submitted without the necessary information. An application with missing information may result in longer processing times. Please note that all APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section II.A). Current APEN forms can be found at: https://www.colorado.gov/cdphe/APENforms James Fleak <JFleak@kahunausa.com> Mon, Jul 16, 2018 at 2:56 PM To: Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Hi Katherine, The UTM coordinates were utilized by the consultant that was initially working with REP Processing and he used those values since he put together the dispersion model. The site is located in the SW/4 of S21 T8N R66W. Hope that helps. I received your message about the tanks to be listed individually. I will call to make sure I'm clear how that Form 102 should state the emissions. James James Fleak, P.E. 720-889-9955 Direct https://mail.google.com/mail/u/0?ik=e82d6de00d&view=pt&search=all&permthid=thread-a%3Ar5610759831789739182&simpl=msg-a%3Ar372031820... 1/2 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. gov/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: vpis AIRS ID Number: (L3 / IFC>E3 /C'(' [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Site Location: REP Processing, LLC Pierce Gas Processing Plant Site Location 517930E 4500068N Zone 13T County: Weld Mailing Address: (Include Zip Code) 1611 N. Broadway Ave Oklahoma City, OK 73101 E -Mail Address2: L.King@RimrockEnergy.com NAICS or SIC Code: 211130 Permit Contact: Lance King Phone Number: 405-317-9587 '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. 2Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Stack Information eogra obtude/Longitude or, 518043E 4499998N Zone 13T for Cl eratorr Stac I0 A« ' DischargeHieight� Above laroun Level 5(Feetf x ya ,e, r F Ft0 Rate CFMftr a �� Ye[oa HTR4 19.8 709 9,541 22.5 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 Square/rectangle Interior stack width (inches): O Other (describe): O Upward with obstructing raincap 36 Interior stack depth (inches): Section 5 - Fuel Consumption Information Design Input Rate ,t 5 (MMBTU/hrj Actual ual Fuel Use4 Ann (Specify Umts) Requested Annual Permit Limits ($pecify`Units) 24.000 206.12 mmscfy 24 mmBtu/Hr From what year is the actual annual fuel use data? NA Fuel consumption values entered above are for: 0 Each Boiler O All Boilers ❑ N/A Indicate the type(s) of fuel used6: p Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑ Field Natural Gas Heating value: 1,020 BTU/SCF O Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) O Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coat Heating value: BTU/lb Ash Content: Sulfur Content: ❑ Other (describe): Heating value (give units): '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. 'Requested values will become permit limitations. Requested limits) should consider future process growth. 'If fuel heating value is different than the listed assumed value, please provide this information in the "Other" field. Form APCD-22O - Boiler APEN - Revision 7/2016 COLORADO 3 I •. HMIU d EMrlt0�6�Nf< 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: TSP (PM) PM 10 PM2.5 SOX NOx 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: tcontrolled TSP (PM) Controlled (Tons /year} Jncontrolled`: (Tons/year) ,.: ontralled Tons/year) PM10 PM2.5 SOX NOx CO VOC Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 'Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-22O - Boiler APEN - Revision 7/2016 5 1 AV ROOM m 6lSMlMlginf COLORADO Boiler APEN - Form APCD-220 Air Pollutant Emission Notice (APEN) and Application for Construction Permit Alt sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for 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.Rov/cdphe/aped. 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. goy/ 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. V ED JUN 292018 Permit Number: IWOYI [Leave blAnk unless APCD has already assigned a permit # and AIRS ID] AIRS ID Number: 12 3 iciFDPI d 1 q Section 1 - Administrative Information Company Name: Site Name: Site Location: Mailing Address: (Include Zip Code) REP Processing, LLC Pierce Gas Processing Plant 517930E 4500068N Zone 13T Ryvl+ S2-1 TAN ttw 1611 N. Broadway Ave Oklahoma City, OK 73101 E -Mail Address': JFleak@KahunaVentures.com K.0 IIB per ati-ac►ua fma(" I Site Location County: Weld NAICS or SIC Code: 211130 Permit Contact: James Fleak Phone Number: 720-889-9955 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 'Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 384864 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit l,' and AIRS ID] Section 2- Requested Action O NEW permit OR newly -reported emission source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' O Other (describe below) -OR - ❑ APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) El APEN submittal for permit exempt/grandfathered source Additional Info & Notes: 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD -104) must be submitted. Section 3 - General Boiler Information General description of equipment and purpose: TEG Reboiler Heater Manufacturer: TBD Model No.: Serial No.: Company equipment Identification No. (optional): HTR5 For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: February 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: 24 hours/day 7 Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 days/week 52 weeks/year June -Aug: 25 Sept -Nov: 25 Are you reporting multiple identical boilers on this APEN? ❑Yes 1✓❑ 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 7/2016 AV COLORADO 2 O Upward O Horizontal Permit Number: AIRS ID Number: / / [heave blank unless APC I) has already assigned a permit ; and AIRS ID] Section 4 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 517914E 4499941N Zone 13T Operator Stack ID No. Discharge Height " Above Ground Level Temp. (•F) Flow Rate - (ACFM) '- Velocity (rt/sec) HTR5 22.0 644 188 3.98 Indicate the direction of the stack outlet: (check one) ❑ Downward O Other (describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): ❑ Square/rectangle Interior stack width (inches): O Other (describe): ❑ Upward with obstructing raincap 12 Interior stack depth (inches): Section 5 - Fuel Consumption Information Design Input Rate (MMBTU/hr) Actual Annual Fuel Use (Specify Units), Requested Annual Permit Limits (Specify Units) 0.500 4.29 mmscfy 4.29 mmscfy From what year is the actual annual fuel use data? NA Fuel consumption values entered above are for: 0 Each Boiler ❑ All Boilers ❑ N/A Indicate the type(s) of fuel used°: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) 0 Field Natural Gas Heating value: 1,020 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): Heating value (give units): if you are reporting multiple identical boilers on one APEN, be sure to clarify if thevalues in this section are on an individual boiler basis, or if the values represent total fuel usage for multiple boilers 5Requested values will become permit limitations. Requested limit(s) should consider future process growth. 61f fuel heating value is different than the listed assumed value, please provide this information in the "Other" field. Form APCD-220 - Boiler APEN - Revision 7/2016 3 p ono Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit 1' 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? D✓ Yes No describe the control euipment AND state the overall control efficiency (% reduction): If yes please q Pollutant Control Equipment Description Overall Control Efficiency (% reduction in emissions) TSP (PM) PM u) PMz.5 S0x N0x Low NOx Burner 50 CO V0C Other: From what year is the following reported actual annual emissions data? NA 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 Type (natural gas, #2 diesel, etc.) Pollutant `: Uncontrolled Emission Factor (Specify Units) Emission Source (AP -42, Mfg. etc) ° Actual Annual Emissions Factor Emission Limits) _.�._ - Requested Annual Permit _- s ,.: T a! Uncontrolled (fons/year) Controlled (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year), Natural Gas TSP (PM) 7.60 AP -42 0.016 0.016 PM,o 7.60 AP -42 0.016 0.016 PM1.5 7.60 AP -42 0.016 0.016 SO,, 0.60 AP -42 0.001 0.001 N0x 50.0 AP -42 0.215 0.107 CO 84.0 AP -42 0.180 0.180 VOC 5.50 AP -42 0.012 0.012 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 'Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave bl ank. Form APCD-220 - Boiler APEN - Revision 7/2016 4I /V COLORADO r: Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit. F.' and AIRS I01 0 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 Emissbn Factor (Specify 11n1ts) Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions ` Requested Annual Permit s Emission Limits) Uncontrolled (Tons/year) Controlled' (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) TSP (PM) PM10 PM2.5 SOx 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 TSP (PM) Uncontrolled (Tons/year) Controlled' (Tons/year) Requested Annual Perm Emission Limit(s)5 Uncontrolled (Tons/year) Controlled (Tons/year) PMla PM2.5 SOx NOx CO VOC Other: 5 Requested values wilt become permit limitations. Requested limit(s) should consider future process growth. 'Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave bl ank. Form APCD-220 - Boiler APEN - Revision 7/2016 Permit Number: AIRS ID Number: [Leave blank unlens 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 rce: t yes, use the rouowing CAS Number I.auLe w I Chemical Name rpua L u Pc 1I.,r Overall Control Efficiency -..' '....... ,..,.......... Uncontrolled Emission Factor ,..... , _...__ -. - - — Emission Factor Source (AP -42, Mfg. etc) (lbs/year) (specify units) ( Uncontrolled Actual Emissions Y ) Controlled Actual Emissions (Ills/year) 'Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave bl ank. 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 Authori d Person (not a vendor or consultant) Date Kevin Bailey Chief Operating Officer Name (please print) Title Check the appropriate box if you want: ❑ Copy of the Preliminary Analysis conducted by the Division [r] Draft permit prior to public notice ❑ Draft of the permit prior to issuance (Checking any of these boxes may result in an increased fee and/or processing time) This notice is valid for five (5) years unless a significant change is made, such as an increased production, new equipment, change in fuel type, etc. A revised APEN shall be filed no less than 30 days prior to the expiration date of this APEN form. 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 Telephone: (303) 692-3150 Form APCD-220 - Boiler APEN - Revision 7/2016 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 AVM, COLORADO 7/17/2018 State.co.us Executive Branch Mail - Site Location for Pierce Gas Processing Plant STATE OF COLORADO Underriner - CDPHE, Katherine <katherine.underriner@state.co.us> Site Location for Pierce Gas Processing Plant 2 messages Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Mon, Jul 16, 2018 at 12:30 PM To: jfleak@kahunaventures.com Hi James, While looking at the APENs further I noticed that the site location lists coordinates. These coordinates are listed as 417930E 4500068N Zone 13T which is not a format I have seen before. Based on Google Earth, it looks like this is located around 40.650871, -104.787540. Can you please send me the site location is Section, Township, Range format? Thanks, Katherine Underriner Application Completeness Technician Stationary Sources Program COLORADO Air Pollution Control Division Department of Petite Health &Environment P 303.692.6381 I F 303.782.0278 4300 Cherry Creek Drive South, Denver, CO 80246-1530 katherine.underriner@state.co.us I www.colorado.gov/cdphe/aped Are you curious about ground -level ozone in Colorado? Visit our ozone webpage to learn more. As of January 1, 2014, the Colorado Air Pollution Control Division no longer accepts blank or incomplete APENs. Additional fees may apply if an APEN is submitted without the necessary information. An application with missing information may result in longer processing times. Please note that all APEN submissions should be completed using forms currently supplied by the Division (See Reg. 3, Part A, Section II.A). Current APEN forms can be found at: https://www.colorado.gov/cdphe/APENforms James Fleak <JFleak@kahunausa.com> To: Katherine Underriner - CDPHE <katherine.underriner@state.co.us> Hi Katherine, Mon, Jul 16, 2018 at 2:56 PM The UTM coordinates were utilized by the consultant that was initially working with REP Processing and he used those values since he put together the dispersion model. The site is located in the SW/4 of S21 T8N R66W. Hope that helps. I received your message about the tanks to be listed individually. I will call to make sure I'm clear how that Form 102 should state the emissions. James James Fleak, P.E. 720-889-9955 Direct https://mail.google.com/mai I/u/0?ik=e82d6de00d&view=pt&search=all&permthid=thread-a%3Ar5610759831789739182&simpl=msg-a%3Ar372031820... 1/2 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 gas venting only. Gas venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEII for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: vgwe e O11'F AIRS ID Number: ' a3 / 1`r—bl3 / O. O [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name1: REP Processing, LLC Site Name: Pierce Gas Processing Plant Site Location: 517930E 4500068N Zone 13T Mailing Address: 1611 N. Broadway Ave (Include Zip Code) Oklahoma City, OK 73101 Site Location County: Weld NAICS or SIC Code: 211130 Contact Person: Phone Number: E -Mail Address2: Lance King 405-317-9587 L.King@RimrockEnergy.com I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-211 - Gas Venting APEN - Revision 7/2018 1 I ,COLORADO ! Departmental Pantie HWM&phlenmMl AIRS ID Number: / Permit Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID) Section 4 - Process Equipment Information O Gas/Liquid Separator O Well Head Casing O Pneumatic Pump Make: Model: O Compressor Rod Packing Make: ❑✓ Blowdown Events # of Events/year: ❑ Other Description: Serial #: Capacity: gal/min Model: # of Pistons: Leak Rate: Scf/hr/pist 24 Volume per event: 0.0096 MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑ Yes Gas Venting Process Parameters5: Liquid Throughput Process Parameters5: Vented Gas Properties: 0 No Vent Gas Heating Value: 1 224 BTU/SCF Requested: 0.23 MMSCF/year Actual: MMSCF/year -OR- Requested: bbl/year Actual: bbl/year Molecular Weight: 23.67 VOC (Weight %) 30.6 Benzene (Weight %) 0.058 Toluene (Weight %) 0.004 Ethylbenzene (Weight %) 0.001 Xylene (Weight %) 0 n -Hexane (Weight %) 0.563 2,2,4-Trimethylpentane (Weight %) 0 Additional Required Information: ▪ Attach a representative gas analysis (including BTEX i3 n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-211 - Gas Venting APEN - Revision 7/2018 3 I ............................... ,COLORADO 2.52 lbs/event Eng. Est. PM Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Overall' Requested itrol Efficiency„« action in" emissions sox NO. CO VOC HAPs Other: From what year is the following reported actual annual emissions data? enaPollutant Emissions Inventory NA NA NA NA NA ontrol inusions onsfyear)? PM SOX NA NA NA NA NA NO. NA NA NA NA NA CO NA NA NA NA NA VOC 0.659 tons/event Eng. Est 15.8 0.79 on -Criteria Reportable":Poll lutant Emissions Invento mission Facts ua nual Emissions. roller :missions• ounds/year) v ontrolled issions9. undryear) Benzene 71432 Toluene 108883 0.168 lbs/event Eng. Est. Ethylbenzene 100414 0.042 lbs/event Eng. Est. Xylene 1330207 0.0 lbs/event Eng. Est. n -Hexane 110543 24.21 lbs/event Eng. Est. 2,2,4- Trimethylpentane 540841 0.0 lbs/event Eng. Est. Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 - Gas Venting APEN - Revision 7/2018 5I COLORADO R.= Mann MannE fnte n nmaN Inlet Compressor Blowdowns P1 (PSIA) V1 (ft^3) T2 (OR) P2 (PSIA) T1 (DR) Blowdown Volume (ft^3) Blowdown Density (Ibs/ft^3) 112.2 935 579.67 12.2 519.67 9591.749 0.448707 VOC Density (Ibs/ft^3) 1.044826 Mass (Ibs) / VOC Content Event (Ibs) / Event 4303.885019 1317.06038 VOC Volume (ft/9) 1260.554972 VOC Composition Propane i-Butane n -Butane i-Pentane n -Pentane Cyclopentane Hexane Cyclohexene Heptane Methylcyclohe: 2,2,4-Trimethy Benzene Toluene Ethylbenzene o-Xylene m-Xylene p-Xylene Octane Nonane Decane Total VOC Tons of Uncontrolled VOC / Tons / Year (24 Event Events) 0.65853 15.8047246 Mass Fraction (%) VOC Mass 18.7540029 807.1507 2.15E+00 92.45378 6.16E+00 265.3266 1.27E+00 54.85828 1.40E+00 60.31403 1.35E-01 5.824843 0.56259364 24.21338 0.02746813 1.182197 0.03707245 1.595556 0.01070859 0.460886 0 0 0.05846298 2.516179 0.00389864 0.167793 0.00097799 0.042092 0 0 0 0 0 0 0.02177528 0.937183 0.00032839 0.014134 6.36E-05 0.002737 30.6016629 Controlled Tons / Year (24 Events) 0.79023623 Permit Number: MRS 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 name3 ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) OR O APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info & Notes: 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Inlet Compressor Blowdown MSS -1 Maintenance, Startup & Shutdown Company equipment Identification No. (optional): For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: Feb. 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: 24 Will this equipment be operated in any NAAQS nonattainment area? hours/day 7 Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions? Is this equipment subject to Colorado Regulation No. 7, Section XVII.G? Form APCD-211 - Gas Venting APEN - Revision 7/2018 days/week 52 weeks/year 0 Yes ❑ Yes Yes ❑ No No ❑ No COLORAD'D 2 I r<J Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit ii and AIRS ID) Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: Compressor Rod Packing Make: ❑✓ Blowdown Events # of Events/year: ❑ Other Description: Serial #: Model: # of Pistons: 24 Capacity: gal/min Leak Rate: Scf/hr/pist Volume per event: 0.0096 MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? O Yes Gas Venting Process Parameters5: Liquid Throughput Process Parameters5: Vented Gas Properties: Vent Gas Heating Value: ❑✓ No 1Zio4' 1,2Pi4 BTU/SCF Requested: 0.23 MMSCF/year Actual: MMSCF/year -OR- Requested: bbl/year Actual: bbl/year Molecular Weight: y6' 25, 0 3 VOC (Weight %) 3,9.,e/7 -/Z. Benzene (Weight %) 0,388 6.010 Toluene (Weight %) 0,..004 0.005 Ethylbenzene (Weight %) Q. -9Y( a .005- Xylene (Weight %) ,0' 0. 001`0 n -Hexane (Weight %) p�583 O, -3 2,2,4-Trimethylpentane (Weight %) fir 0. DO / 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) 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-211 - Gas Venting APEN - Revision 7/2018 3IAV COLORADO Permit Number: AIRS ID Number: / / Benzene PM [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach alt emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): ►escnption of Control Method(s) Overall Requested Control Efficiency :(% reduction rn emissions) SO. NO. CO VOC HAPs Other: From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Uncontrolled Basis PM NA NA NA Source (AP -42, Mfg.., etc). Actual Annual Emiss ons Requested Annual Permit• Emission:Limit(s')5, - Uncontrolled Emissions (tons/ year) Controlled Emissfonsb (tons%year) :. Uncontrolled Emissions (tons/yeor) NA Controlled Emissions (tons/year) NA SOx NA NA NA NA NA NO. NA NA NA NA NA CO NA NA NA NA NA VOC O 09 tons/event Eng. Est. ;1.,5O /0. (o (P of53 Non -.Criteria Reportable Pollutant Emissions.; Inventory Chemical, Abstract Service (CAS) Number 71432 Emission Factor _ Actual Annual Emissions Uncontrolled Basis o; lbs/event Source, (AP -41, .Mfg., etc.) Eng. Est. Uncontrolled Emissions .:' (pounds/year) Controlled Emissions'_- (pounds/year) Toluene 108883 o(;,43; lbs/event Eng. Est. Ethylbenzene 100414 0 2bcz4' X0.293 Ibs/event Eng. Est. Xylene 1330207 lbs/event Eng. Est. n -Hexane 2,2,4- Trimethylpentane Other: 110543 540841 , - D 3s/event 0:0O,03 lbs/event Eng. Est. Eng. Est. 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. COLORADO Form APCD-211 - Gas Venting APEN - Revision 7/2018 Inlet Compressor Blowdowns P1 (PSIA) V1 (ft^3) T2 (°R) P2 (PSIA) T1 (°R) Blowdown Volume (ft^3) Blowdown Density (Ibs/ft^3) 112.2 935 579.67 12.2 519.67 9591.749 0.537595 VOC Density (Ibs/ft^3) 1.044826 VOC Mass (lbs) / Content Event (lbs) / Event 5156.476424 888.16388 VOC Volume (ft^3) 850.0592749 Tons of VOC/ Event 0.444082 ProMax Stream 3 on Tab LP Inlet VOC Composition Propane i-Butane n -Butane i-Pentane n -Pentane Mass Fraction (%) 10.4422181 1.27573141 3.55890951 0.6998649 0.75565425 Cydopentane 0.03933896 Hexane 0.27280916 Cydohexene 0.01209923 Heptane 0.11564998 Methylcyclohe: 0.01209547 2,2,4-Trimethy 0.00141158 Benzene 0.01012968 Toluene 0.00838813 Ethylbenzene 0.00477122 o-Xylene 0.00076364 m-Xylene 0.00086569 p-Xylene 0.00405189 Octane 0.00756841 Nonane 0.00140827 Decane 0.00051058 Total VOC 17.2242401 VOC Mass 538.4505 65.78279 183.5143 36.08837 38.96513 2.028504 14.06734 0.623894 5.963464 0.6237 0.072788 0.522335 0.432532 0.246027 0.039377 0.044639 0.208935 0.390263 0.072617 0.026328 Uncontrolled Tons / Year (24 Events) 10.65796656 Controlled Tons / Year (24 Events) 0.532898328 3 0 tai Gas Venting APEN - Form APCD-2117 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for gas venting only. Gas venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEII for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: C3 kJ E 0.7 T-4 AIRS ID Number: I �3 / RFD13 / / [Leave blank unless APCD has already assigned a permit r: and AIRS ID] Section 1 - Administrative Information Company Name': REP Processing, LLC Site Name: Pierce Gas Processing Plant Site Location: 517930E 4500068N Zone 13T Mailing Address: (Include Zip Code) 1611 N. Broadway Ave Oklahoma City, OK 73101 Site Location County: Weld NAICS or SIC Code: 211130 Contact Person: Phone Number: E -Mail Address2: Lance King 405-317-9587 L.King@RimrockEnergy.com I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices wilt be issued by the APCD via e-mail to the address provided. Form APCD-211 - Gas Venting APEN Revision 7/2018 1 COLORADO 1 cepareewd Pith 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: ❑✓ Blowdown Events # of Events/year: ❑ Other Description: Serial #: Capacity: gal/min Model: # of Pistons: Leak Rate: Scf/hr/pist 728ea., except 1 NGL Volume per event: 0.0014-0.0276 see talcs MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? Gas Venting Process Parameters5: Liquid Throughput Process Parameters5: Vented Gas Properties: ❑ Yes ❑✓ No Vent Gas Heating Value: 1483 BTU/SCF Requested: 3.2 MMSCF/year Actual: MMSCF/year -OR- Requested: bbl/year Actual: bbl/year Molecular Weight: VOC (Weight %) 0.028-85.14 Benzene (Weight %) 0.000-0.058 Toluene (Weight %) 0.000-0.044 Ethylbenzene (Weight %) 0.001-0.013 Xylene (Weight %) 0.000-0.015 m -Hexane (Weight %) 0.000-1.333 2,2,4-Trimethylpentane (Weight %) 0.000-0.028 Additional Required Information: Attach a representative gas analysis (including BTEX Ft n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Ft n -Hexane, temperature, and pressure) 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-211 - Gas Venting APEN - Revision 7/2018 3I COLORADO Xa:1g16 EW19Nept Permit Number: AIRS ID Number: / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): PM So. NO. CO VOC HAPs Other: From what year is the following reported actual annual emissions data? ntena Poll'.utant Emissions Inventor NA NA NA NA NA PM SOx NA NA NA NA NA NO. NA NA NA NA NA CO NA NA NA NA NA VOC 0.0001-1.43 tons/event Eng. Est. 183.6 9.2 'n Criteria .` ortable Pollutan missions• Invent 71432 0.001-0.167 lbs/event Eng. Est. missiota_Factoi Benzene ua �nua missli as Toluene 108883 0.001-0.133 lbs/event Eng. Est. Ethylbenzene 100414 0.00D-0.010 lbs/event Eng. Est. Xylene 1330207 0.000-0.054 lbs/event Eng. Est. n -Hexane 110543 0.0D-3.43 lbs/event Eng. Est. 2,2,4- Trimethylpentane 540841 0.000-0.085 lbs/event Eng. Est. Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 - Gas Venting APEN - Revision 7/2018 51 COLORADO Residue Pig Launcher Blowdowns P1 (PSIA) V1 (ft^3) T2 ('R) P2 (PSIA) 150 110 519.67 12.2 Mass (lbs) / VOC Content Uncontrolled Controlled Event (Ibs) / Event Tons of VOC / Tons / Year Tons / Year T1 (OR) 519.67 Event (728 Events) (728 Events) Blowdown Volume (ft^3) 1352.459 743.9836475 0.20993358 0.000104967 0.076415822 0.003820791 Blowdown Density (lbs/ftA3) 0.550097 VOC Volume (ft^3) VOC Density (Ibs/ft^3) 1.54885 0.135541581 VOC Mass Composition Fraction (%) VOC Mass Propane 0.0282165 0.209926174 i-Butane 5.80E-07 4.31206E-06 n -Butane 4.16E-07 3.09187E-06 i-Pentane 2.26E-11 1.68185E-10 n -Pentane 5.24E-12 3.90092E-11 Cyclopentane 2.60E-13 1.9353E-12 Hexane 0 0 Total VOC 0.0282175 HP Inlet Pig Receiver Blowdowns P1 (PSIA) V1 (ft^3) T2 (°R) P2 (PSIA) T1 (°R) Blowdown Volume (ftA3) Blowdown Density (Ibs/ftA3) 162.2 110 519.67 12.2 519.67 1462.459 0.729073 Mass (Ibs) / Event 1066.239619 VOC Volume (ftA3) VOC Density (Ibs/ftA3) 1.451153 209.0225887 VOC Composition Propane i-Butane n -Butane i-Pentane n -Pentane Cyclopentane Hexane Cyclohexene Heptane Methylcyclohe) 2,2,4-Trimethyl Benzene Toluene Ethylbenzene o-Xylene m-Xylene p-Xylene Octane Nonane Decane Total VOC VOC Content Tons of Uncontrolled (Ibs) / VOC / Tons / Year Event Event (728 Events) 303.32376 0.151662 110.4098494 Mass Fraction (%) 14.569254 2.20E+00 6.15E+00 1.45E+00 1.73E+00 1.57E-01 1.1321126 0.0989085 0.380454 0.0949026 0.0283869 0.0549031 0.043912 0.0033636 2.58E-03 2.66E-03 0.0125441 0.1272784 0.1363347 7.27E-02 28.447992 VOC Mass 155.3432 23.4068 65.58674. 15.45265 18.49464 1.67803 12.07103 1.054601 4.056552 1.011889 0.302673 0.585398 0.468207 0.035864 0.027484 0.0284 0.133751 1.357093 1.453655 0.775141 Controlled Tons / Year (728 Events) 5.520492468 Residue Compressor Blowdowns P1 (PSIA) Vi (ft^3) T2 (°R) P2 (PSIA) T1 (SR) 342.2 935 579.67 12.2 IVtass (Ibs) / VOC Content Uncontrolled Controlled Event (Ibs) / Event Tons of VOC / Tons / Year (24 Tons / Year 519.67 Event Events) (24 Events) Blowdown Volume (ft^3) 29253.98 30595.56779 8.63330403 0.004316652 0.103599648 0.005179982 Blowdown Density (Ibs/ft^3) 1.04586 VCC Volume (ftA3) VOC Density (lbs/ftA3) 28.41621 0.303816192 ProMax Stream Residue on Tab 4 - 200MM Cryo VOC Mass Composition Fraction (%) VOC Mass Propane 0.0282165 8.632999538 i-Butane 5.80E-07 0.000177329 n -Butane 4.16E-07 0.00012715 i-Pentane 2.26E-11 6.91642E-09 n -Pentane 5.24E-12 1.60421E-09 Cyclopentane 2.60E-13 7.95873E-11 Hexane 0 0 Total VOC 0.0282175 Hello