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Home My WebLink About20170203.tiffCOLORADO Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150O St PO Box 758 Greeley, CO 80632 January 10, 2017 Dear Sir or Madam: RECEIVED JAN 162017 WELD COUNTY COMMISSIONERS On January 12, 2017, the Air Pollution Control Division will begin a 30 -day public notice period for Verdad Oil and Gas Corporation - Meehl 24-2N. 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 a 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 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 (" P� b l i c ,v le) -v 011@3/1-7 cc= PLc(wry NLCPC3) PwCE2fcH/c lc/3m) or/lCA/ r'7 2017-0203 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Verdad Oil and Gas Corporation - Meehl 24-2N - Weld County Notice Period Begins: January 12, 2017 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: Verdad Oil and Gas Corporation Facility: Meehl 24-2N Oil and Gas Exploration and Production Facility SWSE Sec24 Ti N R65W Weld County The proposed project or activity is as follows: The applicant proposes to operate a new exploration and production facility, consisting of Compression engine, condensate tanks, separator venting, produced water tanks, and condensate loadout. 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 16WE0775 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: David Thompson Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us COLORADO 1 *. 3iaaM, Erz'+iuxnafmFix Division Information Engineer: David Thompson Control Engineer: Steph Spector Review Date: 09/20/2016 Application Date: 06/23/2016 Facility Identifiers Permit No. 16WE0775 AIRS County # 123 'Weld Facility # 9E9A Facility Type: exploration and production facility Located in the 8 -hour non -attainment area? Administrative Information Potentially Located within EAC - determine attain O True Minor ® Synthetic Minor for: r VOC r NOx r CO Company Name: Verdad Oil and Gas Corporation Source Name: Meehl 24-2N Source Location: SIC: SWSE S24 T1 N R65W 1311 Mailing Address Address 1: Address 2: ty, State Zip: Verdad Oil and Gas Corporation 5950 Cedar Springs Road, Suite 200 Dallas, TX 75235 Person To Contact Name: Phone: Fax: Email: Arthur Beecher) 214-728-1840 000-000-0000 abeecherl@verdadoil.com Requested Action Self Certification Required? Issuance Number: Yes 1 Source Description: Oil and gas exploration and production facility known as the Meehl 24-2N, located in the SWSE S24 Ti N R65W, Weld County, Colorado. Point Name Type Control Action 001 Compressor Engine Catalytic Oxidizer Newly reported source 002 Fugitives Fugitives None Cancelled 003 Condensate Storage Tanks Condensate Tanks Flare Newly reported source 004 Condensate Loading Loadout None newly reported source 005 Separators Separator Venting Flare Newly reported source 006 Produced Water Water Tanks Flare Newly reported source Division Information Engineer: David Thompson Control Engineer: Steph Spector Review Date: 09/22/2016 Application Date: 05/26/2016 Facility Identifiers Permit No. 16WE0767 AIRs County # 123 Weld Facility # 9E95 Point # 001 Facility Equipment ID Compressor Section 01: Administrative Information Attainment Status PM10 Attainment PM2.5 Attainment SOx Attainment NOx Nonattainment VOC Nonattainment CO Attainment Potentially Located within EAC - determine attainr Company Name: Verdad Oil and Gas Company Source Name: Highland 29-1N Source Location: W SNE Sec 29 Ti N R65W SIC: 1311 Elevation (feet) 0 Mailing Address Address 1: Address 2: City, State Zip: Verdad Oil and Gas Company 5950 Cedar Springs Road, Suite 200 Dallas TX, 75235 Contact Name: Arthur Beecherl Section 02: Requested Action pt New permit/newly reported emission ✓ Request MOD - Change fuel/equipment ✓ Request MOD - Change permit limit ✓ Request MOD - Change company name ✓ Request MOD - Transfer of ownership ✓ Request MOD - Other Issuance Number: 1 Add] Info and notes: r Request portable source permit If this is an exemption, enter XA or XP here •General Facility Information General description of equipment purpose: This emission unit is used for natural gas compression. Date the engine was ordered: 10/7/2015 Date engine construction commenced: 42/11/2015 Date engine relocated into Colorado: 10/1/2015 Date of any reconstruction/modification: 1/1/1900 Will this equipment be operated in any nonattainment area? Yes • Engine Information Engine Info Engine date of mfg 2/1/20151 Engine Displacement - 5.7 Ucyl Manufacturer: General Motors Model Number: FX 10Q Serial Number: 10CHMM502250021 Engine Function Compression berating Mfg's Max. Rated Horsepower @ sea level: 192 C Derate Based on Altitude: C Derate by a factor of: C Use Site -Specific Rating: r' No Deration 3 % for every 500 feet over 3000 feet of altitude 0.5 1000 hp Horsepower used for calcuations: 92 BSCF @ 100% Load (btu/hp-hr): 8500 Site - Rated BSCF @ 100% load (btu/hp-hr): 8500 BSCF: Site -Rated value will be used when available Other Parameters Engine Type 4SRB Aspiration naturally aspirated Electrical Generator Max Site Rating (kw) 0 Annual hours for PTE 8760 Annual hours for permit 8760 <-Optional: Use generator rating to estimate horsepower instead of derating and mfg value above Assumed efficiency: 75.0% Section 06: Fuel Consumption Information Fuel Use Rate @ 100% Load 823 scf/hr ACTUAL Annual Fuel Consumption 7.21 MMscf/yr MAX POTENTIAL Annual Fuel Consumption 7.210 MMscf/yr REQUESTED Annual Fuel Consumption 7.210 MMscf/yr Fuel Heating Value 950.25 btu/scf <-Optional: Use default fuel heating values <-Optional: Use BSCF & FHV to estimate Max potential Annual Fuel Consumption Section 07: Emission Control Information Primary Control Device Description CHOOSE ONE and delete the non -selective catalytic reduction (NSCR) system and air -fuel ratio control Uncontrolled Emission Factors - Criteria & HCHO Pollutant Value - lb/MM Btu Value - g/bhp-hr Source/Comments NOx 3.631 14.000 CO 2.853 11.000 VOC 0.182 0.700 Formaldehyde 0.021 0.079 Use ? Button to find a default set of values. Use ! Button to enter value in one set of units and have the program find the other one NOTE: the program needs to have values in both unit sets entered, please Control Efficiency/Controlled Emission Factors - Pollutant Value - lb/MMBtu Value - g/bhp-hr Control (%) Source/Comments NOx 0.254 0.980 93.0% CO 0.514 1.980 82.0% VOC 0.182 0.700 0.0% Formaldehyde 0.021 0.079 0.0% For each controlled pollutant, enter one of the following: mm u, g/bhp-hr or %. Then press button to calculate the rest. NOTE: the program needs to have all values entered, please Other Pollutants - Emission Factors and Controls Step 1 Choose a set of uncontrolled emission factors for SO2, PM, PM10, PM2.5 and Step 2 Option A: Choose one set for everything (i.e. AP -42) Option B: Choose the highest value for each pollutant (i.e., some will be AP -42, some will Option C: Write in a value for each pollutant yourself Option D: Run option A or B for all pollutants, and then Run Option C to overwrite a few vz Enter a control efficiencies (if applicable) for SO2, PM, PM10, PM2.5 and NCRP Ignore step 2 if the engine is uncontrolled. MACT ZZZZ Facility HAP Status Area Source Is the engine an emergency RICE under 7777 definitions? No Is the engine a limited use RICE under 7777 definitions? No Is the engine a landfill/digester gas RICE under 7777 definitions? No MACT 7777 Category: New/Recon 4SRB less than or equal to 500 HP The permit document will include guidance about what MACT ZZZZ conditions to include based on the MACT ; NSPS JJJJ Currently this rule is not adopted into Reg No. 6, the permit only addresses NSPS JJJJ in the notes to permit he Regulation No. 7 - Section XVII.E (Statewide Standards) rseoowers listed above, the following standards appy: HP Con/Relocate Date NOx CO VOC NA January 1, 2011 NA NA NA Engine meets stds preconrol? NA NA NA Engine meets stds postcontrol? NA NA NA Final Calculations Click this button AFTER all entries on this page are complete to finalize calculations on the "Emission Calculations" Tab. Summary of Preliminary Analysis - NG RICE Company Name Facility Name Facility Location Facility Equipment ID Verdad Oil and Gas Company Highland 29-1N SWNE Sec 29 Ti N R65W Compressor Permit No. AIRS Review Date Permit Engineer 16WE0767 123/9E95/001 09/22/2016 David Thompson Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) General Motors, Model FX 10Q, Serial Number 10CHMM502250021, natural gas -fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 92 horsepower. 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) 7.21 Requested (mmscf/m) 0.61 Fuel Heat Value (btu/scf) 950.25 BSCF (Btu/hp-hr) 8500 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) 8760 Permit limits calculated at (hpy) 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 PM 10 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 12.4 0.9 12.4 93.0% VOC 0.6 0.6 0.6 0.0% CO 9.8 1.8 9.8 82.0% SOx 0.0 0.0 0.0 0.0% TSP 0.1 0.1 0.1 0.0% PM 10 0.1 0.1 0.1 0.0% PM2.5 0.1 0.1 0.1 0.0% Total HAPs* 0.0 0.0 0.1 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. HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde * * 140 0.0% Methanol * * 21 0.0% Acetaldehyde * * 19 0.0% Acrolein * * 18 0.0% Benzene * * 11 0.0% 1,3 -Butadiene * * 5 0.0% Toluene * * 4 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus I— WI...ILLII SU .w.ya...c............a Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT ZZZZ New/Recon 4SRB less than or equal to 500 HP located at a(n) Area Source Reg 7 XVII.E Standards (g/hp-hr) NOx: NA CO: NA VOC: NA Reg 7 XVI.B (Ozone NAA requirements) applies? No MACT ZZZZ (area source) Is this engine subject to MACT Z777 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 0 Preliminary Analysis: RICE Emission Calculations - NG RICE Company Name Verdad Oil and Gas Company Permit No. 16WE0767 AIRS 123/9E95/001 Engine Type 4SRB Throughputs Requested Fuel Consumption (MMBtu/yr) Max Potential Fuel Consumption (MMBtu/yr) Actual Fuel Consumption (MMBtu/yr) Emissions (tpv) - Criteria MMBtu/yr 6851.303 6851 303 6851.303 MMscf/yr 7.21 7.21 7.21 PM10 PM2.5 TSP SO2 NOx VOC CO Uncontrolled Requested Emissions 0.1 0.1 0.1 0.0 12.4 0.6 9.8 Controlled Requested Emissions 0.1 0.1 0.1 0.0 0.9 0.6 1.8 PTE 0.1 0.1 0.1 0.0 12.4 0.6 9.8 Uncontrolled Actual Emissions 0.066492 0.002014 12.439013 0.62195064 9.77351 Controlled Actual Emissions 0.066492 0.002014 0.8707309 0.62195064 1.759232 Emission Factors - Criteria PM10 PM2.5 TSP SO2 NOx VOC CO lb/MMBtu - Uncontrolled 0.019 0.019 0.019 0.001 3.631 0.182 2.853 Ib/MMBtu - Controlled 0.019 0.019 0.019 0.001 0.254 0.182 0.514 Control 0.0 0.0 0.0 0.0 93.0% 0.0% 82.0% 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 1/6/2017 Colorado Department of Public Health Envrionment Air Pollution Control Division Page 9 of 31 Preliminary Analysis: RICE Emission Calculations Company Name Verdad Oil and Gas Company Permit No. 16WE0767 AIRS 123/9E95/001 Emissions - NCRPs Pollutant Formaldehyde Methanol Acetaldehyde Acrolein Benzene 1,3 -Butadiene Toluene Xylene PAH CAS BIN Requested Controlled lb/yr Uncontrolled lb/yr PTE lb/yr Actual Controlled I Uncontrolled lb/yr lblyr Cont. Req. actual>Rep lb/yr 50000 A 140.5 140.5 140.5 140.5 140.5 0.0 0.0 75070 A 19.1 19.1 19.1 19.1 19.1 0.0 0.0 71432 A 10.8 10.8 10.8 10.8 10.8 0.0 106990 A 4.5 4.5 4.5 4.5 4.5 0.0 108883 C 3.8 3.8 3.8 3.8 3.8 0.0 1330207 C 1.3 1.3 1.3 1.3 1.3 0.0 0 0 1.0 1.0 1.0 1.0 1.0 0.0 Naphthalene 91203 B 0.7 0.7 0.7 0.7 0.7 0.0 Methylene Chloride 75092 A 0.3 0.3 0.3 0.3 0.3 0.0 1,1,2,2-Tetrachloroethane 79345 A 0.2 0.2 0.2 0.2 0.2 0.0 Ethylbenzene 100414 C 0.2 0.2 0.2 0.2 0.2 0.0 Ethylene Dibromide 106934 A 0.1 0.1 0.1 0.1 0.1 0.0 Carbon Tetrachloride 56235 A 0.1 0.1 0.1 0.1 0.1 0.0 1,1,2-Trichloroethane 79005 A 0.1 0.1 0.1 0.1 0.1 0.0 Chloroform 67663 A 0.1 0.1 0.1 0.1 0.1 0.0 Chlorobenzene 108907 A 0.1 0.1 0.1 0.1 0.1 0.0 1,3-Dichloropropene 542756 A 0.1 0.1 0.1 0.1 0.1 0.0 Styrene 100425 C 0.1 0.1 0.1 0.1 0.1 0.0 1,1-Dichloroethane 75343 B 0.1 0.1 0.1 0.1 0.1 0.0 Vinyl Chloride 75014 A 0.0 0.0 0.0 0.0 0.0 0.0 2-Methylnaphthalene 91576 0 0.0 0.0 0.0 0.0 0.0 0.0 2,2,4-Trimethylpentane 540841 C 0.0 0.0 0.0 0.0 0.0 0.0 Acenaphthene 0 0 0.0 0.0 0.0 0.0 0.0 0.0 Acenaphthylene 0 0 0.0 0.0 0.0 0.0 0.0 0.0 Anthracene 0 0 0.0 0.0 0.0 0.0 0.0 0.0 Benz(a)anthracene 0 0 0.0 0.0 0.0 0.0 0.0 0.0 Benzo(a)pyrene 0 0 0.0 0.0 0.0 0.0 0.0 0.0 Benzo(b)fuoranthene 0 0 0.0 0.0 0.0 0.0 0.0 0.0 Benzo(e)pyrene 0 0 0.0 0.0 0.0 0.0 0.0 0.0 Benzo(g,h,i)perylene 0 0 0.0 0.0 0.0 0.0 0.0 0.0 Benzo(k)fluoranthene 0 0 0.0 0.0 0.0 0.0 0.0 0.0 Biphenyl 92524 C 0.0 0.0 0.0 0.0 0.0 0.0 Chrysene 0 0 0.0 0.0 0.0 0.0 0.0 0.0 Fluoranthene 0 0 0.0 0.0 0.0 0.0 0.0 0.0 Fluorene 7782414 C 0.0 0.0 0.0 0.0 0.0 0.0 Indeno(1,2,3-c,d)pyrene 0 0 0.0 0.0 0.0 0.0 0.0 0.0 n -Hexane 110543 C 0.0 0.0 0.0 0.0 0.0 0.0 Printed 1/6/2017 67561 C 107028 A 21.0 18.0 21.0 18.0 21.0 18.0 21.0 18.0 21.0 18.0 Colorado Department of Public Health Envrionment Air Pollution Control Division PTE >Reportable 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 Unc. Requested 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 10 of 31 Preliminary Analysis: RICE Emission Calculations Company Name Verdad Oil and Gas Company Permit No. 16WE0767 AIRS 123/9E95/001 Emission Factors - NCRPs Pollutant Fnrmnlrleli,iAn CAS cnnnn Controlled Uncontrolled Emission Factor IbIMMBtu Iglbhp-hr n l% Control 'Notes Emission Factor lb/MMBtu Iglbhp-hr'Notes Colorado Department of Public Health Envrionment Air Pollution Control Division Methanol Acetaldehyde Acrolein Benzene 1,3 -Butadiene Toluene Xylene PAH Naphthalene Methylene Chloride 1,1, 2, 2-Tetrachloroethane Ethylbenzene 0.0205 O 0.00306 0.011797954 0 0.00279 0.010756958 O 0.00263 0.010140072 0.0% No Control 0 0.00158 0.006091754 0.0% No Control 0.0% No Control 0.0% No Control O 0.000663 0.002556223 0.0% No Control .02 0.07904 0.00 0.00306 0.0118 AP -42; Table 3.2-3 (7/2000); Natural Gas 0.00279 0.01076 AP -42; Table 3.2-3 (7/2000); Natural Gas 0.00263 0.01014 AP -42; Table 3.2-3 (7/2000); Natural Gas 0.00158 0.00609 AP -42; Table 3.2-3 (7/2000); Natural Gas 0.000663 0.00256 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.000558 0.002151392 0.0% No Control 0.000558 0.00215 AP -42; Table 3.2-3 (7/2000); Natural Gas O 0.000195 0.00075183 0.0% No Control 0.000195 0.00075 AP -42; Table 3.2-3 (7/2000); Natural Gas O 0.000141 0.000543631 0.0% No Control 0.000141 0.00054 AP -42; Table 3.2-3 (7/2000); Natural Gas O 0.0000971 0.000374373 0.0% No Control 9.71 E-05 0.00037 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000412 0.000158848 0.0% No Control 4.12E-05 0.00016 AP -42; Table 3.2-3 (7/2000); Natural Gas O 0.0000253 9.75452E-05 0.0% No Control 2.53E-05 9.8E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas O 0.0000248 9.56174E-05 0.0% No Control 2.48E-05 9.6E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas Ethylene Dibromide 0 0.0000213 8.2123E-05 0.0% No Control 2.13E-05 8.2E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas Carbon Tetrachloride 0 0.0000177 6.82431E-05 0.0% No Control 1.77E-05 6.8E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 1,1,2-Trichloroethane 0 0.0000153 5.89898E-05 0.0% No Control 1.53E-05 5.9E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas Chloroform 0 0.0000137 5.28209E-05 0.0% No Control 1.37E-05 5.3E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas Chlorobenzene 0 0.0000129 4.97365E-05 0.0% No Control 1.29E-05 5E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 1,3-Dichloropropene 0 0.0000127 4.89654E-05 0.0% No Control 1.27E-05 4.9E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas Styrene 0 0.0000119 4.58809E-05 0.0% No Control 1.19E-05 4.6E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 1,1-Dichloroethane 0 0.0000113 4.35676E-05 0.0% No Control 1.13E-05 4.4E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas Vinyl Chloride 0 0.00000718 2.76828E-05 0.0% No Control 7.18E-06 2.8E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 2-Methylnaphthalene 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 2,2,4-Trimethylpentane 0 0 0 #DIV/0l No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas Acenaphthene 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas Acenaphthylene 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas Anthracene 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas Benz(a)anthracene 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas Benzo(a)pyrene 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas Benzo(b)fluoranthene 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas Benzo(e)pyrene 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas Benzo(g,h,i)perylene 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas Benzo(k)fluoranthene 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas Biphenyl 0 0 0 #DIV/0! No Control 0 0 AP -42, Table 3.2-3 (7/2000); Natural Gas Chrysene 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas Fluoranthene 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas Fluorene 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas Indeno(1,2,3-c,d)pyrene 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas n -Hexane 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas Printed 1/6/2017 Page 11 of 31 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 3.63 0 0.254179667 0 2.21 CO 2.85 0 0.513546674 0 3.72 VOC 0.18 0 0.181556905 0 2.96E-02 Formaldehyde 50000 A 0.02 0 0.0205 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 12 of 31 Printed 1/6/2017 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 9.71E-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 1004251 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 13 of 31 Printed 1/6/2017 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 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 glbhp-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 925241 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 14 of 31 Printed 1/6/2017 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 HAPCalc 3.0 Literature Literature Test Data Test Data Natural Gas Field Gas Natural Gas Field Gas Pollutant CAS I BIN g/bhp-hr g/bhp-hr glbhp-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 750921A n -Hexane 110543 C Naphthalene 912031 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 75014IA Xylene 13302071 C 0.0014 0.0017 1.70E-03 Page 15 of 31 Printed 1/6/2017 COLORADO DEPARTMENT OF PUBLIC HEALTH ENVIRONMENT AIR POLUTION CONTROL DIVISION INVENTORY AIRS (County/Plant) 123/9E951001 Permit No. 16WE0767 Date 9/22/2016 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 (tray)* Ctrl. Eff% NCRP = reportable ? 001 2-02-002-53 NOx n 3450.49 lb/MMscf 0 0.9 0.9 12.4 93% CO n 2711.1 lb/MMscf 0 1.8 1.8 9.8 82% VOC n 172.524 Ib/MMscf 0 0.6 0.6 0.6 0% 50000 Formaldehyde n 19.4801 lb/MMscf o 140 140 140 0% No 67561 Methanol n 2.90777 lb/MMscf AP -42; Table 3.2-3 (7/2000); Natural Gas 21 21 21 0% No 75070 Acetaldehyde n 2.6512 lb/MMscf AP -42; Table 3.2-3 (712000); Natural Gas 19 19 19 0% No 107028 Acrolein n 2.49916 lb/MMscf AP -42: Table 3.2-3 (72000); Natural Gas 18 18 18 0% No 71432 Benzene n 1.5014 lb/MMscf AP -42; Table 3.2-3 (7/2000); Natural Gas 11 11 11 0% No 106990 1,3 -Butadiene n 0.63002 lb/MMscf AP -42; Table 3.2-3 (7/2000); Natural Gas 5 5 5 0% No 108883 Toluene n 0.53024 lb/MMscf AP -42; Table 3.2-3 (72000); Natural Gas 4 4 4 0% No 1330207 Xylene n 0.1853 Ib/MMscf AP -42; Table 3.2-3 (7/2000); Natural Gas 1 1 1 0% No 0 PAH n 0.13399 lb/MMscf AP -42; Table 3.2-3 (7/2000); Natural Gas 1 1 1 0% No 91203 Naphthalene n 0.09227 lb/MMscf AP -42; Table 3.2-3 (7/2000); Natural Gas 1 1 1 0% No NOTES *Emissions of criteria are reported in tons/yr; emissions of NCRPs are in lb/yr. Engine BSCF: 8500 Btu/hp-hr Engine HP: 92 Fuel Heat Value: 950.25 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) You can copy each row into the permit history file for a facility -wide summary. The first row can be copied into the Criteria tab. The second and third rows can be copied into the HAPs tab. Be sure to do Edit, Paste Special, Values to avoid creating links back to this PA in the history file. POINT PERMIT Description NOx VOC Fug VOC CO 001 16WE0767 General Motors FX 10Q 92HP 0.9 0.6 1.8 Controlled Emissions I POINT 'PERMIT 'Description I Formaldehyde 'Acetaldehyde I Benzene lAcrolein 001 16WE0767 General Motors FX 10Q 92HP 140 19 Uncontrolled 11 18 'POINT (PERMIT (Description 'Formaldehyde 'Acetaldehyde 'Benzene lAcrolein I 001 16WE0767 General Motors FX 10Q 92HP 140 19 11 18 Notes: Controlled emissions shown above are calculated using the control efficiencies/factors specified on the d Uncontrolled emissions shown above are calculated based on uncontrolled EFs specified on the data en issions Reportable HAPs Total HAPs NOx VOC Fug VOC CO Reportabl e HAPs Total HAPs 12.4 0.6 9.8 (Toluene IEthylbenzeneIXylene In -Hexane 12,2,4-Trim4Methanol I1,3-Butadienel 0 0 21 5 4 0 1 (Toluene I Ethylbenzene IXylene In -Hexane 12,2,4-Trim4Methanol Ii,3-Butadienel 0 0 21 5 4 0 1 lata entry sheet, at the permitted fuel use rate (calculated at 8760 hpy) try sheet, at the maximum potential fuel use rate (calculated at 8760 hpy) Preliminary Analysis - NG RICE Modeling Model Inputs (Facili Permit: 16WE0767 Source Type Point Emission Rate - NOx 2.5E-02 g/sec Source: NOx annual rate calculated in Preliminary Analysis Emission Rate - NO2 1.9E-02 g/sec (NO2 = NOx rate • 0.75) Release Height 10 meters Receptor Height 0 meters Stack Height 0 ft Exit Temperature 0 °F Inside Diameter 0 ft Exit Velocity 0 ft/sec Urban/Rural Rural Model Results (Facili. Maximum Impact from model (1 -hr concentration): 0µg/m3 NO2 Max Impact occurs at (distance): 0 meters Convert 1 -hr concentration to Annual Concentration 0.00 µg/m3 (annual conc. = 1 -hr conc. x 0.08) Background Concentration 'Annual Concentration: I 0µg/m' Source: Ambient Background Concentration Database (October, 2005) Region: # Subregion: X - XXX Total Impacts (Facility + Background Total Impacts (µg/m3) Ambient Standard (µg/m3) Complies with Ambient Standard? Annual Concentration: 0.0 100 Yes 1/6/2017 003 Three (3) above ground 300 bbl atmospheric condensate storage tank Requsted Throughput 54750 bbl Control Flare Efficiency 95.00%I mmary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 9.74228 lb/bbl 266.7 tpy 13.3 tpy E&P TANK Benzene 0.02455277 lb/bbl 1344.26406 lb/yr 67.2132 lb/yr E&P TANK n -Hexane 0.1343941 lb/bbl 7358.07698 lb/yr 367.9038 lb/yr E&P TANK Regulatory Review Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2 — Odor Section 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 if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 6 - New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. This source is not subject because each tank is less than 19,800 gallons (471 bbl) NSPS OOOO: for storage vessels in the natural gas production, transmission, and processing segments. This source is not subject because each tank emits less than 6 tpy VOC. Regulation 7 — Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Applicant is not subject to the emission control requirements for condensate tanks since it is located in an attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is not currently subject to this since actual uncontrolled emissions are less than 20 tpy of VOC.) 004 Hydrocarbon Loadout to Tanker Trucks Calculations L = 12.46*S*P*M/T (AP -42: Chapter 5.2, Equation 1) L = loading losses in lb per 1000 gallons loaded The table of inputs below enables you to calculate the loading loss emissions factor "L". If you choose to use a state default emissions factor, you may enter is directly into cell B14 in units lb/1,000 gallons which Factor Meaning Value Units Source S Saturation Factor 0.6 AP -42 P True Vapor Pressure 5.4032 psia Sales Oil A M Molecular Weight of Val 40.68 lb/lb-mole AP -42 T Liquid Temperature 520 deg. R Field Data L 3.16 lb/10^3 gal 1.33E-01 lb/bbl Annual requested Throughput Annual requested VOC emissions Control: None Efficiency: 0.00% NCRPs Component Mass Fraction Benzene 0.0035 n -hexane 0.0187 Toluene Xylenes Source: nalysis 0.018 0.0654 7.56E-04 2.75E-03 109500 BBL/yr 4599000 gal/yr 14533 lb/yr 7.27 tpy If the operator provides HAP speciation from a stable "sales oil" analysis, enter the mass fraction from this data. Alternatively, if the operator modeled a pressurized oil to develop a site specific emissions factor, enter the modeled Pressurized oil or Stable Sales Oil Analysis Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.1327 lb/bbl 7.3 tpy 7.3 tpy AP -42 Benzene 0.0008 lb/bbl 82.8 lb/yr 82.8 lb/yr AP -42 n -Hexane 0.0027 lb/bbl 301 lb/yr 301 lb/yr AP -42 Regulatory Review Regulation 3 - APEN and Permitting Requirements Is this site considered an exploration and production location (e.g. well pad)? If yes, review the following two exemptions for applicability: Does the operator unload less than 10,000 gallons (238 BBLs) per day of crude oil on an annual average basis? If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section II.D.1.1 Does this operator unload less than 6,750 bbls per year of condensate via splash fill or 16,308 bbls per year of condensate via submerged fill procedure? No If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section II.D.1.1 Yes No Produced Natural Gas Venting/Flaring Preliminary Analysis Division Information Colorado Department of Public Health and Environment Air Pollution Control Division Equipment Description This source vents natural gas from: a well head separator Emissions from this source are: routed to an enclosed flare Natural gas venting from a well head separator. Emissions from this source are routed to an enclosed flare. 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 Gas/oil ratio liquid throughput Throughput total downtime of compressor 11.602 scf/gal 54750 bbl 2299500 gal 26678799 scf 26.678799 MMscf 5% Throughput (Q) MW 1.33 MMscf/yr 41.070 Ib/Ib-mol 152.3 scf/hr 0.000 MMscf/d 0.11 MMscf/mo mole % MW Ibx/Ibmol mass fraction E lb/hr lb/yr Helium 0 4.0026 0.000 0.000 Helium 0.0 0 CO2 1.442 44.01 0.635 0.015 CO2 0.3 2234 N2 1.134 28.013 0.318 0.008 N2 0.1 1118 methane 19.932 16.041 3.197 0.078 methane 1.3 11253 ethane 21.061 30.063 6.332 0.154 ethane 2.5 22285 propane 35.256 44.092 15.5451 0.379 propane 6.2 54713 isobutane 3.87 58.118 2.2492 0.055 isobutane 0.9 7916 n -butane 11.152 58.118 6.4813 0.158 n -butane 2.6 22812 isopentane 2.025 72.114 1.4603 0.036 isopentane 0.6 5140 n -pentane 2.535 72.114 1.8281 0.045 n -pentane 0.7 6434 cyclopentane 0.362 70.13 0.2539 0.006 cyclopentane 0.1 894 n -Hexane 0.3660 86.18 0.3154 0.008 n -Hexane 0.1 1110 cyclohexane 0.1110 84.16 0.0934 0.002 cyclohexane 0.0 329 Other hexanes 0.166 86.18 0.1431 0.003 Other hexanes 0.1 504 heptanes 0.231 100.21 0.2315 0.006 heptanes 0.1 815 methylcyclohexane 0.086 98.19 0.0844 0.002 methylcyclohexane 0.0 297 224-TMP 0.01 114.23 0.0114 0.000 224-TMP 0.0 40 Benzene 0.128 78.12 0.1000 0.002 Benzene 0.0 352 Toluene 0.045 92.15 0.0415 0.001 Toluene 0.0 146 Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment Air Pollution Control Division Ethylbenzene 0.008 106.17 0.0085 0.000 Ethylbenzene 0.0 30 Xylenes 0.014 106.17 0.0149 0.000 Xylenes 0.0 52 C8+ Heavies 0.066 2616.594 1.7270 0.042 C8+ Heavies 0.7 6078 mass traction: 41.070 0.7448 Notes Mole %, MW, and mass fractions from Critter Creek 2-03H gas analysis collected XX/X/XX. Emissions are based on 8760 hours of operation per year. I calculated the average MW of C8+ based on the average MW on the analysis for the gas. Total VOC Emissions (Uncontrolled) annual limit assuming 95% control monthly limit assuming 95% control (lb/mo.) Flaring Information Equipment Description Flare to combust lowpressure separator gas during VRU downtime. Cimmarron Energy Manufacturer Model Serial Number Gas Heating Value Throughput Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment Air Pollution Control Division ECD-2-48-210 2291 3056.056425 Btu/scf MMBtu/yr Combustion emission factor source: AP -42: Chapter 13.5 0.068 lb NOX/MMBtu tpy NOX 0.37 0.57 lb CO/MMBtu tpy CO 0.10 Emissions Summary 0.1 tpy NOX Uncontrolled/PTE 0.6 tpy CO 53.8 tpy VOC Controlled 2.7 tpy VOC Uncontrolled Total (Ib/yr) Scenario A Reportable? Controlled Total (Ib/yr) Benzene 352 Yes 18 Toluene 146 No 7 Ethylbenzene 30 No 1 Xylenes 52 No 3 n -hexane 1110 Yes 56 224-TMP 40 No 2 Regulatory Applicability AQCC Regulation 1 _ This source is subject to the opacity requirements for flares in Section II.A.5:'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity.' 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." Regulation 3 Part A: An APEN is required for this source because uncontrolled VOC emissions exceed two tons per year in an attainment area. Part B: A permit is required for this source because uncontrolled VOC emissions from this facility exceed five tons per year in an attainment area. This source is subject to Section III.D.2 (Minor Source RACT) because it is located in a nonattainment area. RACT for this source has been determined to be the use of a flare to control emissions. Is public comment required? Public Comment Required AQCC Regulation 7 Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014? _ yes This separator is subject to Reg 7, Section XVII.G. and control requirements of Reg 7, XVI1.B.2 Facility Status This facility is a synthetic minor source of NOXNOC/CO/HAP for Title V applicability. This facility is a synthetic minor source of NOXNOC/CO/HAP for NSR applicability. Produced Natural Gas Venting/Flaring Preliminary Analysis tpy 0.00 1.12 0.56 5.63 11.14 27.36 3.96 11.41 2.57 3.22 0.45 0.56 0.16 0.25 0.41 0.15 0.02 0.18 0.07 Colorado Department of Public Health and Environment Air Pollution Control Division Produced Natural Gas Venting/Flaring Preliminary Analysis 0.01 0.03 3.04 53.8 2.7 457.2 Colorado Department of Public Health and Environment Air Pollution Control Division Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment Air Pollution Control Division 005 One (1) above ground 400 bbl produced water storage tank Emissions Calculations Requsted Throughput 10950 bbl Control Flare Efficiency 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.262 lb/bbl 1.43445 tpy 0.071723 tpy CDPHE Benzene 0.007 lb/bbl 76.65 lb/yr 3.8325 lb/yr CDPHE n -Hexane 0.022 lb/bbl 240.9 lb/yr 12.045 lb/yr CDPHE Regulatory Review Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (only needed if using flare) Regulation 2 — Odor 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 if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. COLORADO DEPARTMENT OF PUBLIC HEALTH ENVIRONMENT AIR POLUTION CONTROL DIVISION INVENTORY AIRS (County/Plant) // Permit No. 0 Date 1/0/1900 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 ? 0 31000205 NOx n 155.788 lb/MMscf AP -42: Chapter 13.5 0.1 0.1 0% CO n 847.67 lb/MMscf AP -42: Chapter 13.5 0.6 0.6 0% VOC n 80709.36 lb/MMscf Engineering Calcs 2.7 53.8 95% 71432 Benzene n 263.8354 lb/MMscf Engineering Calcs 18 352 95% Yes 108883 Toluene n 109.4129 lb/MMscf Engineering Calcs 7 146 95% No 100414 Ethylbenzene n 22.4106 lb/MMscf Engineering Calcs 1 30 95% No 1330207 Xylene n 39.2185 lb/MMscf Engineering Calcs 3 52 95% No 110543 n -Hexane n 832.2396 lb/MMscf Engineering Calcs 56 1110 95% Yes 540841 224-TMP n 30.1398 lb/MMscf Engineering Calcs 2 40 95% No NOTES *Emissions of criteria are reported in tons/yr; emissions of NCRPs are in lb/yr. POINT PERMIT Descriptior NOx VOC Fug VOC CO Reportable Total HAP; NOx 000 00xx0000 Produced r 0.426859 11.22081 2.322616 0.426859 Controlled Emissions POINT PERMIT Descriptior Formaldeh Acetaldehy Benzene Acrolein Toluene Ethylbenze Xylene 000 00xx0000 Produced natural gas venting 54.21817 25.98192 9.210738 15.35123 Uncontrolled POINT PERMIT Descriptior Formaldeh Acetaldehy Benzene Acrolein Toluene Ethylbenze Xylene 000 00xx0000 Produced natural gas venting 1084.363 519.6385 184.2148 307.0246 VOC Fug VOC CO Reportable Total HAPs 224.4162 2.322616 n -Hexane 2,2,4 -Trim( Methanol 1,3 -Butadiene 199.3737 5.780822 n -Hexane 2,2,4 -Trim( Methanol 1,3 -Butadiene 3987.474 115.6164 STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 PERMIT NO: 16WE0775 CONSTRUCTION PERMIT Issuance 1 DATE ISSUED: ISSUED TO: Verdad Oil and Gas Company THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Meehl 24-2N, located in SWSE SEC24 T1 N R65W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Point Description Compressor 001 One (1) General Motors, Model FX 10Q, Serial Number 10CHMM502250021, natural gas -fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 92 horsepower. non -selective catalytic reduction (NSCR) system and air -fuel ratio control This emission unit is used for natural gas compression. Condensate Storage Tanks 003 Three (3) 400 barrels manifolded together used to store condensate. Condensate Loading 004 Loadout of condensate into tank trucks Separator Venting 005 Produced gas vented from separators during compressor downtime. Point 001: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another General Motors FX 10Q 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 THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION AIRS ID: 123/9E9A Page 1 of 18 NGEngine Version 2014-1 Public Health and Environment Air Pollution Control Division 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. The Notice of Startup form may be downloaded online at https://www.colorado.Qov/pacific/cdphe/other-air- permittinQ-notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section I II.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. (Reference: Regulation No. 3, Part B, 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 per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 4. 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 5. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type NOX VOC CO Compressor 001 0.9 0.6 1.8 Point Condensate Storage Tanks 003 13.3 Point Condensate Loading 004 8.6 Point Separators 005 0.1 2.7 0.6 Point 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 be less than 8.0 tpy. Facility -wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. AIRS ID: 123/9E9A Page 2 of 18 Public Health and Environment Air Pollution Control Division Compliance with the annual 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 emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 6. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit (Reference: Regulation No.3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled Compressor 001 Catalytic Reduction and Air to Fuel Ratio Controller NOx, CO Condensate Storage Tanks 003 Enclosed Flare VOC, HAPs Separators 005 Enclosed Flare VOC, HAPs PROCESS LIMITATIONS AND RECORDS 7. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Compressor p 001 Consumption of natural gas as a fuel 7.21 MMscf/yr Condensate Storage Tanks 003 Condensate 54,750 bbl/yr Condensate Loading 004 Condensate Loadout 109,500 bbl/yr AIRS ID: 123/9E9A Page 3 of 18 Public Health and Environment Air Pollution Control Division Produced gas vented from Separators 005 separators during compressor downtime 1.4 MMscf/yr Fuel consumption shall be measured by one of the following methods: individual engine fuel meter; facility -wide fuel meter attributed to fuel consumption rating and hours of operation; or manufacturer -provided fuel consumption rate. The owner or operator shall calculate monthly process rates based on the calendar month. Produced gas vented from separators during downtime will be measured by using a cubic feet of gas to gallon of liquid ratio of 11.602 and tracking liquid throughputs during compressor downtime 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. 8. Point 004: Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 9. Point 005: The owner or operator must use monthly VRU downtime records, monthly condensate/crude oil throughput records, calculation methods detailed in the O&M Plan, and the emission factors established in the Notes to Permit Holder to demonstrate compliance with the process and emissions limits specified in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 10. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 11. Point 001: 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 I I.A.1. & 4.) 12. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 13. Point 003: This source is subject to Regulation Number 7, Section XII. 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 condensate storage tanks; and • Ensure that the combustion device controlling emissions from this storage tank be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion AIRS ID: 123/9E9A Page 4 of 18 Public Health and Environment Air Pollution Control Division device, or by other means approved by the Division, determine whether it is operating properly. (Regulation Number 7, Section XII.C.) (State only enforceable) 14. Point 003 and 005: 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. 15. Point 003: The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall install and operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons except where the combustion device has been authorized by permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation Number 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two years, made available to the Division upon request. This control requirement must be met within 90 days of the date that the storage tank commences operation. 16. Point 003: The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Section XVII.C.2. 17. Point 004: This source is located in an ozone non -attainment or attainment - maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 18. Point 004: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.D.2): a. 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. AIRS ID: 123/9E9A Page 5 of 18 Public Health and Environment Air Pollution Control Division 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. 19. Point 004: 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. OPERATING & MAINTENANCE REQUIREMENTS 20. 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 your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 21. Point 001: A source initial compliance test shall be conducted on emissions point 001 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emission limits in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. Volatile Organic Compounds using EPA approved methods. Hazardous Air Pollutants using EPA approved methods. 22. Point 003 and 005: The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XII.C, XVII.B.2. and XVII.A.16) Periodic Testing Requirements 23. Point 001: 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. AIRS ID: 123/9E9A Page 6 of 18 Public Health and Environment Air Pollution Control Division 24. Point 003 and 005: The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, on a weekly basis to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XII.C, XVII.B.2. and XVII.A.16) ADDITIONAL REQUIREMENTS 25. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. 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 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. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative -operating scenario and is installing a permanent replacement engine. 26. Federal regulatory program requirements (i.e. PSD or NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). AIRS ID: 123/9E9A Page 7 of 18 Public Health and Environment Air Pollution Control Division GENERAL TERMS AND CONDITIONS 27. 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 No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 28. 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 No. 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. 29. 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. 30. 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. 31. 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. 32. 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. 33. 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. AIRS ID: 123/9E9A Page 8 of 18 Public Health and Environment Air Pollution Control Division By: David Thompson Permit Engineer Permit Histo Issuance Date Description Issuance 1 This Issuance Issued to Verdad Oil and Gas Corporation. AIRS ID: 123/9E9A Page 9 of 18 Public Health and Environment Air Pollution Control Division 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 (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emission Rate (Ib/yr) Are the emissions reportable? Controlled Emission Rate (lb/yr) 001 Formaldehyde 50000 140 No 140 Methanol 67561 21 No 21 Acetaldehyde 75070 19 No 19 Acrolein 107028 18 No 18 Benzene 71432 11 No 11 1,3 -Butadiene 106990 5 No 5 Toluene 108883 4 No 4 003 Benzene 71432 1345 Yes 68 n -Hexane 110543 7359 Yes 368 004 Benzene 71432 83 No 83 n -Hexane 110543 301 No 301 005 Benzene 71432 352 Yes 18 Toluene 108883 146 No 7 Ethylbenzene 100414 30 No 1 Xylenes 1330207 52 No 3 n -hexane 110543 1110 Yes 56 224-TMP 540841 40 No 2 AIRS ID: 123/9E9A Page 10 of 18 Public Health and Environment Air Pollution Control Division 5) The emission levels contained in this permit are based on the following emission factors: Point 001: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr NOx 3.6311 14.00 0.2542 0.98 CO 2.8530 11.00 0.5135 1.98 VOC 0.1816 0.70 0.1816 0.70 50000 Formaldehyde 0.0205 0.08 0.0205 0.08 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 71432 Benzene 0.0016 0.01 0.0016 0.01 106990 1,3 -Butadiene 0.0007 0.00 0.0007 0.00 108883 Toluene 0.0006 0.00 0.0006 0.00 Emission factors are based on a Brake -Specific Fuel Consumption Factor of 8500 Btu/hp-hr, a site -rated horsepower value of 92, and a fuel heat value of 950.25 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde 0 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 71432 Benzene AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 106990 1,3 -Butadiene AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 108883 Toluene AP -42; Table 3.2-3 (7/2000); Natural Gas No Control Point 003: Pollutant Emission Factors Uncontrolled Source lb/bbl Condensate Throughput VOC 9.74 E&P TANK n -Hexane 0.025 E&P TANK Benzene 0.135 E&P TANK Note: The controlled emissions for this point are based on the flare coni Point 004: Pollutant Emission Factors Uncontrolled lb/bbl loaded - Source VOC 0.137 AP -42 AIRS ID: 123/9E9A rol efficiency of 95%. Page 11 of 18 Pollutant Emission Factors Uncontrolled lb/bbl loaded - Source Benzene 0.0008 PS 14-02 n -Hexane 0.0027 PS 14-02 Public Health and Environment Air Pollution Control Division The uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L = 12.46`S" P" M/T S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 5.4032 psia M (vapor molecular weight) = 40.68 Ib/Ib-mol T (temperature of liquid loaded) = 520 °R Point 005: CAS # Pollutant Uncontrolled Emission Factors (lb/MMSCF) Controlled Emission Factors (lb/MMSCF) Source VOC 80709 4035 Gas Analysis 71432 Benzene 263.835 13.1918 Gas Analysis 108883 Toluene 109.413 5.4706 Gas Analysis 100414 Ethylbenzene 22.4106 1.1205 Gas Analysis 1330207 Xylene 39.2185 1.9609 Gas Analysis 110543 n -Hexane 832.24 41.6120 Gas Analysis 540841 2'2'4 Trimethylpentane 30.1398 1.5070 Gas Analysis 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) 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.qov/ttn/atw/area/fr18ia08.pdf 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, HAPs NANSR Synthetic Minor Source of: VOC, HAPs MACT ZZZZ Major Source Requirements: Not Applicable Area Source Requirements: Applicable AIRS ID: 123/9E9A Page 12 of 18 Public Health and Environment Air Pollution Control Division 9) 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 10) A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at: http://www.colorado.gov/pacific/cdphe/air-permit-self-certification AIRS ID: 123/9E9A Page 13 of 18 Public Health and Environment Air Pollution Control Division 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 a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing compressor 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. AIRS ID: 123/9E9A Page 14 of 18 Public Health and Environment Air Pollution Control Division 2.1.2 The owner or operator may permanently replace the existing compressor 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 http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that "based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at: https://www.colorado.gov/pacific/sites/default/files/AP Portable -Analyzer -Mon itorinq-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. AIRS ID: 123/9E9A Page 15 of 18 Public Health and Environment Air Pollution Control Division For comparison with a short-term limit that is either input based (Ib/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently 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 § 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 As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 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. AIRS ID: 123/9E9A Page 16 of 18 The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. Public Health and Environment Air Pollution Control Division 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 NO X CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 500<Hp July 1, 2007 July 1, 2010 2.0 1.0 4.0 2.0 1.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § I.B (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 AIRS ID: 123/9E9A Page 17 of 18 Public Health and Environment Air Pollution Control Division 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. AIRS ID: 123/9E9A Page 18 of 18 • Internal Combustion En Emission Source AIRS ID: O A ti . r+ ; V E 043 e € V r. a Er ,� .€b a et o d J F O, E ' ass to u F 2. I WL o = .sc O h [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 02 — Requested Action (check applicable request boxes) Section 01 — Administrative Information Request for NEW permit or newly reported emission source Request for coverage under GENERAL PERMIT number GP02 (Natural Gas Only) 17, n. a R i4 0 0 O .o .0 OD u d t E 0. 0 w x 0 z O U O d 7 o• o❑❑ 0 0U zc Verdad Oil and Gas Corporation 0 0 O U 4) O O Change company name ❑ Transfer of ownership Change fuel or equipment Change permit limit ❑ ❑ a) rn 0 'U 0 4) w Request PORTABLE source permit Request APEN Update D N L co o .0T 0 O ZIP Corp: 75235 Emissions data must be completed. Blank APENs will not be accepted. (214) 728-1840 Phone Number: Arthur Beecherl C d E d u aa a N L 0 d C a 0 a w 0 C O Z y `O ❑ QSz Section 03 — General Information For new or reconstructed sources, the projected startup date is: CNI N- 0 v N Natural gas compressor C E C 0 L WU a (4'- C w O 0.04 d > 70- xA L ao oU E W a d 0 N a o al E n N z o, W.g d t N y` y U 0 0. E ti " p C > g 0- O, c ` U w 4 ... bD� 69 C w E ,n OD L O N U h A OD 5 y t dx U L 4) .0 T O 0. O 0 E t o >?� de O. 411 0 c O y C y C E e A w T 0 _o o f �o bb.« ■�� my >>w>o - Et •w V0 L U d 0, 00 .N 0 a w a, q Oil 4' O 8 0 0. L C V] y u 0O O iw .p�t• '0 2 «o' U d de u cn ac 00U,�o,, a°i aXi'.: u5UQ�A For guidance on how to complete this APEN form: 0 0 . N M M M CT N N N S I0 U 0 APEN forms: htto://www.colorado 0 E V 0 ://www.colorado. Application status: htt U, O IN Date the engine was ordered: z N 0 Dare the engine was relocated into Colorado: O A3 ❑ U O r z u a 0 0 c ti C zg .5 1 � � '°a,CO L w 0 0 - 0 E ° W' p U V0' 3 c N 3 C f U, U, N N in date of manufacture: ri) 10CHMM502250021 Model: FX10Q General Motors vinnufacturer: D 0 C 0 U C rjj. 8 0 0 N ti G -C O 0 • 0 g 0 U 0 U w U a C f�l Combustion: U U N O u c C U N a 0. 0 0 0 0 0. 0. a 0. cz .0 'O w w O O 0. 0. 0 U fn O O Cr Cr 0 0 0 0 .D 0 0 0 .0 .0 ❑ ❑ 0 Form APCD-201 -RICEAPEN -V er.02.10.2014.docx FORM APCD-201 • p Internal Combustion En x C 1. G U) Q m a) 6 O. ,CC C L4 aCi CIO > C ♦L • 44 -0 44 O r,y a -r ,d- 0., 0 cy w 4 C � �J F ld WA. > a) y N QJ Q a) z z a © a) H CO c 0,7 00 W 0 H Z O Z E E Q3.0 w a o 0iv P ) a N p 0 7 J 47 f `,4,dct C 11 al with obstructing ra a1 Other: Length nner Diameter (inches) _ • m U L o . Y 43 N .0 _ 4) "a; � OD 4) O 0. o 0 m 7 U] Section 06 — Fuel Consumption Information N Seasonal Fuel Use (%of Annual Use) 0. c N N 0 os d 4) N 0 950.25 (Btu/SCF) 0 0 b 6 ed:Permit Limit 9.81 (MMSCF/yr) O 1,120 (SCF/hr) Natural Gas 0 z C z Estimation Method or Emission Factor Source AP -42 Table 3.2-3 AP -42 Table 3.2-3 AP -42 Table 3.2-3 AP -42 Table 3.2-3 Man Spec Sheet AP -42 Table 3.2-3 Man Spec Sheet AP -42 Table 3.2-3 J AP -42 Table 3.2-3 AP -42 Table 3.2-3 Benzene NA NA NA 0.00158 Ib/MMBtu NA NA ^ _ a, r I NA AP -42 Table 3.2-3 Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Actual Calendar Year Emissions- Emissions • Controlled (Tons/Year Z NA NA Z Z Z 1 NA Controlled Uncontrolled (Tons/Year) (Tons/Year) G b C L ` T, NA NA NA NA NA NA z z [NA NA Uncontrolled (Tons/Year) NA NA NA Z NA VN VN NA NA NA Emission 'Factor Ib/MMBtu lb/MMBtu Ib/MMBtu Ib/MMBtu -'1c 1,1 1nr •-VN 0.0205 0.0205 lb/MMBtu Ib/MMBtu Ib/MMBtu ;Uncontrolled "Basis cr rn 0 0 sr rn 0 0 sr rn 0 0 0.00279 0.00263 "-01 U Y A) J' l U w O' "/ '4,'- �VN VN VN VN VN INA Q z I NA VN VN s y i A o U- ' VN VN VN Z NA NA NA NA NA NA Primary NA NA NA NA NA NA Q z INA VN VN Pollutant TSP PMto O 00.1. XON F ,rnlaldehyde i.:etaldehyde Acrolein S 1T t. N J U a. G L)Q O O U �t O cCd Uy o Y 0c a. O e O O 'y .v) C O 00 W w 0 '- o 3�fl, 'D E N se• w E 7:Y C p e O a� it a u O Y o _C a� .g .0 i u b - Y 'y d C 3 .o O C _ y (4 c 3'� o U C 4., C y O rn C - U N C o ' y 174 'a ±) Y eery O y d N a0 a z arc N 4. .0- O. Y E e O w 0 0 ow C70' Y 7. U '0 ,,,,, (4"e CO duI Lod CJ Y ,N 00 Y L• ;yj > 4) E^ Form APCD-201-RICEAPEN-Ver.02.10.2014.docx N w O N a) 4) Ei Emission Source AIRS ID: Permit Number: C .2 [Provide Facility Equipment ID to identity how this equipment is referenced within you Facility Equipment ID: (Check applicable request boxes) Section 02 — Reauested Action Section 01 — Administrative Information U = F" 00 C 2 0.,© A r W ' __ rJ a a Z E Q❑ on Ill El C a W Q w a, U ° C s47 _> _7 e C c H z to a m U w 0> - z Cr CI L L O w w O 2 0. m m ( ^J CM as a) d 0 0 O a a❑ C2 ❑ C) O ❑ C ° La Change process or equipment Change permit limit APEN Submittal for Permit Exempt/Grandfathered source E .C z a. c = El OD ❑ Meehl 24-2N O 3 0, If1 N N r F 0 Fax Number: 0 N O °z zz ❑'� ❑❑ N 1r `J ar Q — o 0 ° 0 t 4) +. -_ m w •O 1 n 4 Y c o 0 a °a+ .s o a. a ca c, < c C C nCC go N 1. ,>, Lt Ear E o LQ.a Jr-. C mh LL Q, d y E.'> . -c < o Cn o u 5 4 V c T. Q) N 0 c c L 2 O O ON 4� cc zzco L a, m U s Uc• ❑®v o° o S O 8 U o d o cam_ E ° Al y En CC L L:] N a 0 E •° E c ° ° ° N H z •• (5>- > E a N a3 Normal Hours of Source Operation: 0 :O ° } } [SI El ❑ ® ❑ Ti am a, c d) P. o ` d c (, y• C• C) N C h v 0 cd a 0 J = Al 0 o x 7 RI 0 M v3 c o cg) o N 0° cn O U C Cy ..=yO o i o ya. < •E a O di o d "CJ z .cr > ° o 0 O CO C) C C) .Ci co 0 t Y O a a+ c o 2 Lo ° Al E C. -° N oh a ca a 0 c o -F a cu ° ° y ° O OD 0 ° , s'2 _OM 07r o cC v . ° ° 0 C L v c O O c o gc° oo S.o F- ' a y >, . C) I c C) O C i tom. ,2r) et -c N^ a' 0 c<< '00 O 0 0 -0 '' 7,C .y ° _ _ 2 0 ° r C- J .. U U J °=�3� 0(/!) > O C C O :y _ C y o• ° 4 L a c T O 0 0 C c :E > ≥ O 7 L d E >; o a..O o v C cn 0 a Q a on E 0 C e-,1 ^ C •' ° . ° to CL) _ LO C o r L a H5 u •> (.T] O L L C '° cn O• .O O ° �° Lz7 1,=,L -- vN) a, c, ai ar H p O v v, L N yp r orti s L u C.U.. E O m- CC 2 a n..N .< 4 E R 2 Q el v cc u Z OD 5 d a) a) u - . 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L C) Z Name of Well Meehl 24-2N L r. z irm-APCD-205-Condensate Meal 24-2N AP N 0 0 a) CO a O.1 FORM APCD-205 0 0 0D O 0 U Emission Source AIRS ID: Permit Number: 00 0 ❑ 2 C 00 C O 00 N ❑ Make/Model: 2 2 It, used for control of the Stora u 40 40 E 0 U 0 N 00 N A U 0) 0 000 C C 0 L E U a O 40 Emission Control Device 07 0" Ti 4) 40 40 U Manufacture 00 ON a4) N 0 4)) • U m 0 40 0 U a. TTQ •J.n U ET> N N N J 0 U y A 3 I; 0 O c 0i) 9 0 C O ❑U y U U 0- r 0 on ri. = E O 44 E E o g U 0 c 0 0 sed for control o overy Unit (VRU) Y c T 0 N U 17 0. O � C U 2 04 > > 0C -o G `<8 40 7 40 4)) C 000 40 0 C 4-. 0 0 40 O U a) 0) 40 00 h O. O 0 o. .O N U O N. O w 00 E V 0. H 0. L O L = "_ tss L V O CO4° sa �y N 'V s- can 77 vs 0 In = 0 d WI Q. L .0 r%7 a c con O 0 C ++ `rn G00 .... R �e E -E. C L 0 z 0) -r, cf 1 _ •3 J 1 40 r�i 1.23 J 1 5 N 0 O N 0b 0 u C O fga CJ' z a z t• =:I Q z 0\ L d 00 A 0 a O 4_ T En 0 tall ,1 m 00 O 6 y X (i, N y C R u C Y O 0 40 o o c 00 U 0 R 0 O O R _ EVI O L d a) y 0 f.•-• . 4. L .n •i W G °' O _ 04 ;? A ° = G 40 G .0 COc V G V 0 70) I 9V C O a) C 0 r.44 .. m 0 CS I. L 44j U O 0 R m o el I 6I cJ 0. 4.) u c0 C 0 C E en .O y `y sn o 3 e. . et C p N 0 C 0 N rp O 6- h CA N 15 �L E c`44 Vn� 0a ° C.T. C I 0 N N 00 m .-+ 10 C m r--0 w L y •- y 3 0. 67 z w0; a a z z a z z z Q z a z z z z a z z a a_ z z z f�= 1) a Q 1 Q z 0 M 0 x O U 0 O U 0) C 4) 7 0 0 C 0 N 0) .O 4) r 0 C W C v C C a • E N L O 47, cn V C - E ^'� L d 0.1 L W L L u C C 00 W V 6a u a W O. as s h- V 0 C C O Rc 0 = ac W u 6) .0 = y 3 V ,D C a E E s .O 0 u ° u 0 4- - .C W ' E 9 L L a07 Q 0 e 44) 0 0 C W .0 L a 0 .= O 0 W 4V) 0 0 V O E U o z E o V r e0 el V d d u = c " � L u 0-' O C., oU V = L owsw C 0 W 4) Vice President of 0 H 0) O U U 7 0 3 0 O 00 O L N 0 U U 0 n E c 0 O U 0 7 z u 0 U 40 A O -0 •0 � Oo. Z c m ru .0 A a.E E a w wJ oE 0 a 0 w N, .)cu 0 0 9,0 = >+ 0•3 tow E 0611 0 O. 0 0 0 4 G 40 m C) -00 0 O S -C 40 a N 0 a U 0 C 0 L 0D 1 O G C O 0 0 Iu E C) 40 E T C 0 .y 0 z I- F a U O E L o C y 'a. 0 a 40 0 < 01 FORM APCD-205 U) gt c C. a 0 09 Ca 0 To is O C) 4) .O a z :renced within your organization.] [Provide Facility Equipment ID to identity how this equipment is Condensate Loading uested Action (Check applicable request boxes) Section 02 — Re Section 01 — Administrative Information General Permit GP07 Individual Permit El F U C C C 0 u, dl Verdad Oil and Gas Corporation Lz F O L O F O d E�wU U c[AZ �T- w5UO z ,o 7 d d m d C 0 d C C u aate) Q' Ccdtad❑❑ El ❑ ❑ ❑ C) U lc 7 o. F. 0 U ,0 OG 1 CS O ❑ ❑ Change process or equipment Change permit limit CO Meehl 24-2N y F U 0 SWSE S24 T1N R65W C Z z 0 U O _ O. C - .) = H _ — _ fi L y a. U a a) O U 5950 Cedar Springs Road, Suite 200 0) N O )n Cl m F- (6 16 a Request to limit HAPs with a Federally enforceable limit on PTE N C - r O C) a N Arthur Beecherl VrdadOil.com r 0 Addl. Info. & Notes: Fax Number: (214) 728-1840 Sectidn 03 — General Information 0 Cl U O N Normal Hours of Source Operation: 0 0 N O N 0 Loadout for tank trucks v (0 C 770_ 0. C C n. ti C uL v, 5 0 , ti n Don't know Don -t I(n01v' Don't kno\\ Don't know 2 z Z z z } >- >••• �} >- ED ODD ill less than 6750 BBL of condensate per year C. • O C• 0 7,3 d C 'O a) U s.- 0 U > 0 4 U Cn 0 )z 0 • 2 = ed c 00 0 ct c o ▪ (1) o C, • O O J 0 • 44 • " rn O sc -77 - 0 o • - 0 a 0 U +-' ,0 • L h r+ - C R r 0 O v • "C — 77 •- • U U y O O U c p • v U - U C • '' . o • = 0 n o a o U U O- 0 4-7 Q, E a C 0 n v C a 7 - — 3 c z C) a 0 U per ADEN & O • j N L C e0+ > EAC w R s - E 6 4- r b. c o C d U bi E E V ee 2 U 2 ,C C) C1 Cr) Cl N N C' am c\ 0 0 C') o O O 0 fg- O O U A ♦ ♦ ♦ . cc/JD L s_ O O CJ O Condensate a Product Loaded: C) 40 0 0 Cl; O C 0 d U a E v II w 0 d Up A a0 L V.i 0- ›- L C) A • Ea CC C C) y U «S C U C 1- C co 1- O U C VI 0 00 C C0 2 d sls -49 0 E U 0 C L 2 c0 0 z 0 E ao C u C 0 d 0 0 O m O m CC C c CZ > • v - • E � N a-+ d b0 C 3 0n U C C. - b0 0 0 0 m 2 ' C) 0 d Cr Cl C) U ^.) • V.) H r C • FORM APCD-208 Form APCD-203-HydrocarbonLiquidLoadineAPEN-Vcr.4-I4-2014 ( 0 O CG a uid Loadin O d t Cy "CJ O 0 u U O A = y � C v O C O CID u O •,1 O vn � W . O U N N 0, 4-J En O EEn m C U C an O En z amF Qu zo a o yR E a at 42 *.•;4 CCcop Vl O O U d d O - Other (Describe): Width (inches) = O ❑ J 00 'Z O O ❑ ❑ Vertical with obstructing rainc O d r. W o E C y� a� r C v C O u Ncu .d qy N a o on O L) N v a t` 5 = O i Q [a Section 08 — Emissions Inventory Information O O CO 0o O O O E d O. C O 7- C O G O C. O L. O a E c. C L d C d Cu d C. a O C C O N V C Cl) y N m m O u O Condensate Ca Ca .O 00 co C O N N on CO CO tn C O 0 0 7 u C O O bL Cf C: U C/) C C. DID O t df C O C .O 0 .N E 41, 7 C C C U C r C L 3- u C C O C.1 CO C O E d V Zr u a d 10 C En C O yC C m C O C E C O 0 u [L C O .N • E W Estimation Method or Emission Factor Source N/A AP -42, E&P Tanks N/A E&P Tanks E&P Tanks Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions Controlled (Tons/Year) V/N V/N V/N V/N V/N Uncontrolled (Tons/Year) 1 V/N 2.Z 2. V/N M Lf) O 0 N- O Actual Calendar Year Emissions5 Controlled (Tons/Year) N/A N/A N/A N/A N/A Uncontrolled (Tons/Year) V/N VN VN V/N VN Emission Factor 76 Ta To In Q o Q o O C 0 a \ G O z O Uncontrolled Basis V/N 3.16 N/A CO r- 0 O O O O_ Control Efficiency (% Reduction) Identify in Section 07 Control Device Description Primary Secondary VOC FO 0 u c 0) Z 0 . 0 C O r 00 F u L O "O C t CO o d 7. r� y E t a a E `° V C d C 0 C bD O W C O O. O. -o CO C co u w C u .3 d O • d+ = d E c C C h� C E O O u C E w.E c C CO C I. C o d o L d d .L C \\ G C C ^` O m \V C.• • d i 0 O C CO) 0. C C d bL 0 C CC—C O V u .3 VP of Operations Arthur Beecherl N O N on C 4) Name of Legally Authorized Person (Please print) C C > 0. C N • 0 C) Q C O Emission Source AIRS Ill: [Leave blank unless APCD has already assigned a permit # & AIRS ID] 16/E0775 Permit Number: [Provide Facility Equipment ID to identity how this equipment is referenced within your organization.] co O a) Facility Equipment ID: uested Action (check applicable request boxes) Section 02 — Re Section 01 — Administrative Information Request for NEW permit or newly reported emission source :a 7 V 1C u V V V N C z H A tu cr U O 'C U U zc7 Verdad Oil and Gas Corpo Meehl 24-2N c) 0 z z C U G cr Change company name U O ❑ Transfer of ownership ❑ ❑ Change fuel or equipment Change permit limit ❑ ❑ Request to limit HAPs with a Federally enforceable limit on PTE Request APEN update only (check the box below that Li+ N Cl.) O CO) in C'74 LO O .n U.� C U W N SWSE 524 Ti N R65W Source Location: 5950 Cedar Springs Road, Suite 200 N O Arthur Beecherl Person To Contact: Fax Number: ABeecheri@VerdadOil.com Section 03 — General information CO O CV O O For new or reconstructed sources, the projected startup date is: N Pi y N- N C C C to • 0 e O C. C ai ) ✓ G U C o !/] L c x 0 °z Produced gas venting from separators to Emission Control Device during Maintenance/Startup/Shutdown (5% of the year) For guidance on how to complete this APEN Form: O OO • ,7' r--� a) N N cy O O, M M M C) O O O G ^G C. 7 • U O- 77 00 d - O o ti o ° C C 5 > C z E CO 'C 7;-): G O C O M U � _ 0o a) g Q — ti 3 E. ment Information C Section 04 — Processin Description of Source: Gas/liquid Separator U40 CO G � U C) c) a) 'O 'O O C C 0. a) E C C 0. O ❑ ® ❑ ❑ ❑ ❑ a). S O:: 4� CO. lv G. U C. Process Parameters: S. o'. 01 a xC b " CD co ai-u 0 O CO O O v O d G'G' CO CNI U'= o 5 C U O m O CO O 7 ,S C U - C U n � = G C O 0 ta C) a) O: V CO C O U U a) a) o G X X U U CJ • U ❑ ❑X FonnAPCD-2I I-NaturalGasVenlingAPEN-Ver.10-14-2013 docx FORM APCD-211 Emission Source AIRS ID: Section 06 —Stack (Source, if no combustion) Location (Datum & either L n/Long or UTM) L W C CD -104.608411 N- N CA cn O CO Q z 4 o •7:5' Z O C/) 0- -,(13 C O C O O a w z UI IZ Q O E U) 0. C CO a) CD a) 0) O 0 n U 0 N y E W N ¢) z O a) 130 a) ❑ Vertical with obstructing raincap ❑ Ve :k one): ❑ Direction of stack outlet (cheek one): Section 07 — Control Device Information Section 08 — Emissions Inventory Information & Emission Control Information Estimation Method or Emission Factor Source Site Specific II N 7 d a I AP -42 II SOx ECD 100 95 -- -- -- — -- -- No S in Gas Benzene ECD 100 95 C..32 1 lb/MMscf -- - ;'- 1l' _ Site Specific Toulene ECD 100 95 Oei. q i lb/MMscf -- -- d'f ! Site Specific Ethylbenzene ECD 100 95 _ k.:Z,'11oC- lb/MMscf -- -- 00;" p Site Specific Xylene ECD 100 95 I. 1,47.O.5 Ib/MMscf -- -- - _ Site Specific n -Hexane ECD 100 95 032.0 Ib/MMscf -- -- d V I C' Site Specific Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions Controlled (Tons/Year) d O 1.54 Uncontrolled (Tons/Year) --. r1 , Actual Calendar Year Emissions4 Controlled (Tons/Year) I , Uncontrolled (Tons/Year) Emission Factor Units 2 2 35 lb/MMBtu lb/MMBtu Uncontrolled Basis 0- C e co o 0.37 Control Efficiency (% Reduction) L0 C) 1.11 C) 95 Overall Collection Efficiency 0 0 C 0 Control Device Description Priinmiy Secondary ECD ECD ECD Pollutant. VOC NOx 0 0) H 3gAPliN-Ver.10-14-2013 docx rmAPC: D-21 I -Natu ralGms V N O c•I a) C FORM APCD-211 Hello