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Home My WebLink About20192110.tiffRc ►00 U/(2/19 COLORADO Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150 0 St PO Box 758 Greeley, CO 80632 May 30, 2019 Dear Sir or Madam: RECEIVED JUN 0 4 2010 WELD COUNTY COMMISSIONERS On June 6, 2019, the Air Pollution Control Division will begin a 30 -day public notice period for Bill Barrett Corporation - Anschutz Equus Farms 4-62-28 NWNW. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer cc: PLLTP) HLCJT�, AWCJ'\ jcNlclh) C9ILlltct 2019-2110 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Bill Barrett Corporation - Anschutz Equus Farms 4-62-28 NWNW - Weld County Notice Period Begins: June 6, 2019 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: Bill Barrett Corporation Facility: Anschutz Equus Farms 4-62-28 NWNW Wellpad Facility NWNW SEC 28 T4N R62W Weld County The proposed project or activity is as follows: Engines, Tanks, and Loadout equipment 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 18WE0228 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Comments may be submitted using the following options: • Use the web form at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices. This page also includes guidance for public participation • Send an email to cdphe.commentsapcd@state.co.us • Send comments to our mailing address: Timothy Sharp Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 1 I A�COLORADO � . Public Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Timothy Sharp Package tt: 375836 Received Date: 3/2/2018 Review Start Date: 5/2/2.018 Section 01 - Facility Information Company Name: Bill Barrett Corporation County AIRS ID: 123 Quadrant Section Township Range NWNW Z3 `: Plant AIRS ID: Facility Name: Physical Address/Location: County: 9F6A Anschutz Equus Farms 4-62-28 NWNW NWNW quadrant of Section 28, Township 4N, Range 62W Weld County Type of Facility: Exploration & Production Well Pad What industry segment? Oil & Natural Gas Production & Processing Is this facility located in a NAAQS non -attainment area? Yes If yes, for what pollutant? ❑ Carbon Monoxide (CO) Section 02 - Emissions Units In Permit Application Particulate Matter (PM) Q Ozone (NOx & VOC) AIRs Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance At Self Cert Required? Action Engineering Remarks 002 Natural Gas RICE C -13678/1A/1 Yes 18WE0234 1 Yes Permit Initial Issuance 003 Natural Gas RICE C-12839/1 Yes 18WE0233 1 Yes Permit Initial Issuance 005 Natural Gas RICE C-14789/1 Yes 18WE0236 _ Yes Permit Initial Issuance 006 Liquid Loading TL -Comp Tank Yes 18WE0228 a Yes Permit Initial Issuance 007 Liquid Loading TL- Prod Tank Yes 18WE0229 I_ Yes Permit Initial Issuance 008 Produced Water Tank PW Tank Yes 18WE0230 a Yes Permit Initial Issuance 009 Condensate Tank Comp Tank Yes 18WE0231 1 Yes Permit Initial Issuance 010 Condensate Tank Prod Tank Yes 18WE0232 1 Yes Permit initial Issuance Section 03 - Description of Project New well pad facility. email requesting detail on use of 0.6 g/hp-hr NOx factor instead of 0.7 factor I sted for catalyst. >> applicant has requested testing to confirm emission factors. • Section 04 - Public Comment Requirements Is Public Comment Required? Yes If yes, why? Greater than 25 tons per year in Non -Attainment Area Section 05 - Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? No If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? 'YES If yes, indicate programs and which pollutants: SO2 NOx CO VOC PM2.S PM10 TSP HAPs Prevention of Significant Deterioration (PSD) O E O C ❑ ❑ Title V Operating Permits (OP) O 0 El ❑✓ O O O O Non -Attainment New Source Review (NANSR) El El Is this stationary source a major source? If yes, explain what programs and which pollutants hen5O2 NOx CO VOC PM2.5 PM10 TSP HAPs Prevention of Significant Deterioration (PSD) O O O O O O Title V Operating Permits (OP) O 0 O ❑ ❑ ❑ ❑ El Non -Attainment New Source Review (NANSR) O 0 Hydrocarbon Loadout Emissions Inventory 006 Liquid Loading Facility Al Rs ID: 123 County 916A Plant 006 Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Is this loadout controlled? Collection Efficiency: Control Efficiency: Hydrocarbon liquid Loadout into Trucks ECD Yes 100.0 95 Requested Overall VOC & HAP Control Efficiency %: 95.00 Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Hydrocarbon Loadout Actual Volume Loaded = 36,710 Barrels (bbl) per year Actual Volume Loaded While Emissions Controls Operating = 36,710 Barrels (bbl) per year Requested Permit Limit Throughput = 44,051 Barrels (bbl) per year Requested Monthly Throughput = 3741 Barrels (bbl) per month Potential to Emit (PTE) Volume Loaded = Secondary Emissions - Combustion Device(s) Heat content of waste gas = Volume of waste gas emitted per year = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = 44,052 Barrels (bbl) per year 2520 Btu/scf 83528 scf/year Potential to Emit (PTE) heat content of waste gas routed to combustion device = Section 04 - Emissions Factors & Methodologies Does the company use the state default emissions factors to estimate emissions? Are the emissions factors based on a stabilized hydrocarbon liquid sample drawn at the facility being permitted? Loading Loss Equation L = 12.46*S*P*M/T 175 MMBTU per year 210 MMBTU per year 210 MMBTU per year Yes The stabilized hydrocarbon liquid sample is valid for developing site specific emissions factors. Factor Meaning Value Units Source S Saturation Factor 0.6 AP -42 Chapter 5.2 Table 5.7--1 Submerged Loading: Dedicated Normal Service (S=0.6) P True Vapor Pressure 8.16 psia E&P Tanks M Molecular Weight of Vapors 60 Ib/Ib-mo► T Liquid Temperature 512.12 Rankine L Loading Losses 7.147249863 lb/1000 gallons 0.300184494 lb/bbl Component Mass Fraction Emission Factor Units Source Benzene 0 lb/bbl Toluene 0 lb/bbl Ethylbenzene 0 lb/bbl Xylene 0 lb/bbl n -Hexane 0.01959 0.005880614 Ib/bbl 224 TMP 0 lb/bbl Emission Factors Hydrocarbon Loadout Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) Emission =actor Source (Volume Loaded) (Volume Loaded) VOC 3.00E-01 1.50E-02 Benzene 0.00E+00 0.00E+00 Toluene 0.00E+00 0.00E+00 Ethylbenzene 0.00E+00 0.00E+00 Xylene 0.00E+00 0.00E+00 n -Hexane 5.88E-03 2.94E-04 224 TMP 0.00E+00 0.00E+00 Pollutant Control Device Emission Factor Source Uncontrolled Uncontrolled (lb/MMBtu) (lb/bbl) (waste heat combusted) (Volume Loaded) PM 10 0.00E+00 AP -42 Chapter 13.5 Industrial Flares (NOx) AP -42 Chapter 133 in dutstrial Flares (CO) PM 2.5 0.00E+00 SOx 0.00E+00 NOx 0.0680 3.25E-04 CO 0.3100 1.48E-03 2 of 16 K:\PA\2018\18WE022818WE0229 18WE0230 18WE0231 18WE0232.CP1.xlsm Hydrc carbon Loadout Emissions Inventory Section OS - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncoitrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) PM 10 PM2.5 SOx NOx VOC CO 0.00 0.00 0.00 100 0.00 0 0.00 0.00 0.00 :.00 0.00 0 0.00 0.00 0.00 :.00 0.00 0 0.01 0.01 0.01 =.01 0.01 1 6.61 5.51 0.28 E.61 0.33 56 0.03 0.03 0.03 :.03 0.03 6 Hazardous Air Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (Its/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 259 216 11 259 13 0 0 0 0 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit RACT- Regulation 3, Part B, Section III.D.2.a The loadout must be operated with submerged fill to satisfy RACT. (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction eff ziency of the combustion Section 08 - Technical Analysis Notes Na device based on inlet and outlet oncentration sampling The factors derived are higher than the state default factors. Since the AP -42 method is used these factors are deemed reliable and conservative. • Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 006 Process # 01 SCC Code 4-06-001-32 Crude Oil: Submerged Loading Normal Service (S=0.6) Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons transferred PM2.5 0.00 0 lb/1,000 gallons transferred SOx 0.00 0 lb/1,000 gallons transferred NOx 0.01 0 lb/1,000 gallons transferred VOC 7.1 95 Ib/1,000 gallons transferred CO 0.04 0 lb/1,000 gallons transferred Benzene 0.00 95 lb/1,000 gallons transferred Toluene 0.00 95 lb/1,000 gallons transferred Ethylbenzene 0.00 95 lb/1,000 gallons transferred Xylene 0.00 95 lb/1,000 gallons transferred n -Hexane 0.14 95 lb/1,000 gallons transferred 224 TMP 0.00 95 lb/1,000 gallons transferred 3 of 16 K:\PA\2018\18WE0228 18WE0229 18WE0230 18WE0231 18WE0232.CP1.xlsm Hydrocarbon Loadout Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements Source is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section II.D.1.I)? 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? 4. Is the loadout operation loading less than 5,750 bbls per year of condensate via splash fill? 5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 6. Are total facility uncontrolled VOC emissions greater than S TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section You have indicated that source is in the Non -Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section II.D.1.I)? 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? 4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill? 5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 6. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Sectic Source requires a permit 7. RACT - Are uncontrolled VOC emissions from the loadout operation greater than 20 tpy (Regulation 3, Part B, Section III.D.2.a)? The loadout must be operated with submerged fill to satisfy RACT. Disclaimer and Air Quality Control Commission regulations. This document is not a rule or regulation. and the analysis it contains may not apply to a particular situation based upon the indhvidual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as -recommend," "may,- "should." and "can.- is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations. but this document does not HydrDcarbon Loadout Emissions Inventory 007 Liquid Loading 'Facility AIRs ID: 12-; 9F6A 007 County Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Is this loadout controlled? Collection Efficiency: Control Efficiency: Hydrocarbon Liquid Loading into Trucks ECD Yes 100.0 95 Requested Overall VOC & HAP Control Efficiency %: 95.00 Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Hydrocarbon Loadout Actual Volume Loaded = 1,226,000 Barrels (bbl) per year Actual Volume Loaded While Emissions Controls Operating = 1,226,000 Barrels (bbl) per year Requested Permit Limit Throughput = 1,471,200 Barrels (bbl) per year Requested Monthly Throughput = 124951 Barrels (bbl) per month Potential to Emit (PTE) Volume Loaded = Secondary Emissions - Combustion Device(s) Heat content of waste gas = Volume of waste gas emitted per year = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = 1,471,200 Barrels (bbl) per year 2519.52 Btu/scf 1519135 scf/year Potential to Emit (PTE) heat content of waste gas routed to combustion device = Section 04 - Emissions Factors & Methodologies Does the company use the state default emissions factors to estimate emissions? Are the emissions factors based on a stabilized hydrocarbon liquid sample drawn at the facility being permitted? Loading Loss Equation L = 12.46*S*P*M/T 3,190 MMBTU per year 3,827 MMBTU per year 3,827 MMBTU per year Yes fThe stabilized hydrocarbon liquid sample is valid for developing site specific emissions factors. ill Factor Meaning Value Units Source S Saturation Factor 0.6 , '; - AP 42 Chapter 5.2 Table 5.2-1 Submerged Loading: Dedicated Normal Service (5=0.6) P True Vapor Pressure 4.4465 psia E&P Tanks M Molecular Weight of Vapors 67 Ib/Ib-mol T Liquid Temperature 512.45 Rankine L Loading Losses 4.34621188 lb/1000 gallons 0.182540899 lb/bbl Component Mass Fraction Emission Factor Units Source Benzene 0.00177 0.000323097 lb/bbl Toluene 0 lb/bbl Ethylbenzene 0 lb/bbl Xylene 0 lb/bbl n -Hexane r "268 0.002362241 lb/bbl 224 TMP 0 lb/bbl Emission Factors Hydrocarbon Loadout Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) Emission :actor Source (Volume Loaded) (Volume Loaded) VOC 1.83E-01 9.13E-03 Site Specific - AP -42: C Yapter 5.2, Equation 1 Benzene 3.23E-04 1.62E -0S Toluene 0.00E+00 0.00E+00 Ethylbenzene 0.00E+00 0.00E+00 Xylene 0.00E+00 0.00E+00 n -Hexane 2.86E-03 1.43E-04 224 IMP 0.00E+00 0.00E+00 Control Device Emission Factor Source Uncontrolled Uncontrolled Pollutant (lb/MMBtu) (lb/bbl) (waste heat combusted) (Volume Loaded) PM10 0.00E+00 AP -42 Chapter 13.5 In:lustrlal Flares (NOxj AP -42 Chapter 133 In Austrial Flares (CO) PM 2.5 0.00E+00 SOx 0.00E+00 NOx 0.0680 1.77E-04 CO 0.3100 8.06E-04 5 of 16 K:\PA\2018\18WE0228 18WE0229 18WE0230 18WE0231 18WE0232.CP1.xlsm Hydrocarbon Loadout Emissions Inventory Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (toes/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) PM10 PM2.5 SOx NOx VOC CO 0.00 0.00 0.00 0.00 0.00 0 0.00 0.00 0.00 0.00 0.00 0 0.00 0.00 0.00 0.00 0.00 0 0.13 0.11 0.11 0.13 0.13 22 134.28 111.90 5.59 134.28 6.71 1140 0.59 0.49 0.49 0.59 0.59 101 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (Its/year) (lbs/year) RE quested Permit Limits Uncontrolled Controlled (Its/year) (lbs/year) Benzene 475 396 20 475 24 Toluene 0 0 0 0 0 Ethylbenzene 0 0 0 0 0 Xylene 0 0 0 0 0 n -Hexane 4211 3509 175 4211 211 224 TMP 0 0 0 0 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Not enough information RACT - Regulation 3, Part B, Section III.D.2.a The loadout must operate with submerged fill and loadout emissions must be routed to flare to satisfy RACT. (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes >v n• 'i;14%;i: Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 007 Process # 01 SCC Code 4-06-001-32 Crude Oil: Submerged Loading Normal Service (S=0.6) Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons transferred PM2.5 0.00 0 lb/1,000 gallons transferred SOx 0.00 0 lb/1,000 gallons transferred NOx 0.00 0 lb/1,000 gallons transferred VOC 4.3 95 Ib/1,000 gallons transferred CO 0.02 0 Ib/1,000 gallons transferred Benzene 0.01 95 Ib/1,000 gallons transferred Toluene 0.00 95 lb/1,000 gallons transferred Ethylbenzene 0.00 95 lb/1,000 gallons transferred Xylene 0.00 95 lb/1,000 gallons transferred n -Hexane 0.07 95 lb/1,000 gallons transferred 224 TMP 0.00 95 lb/1,000 gallons transferred 6 of 16 K:\PA\2018\18WE0228 18WE0229 18WE0230 18WE0231 18WE0232.CP1.xlsm Hydrocarbon Loadout Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements Source is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section II.D.1.I)? 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? 4. Is the loadout operation loading less than 5,750 bbls per year of condensate via splash fill? 5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 6. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section You have indicated that source is in the Non -Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section II.D.1.I)? 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? 4. Is the loadout operation loading less than 5,750 bbls per year of condensate via splash fill? 5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 6. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Sectic Not enough information 7. RACT - Are uncontrolled VOC emissions from the loadout operation greater than 20 tpy (Regulation 3, Part B, Section III.D.2.a)? The loadout must operate with submerged fill and loadout emissions must be routed to flare to satisfy RACT. Disclaimer and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation. or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend." "may." "should." and "can," is intended to describe APCD interpretations and recjmmendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations. but this document does not Produced Water Storage Tank(s) Emissions Inventory 008 Produced Water Tank Facility AIRs ID: County 008 Plant Point Section 02 - Equipment Description Details Detailed Emissions knit Description: 4x400 bbl Fixed roof atmospheric storage tank(s) for Produced Water Emission Control Device ECD Description: Requested Overall V & HAP Control Efficiency %: 95 Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Produced Water Throughput = 915,000 Barrels (bbl) per year Actual Produced Water Throughput While Emissions Controls Operating = 915,000 Requested Permit Limit Throughput = 1,098,000 Barrels (bbl) per year Requested Monthly Throughput = 93255 Barrels (bbl) per month Potential to Emit (PTE) Produced Water Throughput = Secondary Emissions - Combustion Device(s) Heat content of waste gas = Volume of waste gas emitted per BBL of liquids produced = 2 scf/bbl Actual heat content Df waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device 1,098,000 Barrels (bbl) per year 1064 Btu/scf 1,947 MMBTU per year 2,337 MMBTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 2,337 MMBTU per year Section 04 - Emissions Factors & Methodologies Will this storage tank emit flash emissions? Emission Factors Produced Water Tank Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) Emission Factor Source (Produced Water Throughput) (Produced Water Throughput) VOC 0.024 C,..:;0 Site Specific E.F. (includes flash Benzene 0.000 0.000 Site Specific E.F. (includes flash Toluene 0.000 Ethylbenzene 0.000 Xylene 0.000 n -Hexane 0.000 Site Specific E.F, (includes flash 224 TMP 0.000 Pollutant Control Device Uncontrolled Uncontrolled (lb/MMBtu) (lb/bbl) Emission Factor Scurce (waste heat combusted) (Produced Water Throughput) PM10 10 0.0000 AP -42 Chapter 13.5 Industrial F aces (NOx) AP -42 Chapter 13.5 Industrial F aces (CO) PM2.5 0.0000 NOx 0.0680 0.0001 CO 0.3100 0.0007 Section 05 - Emissions Inventory Criteria Pollutarts Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requeste: Permit Limits Uncontrolled Controlled (tons/year (tons/year) Requested Monthly Limits Controlled (lbs/month) VOC P M 10 PM2.5 12.9 10.8 0.5 12.9 0.6 110 0.0 0.0 0.0 0.0 0.0 0 0.0 0.0 0.0 0.0 0.0 0 NOx 0.1 0.1 0.1 0.1 0.1 13 CO 0.4 0.3 0.3 0.4 0.4 62 Hazardous Air Pollr.tants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requeste: Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene 373 311 16 373 19 Toluene 0 0 0 0 0 Ethylbenzene 0 0 0 0 0 Xylene 0 0 0 0 0 n -Hexane 1197 997 50 1197 60 224 TMP 0 0 0 0 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XVII.B, C.1, C.3 Storage tank is subject to Regulation 7, Section IVII, B, C.1 & C.3 Regulation 7, Section XVII.C.2 Storage tank is subject to Regulation 7, Section 1(VII.C.2 Regulation 6, Part A NSPS Subpart OOOO Storage Tank is not subject to NSPS OOOO (See regulatory applicability worksheet for detailed analysis) 8 of 16 K:\PA\2018\18WE0228 18WE0229 18WE0230 18WE0231 18WE0232.CP1.xlsm Produced Water Storage Tank(s) Emissions Inventory Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid water sample drawn at the facility being permitted and analyzed using flash liberation analysis? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. Yes If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor. See PS Memo 14-03, Questions 5.9 and 5.12 for additional guidance on testing. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes Flash liberation analysis used to support emissions calculations Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 008 Process # SCC Code 01 4-04-003-15 Fixed Roof Tank, Produced Water, working+breathing+flashing losses Pollutant PM10 PM2.5 NOx VOC CO Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP Uncontrolled Emissions Factor 0.00 0.00 0.00 0.6 0.02 0.01 0.00 0.00 0.00 0.03 0.00 Control % 0 0 0 95 0 95 95 95 95 95 95 Units Ib/1,000 gallons Ib/1,000 gallons lb/1,000 gallons Ib/1,000 gallons lb/1,000 gallons Ib/1,000 gallons lb/1,000 gallons Ib/1,000 gallons Ib/1,000 gallons lb/1,000 gallons lb/1,000 gallons liquid throughput liquid throughput liquid throughput liquid throughput liquid throughput liquid throughput liquid throughput liquid throughput liquid throughput liquid throughput liquid throughput 9 of 16 K:\PA\2018\18WE0228 18WE0229 18WE0230 18WE0231 18WE0232.CP1.xlsm Produced Water Storage Tank Regulatory Analysis Worksheet Please note that NSPS Kb might be might be applicable for certain tanks at water management and injection facilities. If the tanks you are review ng are at one of these facilities, please review NSPS Kb. Colorado Regulation 3 Parts A and B - APEN and Permit Requirements Source is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the operator claiming less than 1% crude oil and is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1.M) 3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? You have indicated that source is in the Non -Attainment Area Yes NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the operator claiming less than 1% crude oil and is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1.M) 3. Are total facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.2)? No Yes Source requires a permit Colorado Regulation 7, Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this produced water storage tank' located at an oil and gas exploration and production operation , well production facility, natural gas compressor stationior natural gas processing plant? 3. Is this produced water storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions'of this storage tank equal to or greater than 6 tons per year VOC? No Yes Yes Yes Storage tank is subject to Regulation 7, Section XVII. B, C.1 & C.3 Section XVII.B — General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.C.1 - Emissions Control and Monitoring Provisions Section XVII.C.3 - Recordkeeping Requirements 5. Does the produced water storage tank contain only "stabilized" liquids? If no, the following additional provisions apply. No Storage tank is subject to Regulation 7, Section XVII.C.2 Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart OOOO, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Is this produced water storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this produced water storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015? 3. Are potential VOC emissions from the individual storage vessel greater than or equal to 6 tons per year? 4. Does this produced water storage vessel meet the definition of "storage vessel"' per 60.5430? Yes No Storage Tank is not subject to NSPS OOOO Subpart A, General Provisions per §60.5425 Table 3 §60.5395 - Emissions Control Standards for VOC §60.5413 - Testing and Procedures §60.5395(g) - Notification, Reporting and Recordkeeping Requirements §60.5416(c) - Cover and Closed Vent System Monitoring Requirements §60.5417 - Control Device Monitoring Requirements (Note: If a storage vessel is previously determined to be subject to NSPS OOOO due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS OOOO per 60.5365(e)(2) even if potential VOC emissions drop below 6 tons per year) RACT Review RACT review is required if Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets both criteria, then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations_ This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. in the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations" the language of the statute or regulation will control The use of non -mandatory language such as 'recommend,- 'may." 'should,- and -can, is intended to describe APCD interpretations and recommendations Mandatory terminology such as "must' and 'required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. Source Req Go to next Source Req Continue - Continue - Gotothen Source is st. Source is su Continue - Storage Tar Condensate Storage Tank(s) Emissions Inventory 009 Condensate Tank !FacilityAIRs ID: 123 County 9F6A Plant 009 Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: 4x400 bbl Fixed roof condensate storage tank ecd 95 Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Condensate Throughput = 36,710 Barrels (bbl) per year Actual Condensate Throughput While Emissions Controls Operating = 36,710 Barrels (bbl) per year Requested Permit Limit Throughput = 44,051 Barrels (bbl) per year Requested Monthly Throughput = 3731 Barrels (bbl) per month Potential to Emit (PTE) Condensate Throughput = Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per BBL of liquids produced = 0.0067 m3/I Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = 44,052 Barrels (bbl) per year 2746 Btu/scf Potential to Emit (PTE) heat content of waste gas routed to combustion device = Section 04 - Emissions Factors & Methodologies Will this storage tank emit flash emissions? Yes 9,170 MMBTU per year 11,004 MMBTU per year 11,004 MMBTU per year Emission Factors Condensate Tank Emission Factor Source Uncontrolled Controlled Pollutant (lb/bbl) (lb/bbl) (Condensate Throughput) (Condensate Throughput) VOC 6.17 0.31 . Specific E.F. (includes flash) Benzene 0.015 0.001 Toluene 0.009 0.000 Ethylbenzene 0.000 Xylene 0.000 n -Hexane 0.006 224 TMP 0.000 Control Device Emission Factor Source Uncontrolled Uncontrolled Pollutant (lb/MMBtu) (lb/bbl) (waste heat combusted) (Condensate Throughput) PM10 0.0000 AP -42 Chapter 13.5 Industrial Flares (NOx) AP -42 Chapter 13.5 Industrial Flares (CO) PM2.5 0.0000 NOx 0.0680 0.0000 CO 0.3100 0.0000 Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) VOC PM10 PM2.5 NOx CO 135.9 113.3 5.7 135.9 6.8 1154 0.0 0.0 0.0 0.0 0.0 0 0.0 0.0 0.0 0.0 0.0 0 0.4 0.3 0.3 0.4 0.4 64 1.7 1.4 1.4 1.7 1.7 290 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 639 532 27 639 32 410 341 17 410 20 0 0 0 0 0 0 0 0 0 0 5617 4681 234 5617 281 0 0 0 0 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Not enough information Regulation 7, Section XII.C, D, E, F Storage tank is subject to Regulation 7, Section XII.C-F Regulation 7, Section XII.G, C Storage Tank is not subject to Regulation 7, Section XII.G Regulation 7, Section XVII.B, C.1, C.3 Storage tank is subject to Regulation 7, Section XVII, B, C.1 & C.3 Regulation 7, Section XVII.C.2 Storage tank is subject to Regulation 7, Section XVII.C.2 Regulation 6, Part A, NSPS Subpart Kb Storage Tank is not subject to NSPS Kb Regulation 6, Part A, NSPS Subpart OOOO Storage Tank is not subject to NSPS OOOO Regulation 8, Part E, MACT Subpart HH Storage Tank is not subject to MACT HH (See regulatory applicability worksheet for detailed analysis) 11 of 16 K:\PA\2018\18WE0228 18WE0229 18WE0230 18WE0231 18WE0232.CP1.xlsm Condersate Storage Tank(s) Emissions Inventory Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use the state default emissions factors to estimate emissions? If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction eff ciency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes Section 09 - Inventory SCC Coding and Emissions Factors v..wv...�.o4w�: .l.n..:k.tiu:......64.:....c:...i.e....-r:.:.c ;—+.a -�:L _�.w........_ AIRS Point # 009 Process # SCC Code 01 74,44:403-11 Fixed f oof Tank, Condensate, workinctbreatiting+ Uncontrolled Emissions Pollutant Factor Control% Units PM10 0.00 0 lb/1,000 gallons condensate throughput PM2.5 0.00 0 lb/1,000 gallons condensate throughput NOx 0.40 0 lb/1,000 gallons condensate throughput VOC 146.9 95 lb/1,000 gallons condensate throughput CO 1.84 0 lb/1,000 gallons condensate throughput Benzene 0.35 95 lb/1,000 gallons condensate throughput Toluene 0.22 95 lb/1,000 gallons condensate throughput Ethylbenzene 0.00 95 Ib/1,000 gallons condensate throughput Xylene 0.00 95 lb/1,000 gallons condensate throughput n -Hexane 3.04 95 Ib/1,000 gallons condensate throughput 224 TMP 0.00 95 Ib/1,000 gallons condensate throughput 12 of 16 K:\PA\2018\18WE0228 18WE0229 18WE0230 18WE0231 18WE0232.CP1.xlsm Condensate Tank Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements Source is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? You have indicated that source is in the Non -Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo ta5-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.2)7 Y NA Yes Not enough information Colorado Regulation 7. Section XII.C-F 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at an oil and gas exploration and production operation', natural gas compressor station or natural gas drip station? 3. Is this storage tank located upstream of a natural gas processing plant? Yes Yes Yes Storage tank is subject to Regulation 7, Section XII.C-F Section XII.C.1 —General Requirements for Air Pollution Control Equipment — Prevention of Leakage Section XII.C.2 — Emission Estimation Procedures Section XII.D — Emissions Control Requirements Section XII.E — Monitoring Section XII.F — Recordkeeping and Reporting Colorado Regulation 7. Section XII.G 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at a natural gas processing plant? 3. Does this storage tank exhibit "Flash" (e.g. storing non -stabilized liquids) emissions and have uncontrolled actual emissions greater than or equal to 2 tons per year VOC? Yes No NA Storage Tank is not subject to Regulation 7, Section XII.G Section XII.G.2 - Emissions Control Requirements Section XII.C.1 — General Requirements for Air Pollution Control Equipment — Prevention of Leakage Section XII.C2 — Emission Estimation Procedures Colorado Regulation 7. Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this condensate storage tank' located at an oil and gas exploration and production operation , well production facility2, natural gas compressor station' or natural gas processing plant? 3. Is this condensate storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions' of this storage tank equal to or greater than 6 tons per year VOC? No Yes Y Yes Storage tank is subject to Regulation 7, Section XVII, B, C.1 & C.3 Section XVII.B —General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.C.1 - Emissions Control and Monitoring Provisions Section XVII.C.3 - Recordkeeping Requirements 5. Does the condensate storage tank contain only "stabilized" liquids? No. Storage tank is subject to Regulation 7, Section XVII.C.2 Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels 1. Is the individual storage vessel capacity greater than or equal to 75 cubic meters (m3) (-472 BBLs]? 2. Does the storage vessel meet the following exemption in 60.111b(d)(4)? a. Does the vessel has a design capacity less than or equal to 1,589.874 m3 (`10,000 BBL] used for petroleum' or condensate stored, processed, or treated prior to custody transfer2 as defined in 60.111b? 3. Was this condensate storage tank constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after July 23, 1984? 4. Does the tank meet the definition of "storage vessel"3 in 60.1 llb? 5. Does the storage vessel store a "volatile organic liquid (VOL)"3 as defined in 60.111b? 6. Does the storage vessel meet any one of the following additional exemptions: a. Is the storage vessel a pressure vessel designed to operate in excess of 204.9 kPa [^29.7 psi] and without emissions to the atmosphere (60.110b(d)(2))?; or b. The design capacity is greater than or equal to 151 m3 ("950 BBL] and stores a liquid with a maximum true vapor pressure' less than 35 kPa (60.11ob(b))?; or c. The design capacity is greater than or equal to 75 M3 (-472 BBL] but less than 151 m3 ("950 BBL] and stores a liquid with a maximum true vapor pressure' less than 15.0 kPa(60.11ob(b))? No Source Reqi Source Reg Continue -' Continue -' Source is su Continue -' Storage Tar Continue -' Go to the n• Go to then• Source is su Source is su Storage Tar Storage Tank is not subject to NSPS Kb Subpart A, General Provisions §60.112b - Emissions Control Standards for VOC §60.113b - Testing and Procedures §60.115b - Reporting and Recordkeeping Requirements §60.116b - Monitoring of Operations 40 CFR. Part 60. Subpart 0000. Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Is this condensate storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this condensate storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015? 3. Are potential VOC emissions2 from the individual storage vessel greater than or equal to 6 tons per year? 4. Does this condensate storage vessel meet the definition of "storage vessel"' per 60.5430? 5. Is the storage vessel subject to and controlled in accordance with requirements for storage vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Subpart HH? Yes No. Storage Tank is not subject to NSPS 0000 Subpart A, General Provisions per §60.5425 Table 3 §60.5395 - Emissions Control Standards for VOC §60.5413 - Testing and Procedures §60.5395(g) - Notification, Reporting and Recordkeeping Requirements §60.5416(c) - Cover and Closed Vent System Monitoring Requirements §60.5417 - Control Device Monitoring Requirements (Note: If a storage vessel is previously determined to be subject to NSPS 0000 due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS 0000 per 60.5365(e)(2) even if potential VOC emissions drop below 6 tons per year] 40 CFR, Part 63, Subpart MACT HH, Oil and Gas Production Facilities 1. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: a. A facility that processes, upgrades or stores hydrocarbon liquids2 (63.760(a)(2)); OR b. A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end users (63.760(a)(3))? 2. Is the tank located at a facility that is major' for HAPs? 3. Does the tank meet the definition of "storage vessel" in 63.761? 4. Does the tank meet the definition of "storage vessel with the potential for flash emissions"s per 63.761? 5. Is the tank subject to control requirements under 40 CFR Part 60, Subpart Kb or Subpart 0000? Yes Storage Tank is not subject to MACT HH Subpart A, General provisions per §63.764 (a) Table 2 §63.766 - Emissions Control Standards §63.773 - Monitoring §63.774 - Recordkeeping §63.775 - Reporting RACT Review RACT review is required if Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets both criteria, then review RACT requirement. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," 'may.' "should" and 'can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must' and 'required' are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. Continue -' Storage Tar Continue -' Storage Tar Condensate Storage Tank(s) Emissions Inventory 010 Condensate Tank Facility AIRs ID: 123 9F6A County Plant 010 Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: 13x400bbl Fixed roof condensate storage tank ECD Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Condensate Throughput = 1,226,000 Barrels (bbl) per year A:tual Condensate Throughput While Emissions Controls Operating = 1,226,000 Barrels (bbl) per year Requested Permit Limit Throughput = 1,471,200 Barrels (bbl) per year Requested Monthly Throughput = 124951 Barrels (bbl) per month Potential to Emit (PTE) Condensate Throughput= Secondary Emissions - Combustion Device(s) Heat content of waste gas = Volume of waste gas emitted per BBL of liquids produced = 1,471,200 Barrels (bbl) per year 2520 9 Btu/scf scf/bbl Actual heat content of waste gas routed to combustion device = 27,806 MMBTU per year Requested heat content of waste gas routed to combustion device = 33,367 tUMBTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 33,367 MMBTU per year Section 04 - Emissions Factors & Methodologies Will this storage tank emit flash emissions? Yet. Emission Factors Condensate Tank Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) Emission Factor Source (Condensate Throughput) (Condensate Throughput) VOC 0.88 0.04 / Benzene 0.002 0.000 Toluene 0.001 0.000 Ethylbenzene 0.000 Xylene 0.000 n -Hexane 0.014 0.001 224 TMP 0.000 Control Device Emission Factor Source Uncontrolled Uncontrolled Pollutant (lb/MMBtu) (lb/bbl) (waste heat combusted) (Condensate Throughput) PM10 0.0000 AP -42 Chapter 135 Industrial Flare! (NOx) AP42 Chapter 13.5 Industrial Flare! (CO) PM2.5 0.0000 NOx 0.0680 0.0015 CO 0.3100 0.0070 Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) VOC PM10 PM2.5 NOx CO 647.5 539.6 27.0 647.5 32.4 5500 0.0 0.0 0.0 0.0 0.0 0 0.0 0.0 0.0 0.0 0.0 0 1.1 0.9 0.9 1.1 1.1 193 5.2 4.3 4.3 5.2 5.2 379 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene 2354 1962 98 2354 118 Toluene 1177 981 49 1177 59 Ethylbenzene 0 0 0 0 0 Xylene 0 0 0 0 0 n -Hexane 20303 16919 346 20303 1015 224 TMP 0 0 0 0 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XII.C, D, E, F Storage tank is subject to Regulation 7, Section XII.C F Regulation 7, Section XII.G, C Storage Tank is not subject to Regulation 7, Section (II.G Regulation 7, Section XVII.B, C.1, C.3 Storage tank is subject to Regulation 7, Section XVII, 3, C.1 & C.3 Regulation 7, Section XVII.C.2 Storage tank is subject to Regulation 7, Section XVII.C.2 Regulation 6, Part A, NSPS Subpart Kb Storage Tank is not subject to NSPS Kb Regulation 6, Part A, NSPS Subpart 0000 Storage Tank is not subject to NSPS 0000 Regulation 8, Part E, MACT Subpart HH Storage Tank is not subject to MACT HH See regulatory applicability worksheet for detailed analysis) 14 of 16 K:\PA\2018\18WE022818WE0229 18WE0230 18WE0231 18WE0232.CP1.xlsm Condensate Storage Tank(s) Emissions Inventory Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use the state default emissions factors to estimate emissions? If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? No If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. No Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company request a control device efficiency greater than 95% for a flare or combustion dev ce? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # Process # SCC Code 010 01 4-04-003-11 Faced Roof Tank, Condensate, workiiuj+tmeathing+flashir;g losses Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons condensate throughput PM2.5 0.00 0 lb/1,000 gallons condensate throughput NOx 0.04 0 Ib/1,000 gallons condensate throughput VOC 21.0 95 lb/1,000 gallons condensate throughput CO 0.17 0 lb/1,000 gallons condensate throughput Benzene 0.04 95 lb/1,000 gallons condensate throughput Toluene 0.02 95 lb/1,000 gallons condensate throughput Ethylbenzene 0.00 95 lb/1,000 gallons condensate throughput Xylene 0.00 95 lb/1,000 gallons condensate throughput n -Hexane 0.33 95 lb/1,000 gallons condensate throughput 224 TMP 0.00 95 lb/1,000 gallons condensate throughput 15 of 16 K:\PA\2018\18WE022818WE0229 18WE0230 18WE0231 18WE0232.CP1.xlsm Condensate Tank Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements Source is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (F:egulation 3, Part A, Section II.D.1.a)? 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo )5-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than S TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? You have indicated that source is in the Non -Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this Individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo )5-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.0.2)? Yes No Yes Source requires a permit Colorado Regulation 7, Section XII.C-F 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at an oil and gas exploration and production operation', natural gas compressor station or natural gas drip station? 3. Is this storage tank located upstream of a natural gas processing plant? Yes Yes Yes Storage tank is subject to Regulation 7, Section XII.C-F Section XII.C.1 - General Requirements for Air Pollution Control Equipment - Prevention of Leakage Section XII.C.2 - Emission Estimation Procedures Section XII D - Emissions Control Requirements Section XII.E - Monitoring Section XII F - Recordkeeping and Reporting Colorado Regulation 7, Section XII.G 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at a natural gas processing plant? 3. Does this storage tank exhibit "Flash" (e.g. storing non -stabilized liquids) emissions and have uncontrolled actual emissions greater than or equal to 2 tons per year VOC? Yes No NA Storage Tank is not subject to Regulation 7, Section XII.G Section XII G.2 - Emissions Control Requirements Section XII C.1 - General Requirements for Air Pollution Control Equipment - Prevention of Leakage Section XII.C2 - Emission Estimation Procedures Colorado Regulation 7, Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this condensate storage tank' located at an oil and gas exploration and production operation , well production facility', natural gas compressor stationsornatural gas processing plant? 3. Is this condensate storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions" of this storage tank equal to or greater than 6 tons per year VOC? "1B Ye<_ Yes Storage tank is subject to Regulation 7, Section XVII, 6, C.1 & C.3 Section XVII.B - General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.C.1 - Emissions Control and Monitoring Provisions Section XVII.C.3 - Recordkeeping Requirements 5. Does the condensate storage tank contain only "stabilized" liquids? Storage tank is subject to Regulation 7, Section XVII.C.2 Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels 1. Is the individual storage vessel capacity greater than or equal to 75 cubic meters (m) (`472 BBLs)? 2. Does the storage vessel meet the following exemption in 60.111b(d)(4)? a. Does the vessel has a design capacity less than or equal to 1,589.874 m3 (-10,000 BBL] used for petroleum' or condensate stored, processed, or treated prior to custody transfer' as defined in 60.111b? 3. Was this condensate storage tank constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after July 23, 1984? 4. Does the tank meet the definition of "storage vessel"3 in 60.111b? 5. Does the storage vessel store a "volatile organic liquid (VOL)"3 as defined in 60.111b? 6. Does the storage vessel meet any one of the following additional exemptions: a. Is the storage vessel a pressure vessel designed to operate in excess of 204.9 kPa ['29.7 psi} and without emissions to the atmosphere (60.11ob(d)(2))?; or b. The design capacity is greater than or equal to 151 m3 (`950 BBL) and stores a liquid with a maximum true vapor pressure' less than 3.5 kPa (60.11ob(b))?; or c. The design capacity is greater than or equal to 75 M3 (`472 BBL] but less than 151 m3 (`950 BBL) and stores a liquid with a maximum true vapor pressure' less than 15.0 kPa(60.110b(b))? No Source Regi Go to next' Source Req, Continue - Continue - Source is w Continue - Storage Tar Continue - Gotothen Go to then Source is su Source is su Storage Tar Storage Tank is not subject to NSPS Kb Subpart A, General Provisions §60.112b - Emissions Control Standards for VOC §60.113b - Testing and Procedures §60.115b - Reporting and Recordkeeping Requirements §60.116b - Monitoring of Operations 40 CFR, Part 60, Subpart 0000, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Is this condensate storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this condensate storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015? 3. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year? 4. Does this condensate storage vessel meet the definition of "storage vessel"' per 60.5430? 5. Is the storage vessel subject to and controlled in accordance with requirements for storage vessels in 40 CFR Fart 60 Subpart Kb or 40 CFR Part 63 Subpart HH? No Storage Tank is not subject to NSPS 0000 Subpart A, General Provisions per §60.5425 Table 3 §60.5395 - Emissions Control Standards for VOC §60.5413 - Testing and Procedures §60.5395(g) - Notification, Reporting and Recordkeeping Requirements §60.5416(c) - Cover and Closed Vent System Monitoring Requirements §60.5417 - Control Device Monitoring Requirements [Note: If a storage vessel is previously determined to be subject to NSPS 0000 due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS 0000 per 60.5365(e)(2) even if potential VOC emissions drop below 6 tons per year] 40 CFR, Part 63, Subpart MACT HR Oil and Gas Production Facilities 1. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)); OR b. A facility that processes, upgrades or stores natural gas prior to the point at which natural gas entars the natural gas transmission and storage source category or is delivered to a final end user3 (63.760(a)(3))? 2. Is the tank located at a facility that is major' for HAPs? 3. Does the tank meet the definition of "storage vessel" in 63.761? 4. Does the tank meet the definition of "storage vessel with the potential for flash emissions"s per 63.761? 5. Is the tank subject to control requirements under 40 CFR Part 60, Subpart Kb or Subpart 0000? Yes No Storage Tank is not subject to MACT HR Subpart A, General provisions per §63.764 (a) Table 2 §63.766 - Emissions Control Standards §63.773 - Monitoring §63.774 - Recordkeeping §63.775 - Reporting RACT Review RACT review is required if Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets both criteria, then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act. its implementing regulations, and Air Quality Control Commission regulations This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances This document does not change or substitute for any law, regulation. or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations. the language of the statute or regulation will control. The use of non -mandatory language such as "recommend" 'may," "should" and "can," is intended to describe APCD interpretations and recommendations Mandatory terminology such as "mast" and 'required' are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself Continue-` Storage Tar Continue.' Storage Tar Summary of Preliminary Analysis - NG RICE Company Name Bill Barrett Corporation Facility Name Anschutz Equus Farms 4-62-28 NWNW Facility Location NWNW SEC 28 T4N R62W Facility Equipment ID 0 18WE0234; Permit No. 18WE0233; 18WE0236 123/9F6A/002, 003, AIRS 005 Review Date 05/02/2018 Permit Engineer Timothy Sharp Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description Three (3) Waukesha, Model L7044GSI, Serial Number C -13678/1A/1; C-12839/1; C-14789/1, natural gas -fired, turbo- charged, 4SRB reciprocating internal combustion engine, site rated at 1680 horsepower. non -selective catalytic reduction (NSCR) system and air -fuel ratio control This emission unit is used for natural gas compression. Details for each engine: Natural Gas Consumption Requested (mmscf/yr) 118.47 Requested (mmscf/m) 10.06 Fuel Heat Value (btu/scf) 962 BSCF (Btu/hp-hr) 7744 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) 8760 Permit limits calculated at (hpy) 8760 Uncontrolled Controlled NOx manufacturer 0 VOC manufacturer 0 CO manufacturer 0 Formaldehyde manufacturer 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 (tpy) Uncontrolled Requested Controlled Requested PTE Proposed Efficiency Control NOx 215.8 9.7 215.8 95.5% VOC 11.4 11.4 11.4 0.0% CO 181.7 23.6 181.7 87.0% SOx 0.0 0.0 0.0 0.0% TSP 1.1 1.1 1.1 0.0% PM10 1.1 1.1 1.1 0.0% PM2.5 1.1 1.1 1.1 0.0% Total HAPs* 0.0 0.0 1.5 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 calcrlated, even those below de minimus. Point Summary of Hazardous Air Pollutants (lb/yr HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Control Efficiency Formaldehyde 1622 1622 1622 0.0% Methanol 349 349 349 0.0% Acetaldehyde 318 318 318 0.0% Acrolein 300 300 300 0.0% Benzene * * 180 0.0% 1,3 -Butadiene * * 76 0.0% Toluene * * 64 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT ZZZZ #VALUE! Reg 7 XVII.E Standards (g/hp-hr) NOx: 1.0 CO: 2.0 VOC: 0.7 Reg 7 XVI.B (Ozone NAA requirements) applies? Yes MACT ZZZZ (area source) Is this engine subject to MACT ZZZZ area source requirements? TBD NSPS JJJJ Is this engine subject to NSPS JJJJ? TBD Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes Points 002 and 003 were previously permitted under GP02 Preliminary Analysis: RICE Emission Calculations - NG RICE Company Name Bill Barrett Corporation Permit No. 18WE0234; 18WE0233; 18WE0236 AIRS 123/9F6A/002, 003, 005 Engine Type 4SRB Throughputs MMBtu/yr MMscf/yr Requested Fuel Consumption (MMBtu/yr) 113966.9 118.46871 Max Potential Fuel Consumption (MMBtu/yr) 113966.9 118.46871 Actual Fuel Consumption (MMBtu/yr) Emissions (tpy) - Criteria PM10 PM2.5 TSP SO2 NOx VOC CO Uncontrolled Requested Emissions 1.1 1.1 1.1 0.0 215.8 11.4 181.7 Controlled Requested Emissions 1.1 1.1 1.1 0.0 9.7 11.4 23.6 PTE 1.1 1,1 1.1 0.0 215.8 11.4 181.7 Uncontrolled Actual Emissions Controlled Actual Emissions Emission Factors - Criteria PM10 PM2.5 TSP SO2 NOx VOC CO lb/MMBtu - Uncontrolled 0.019 0.019 0.019 0.001 3.786 0.199 3.188 lb/MMBtu - Controlled 0.019 0.019 0.019 0.001 0.170 0.199 0.415 % Control 0.0 0.0 0.0 0.0 95.5% 0.0% 87.0% Emission Factor Sources/Notes: Controlled Uncontrolled PM10 No Control AP -42; Table 3.2-3 (7/2000); Natun SO2 No Control AP -42; Table 3.2-3 (7/2000); Naturs NOx 0 manufacturer VOC 0 manufacturer CO 0 manufacturer PM2.5 No Control AP -42; Table 3.2-3 (7/2000); Nature TSP No Control AP -42; Table 3.2-3 (7/2000); Natura Colorado Department of Public Health Envrionment Air Pollution Control Division Printed 5/30/2019 Page 4 of 9 Preliminary Analysis: RICE Colorado Department of Public Health Envrionment Air Pollution Control Division Printed 5/30/2019 Page 5 of 9 Preliminary Analysis: RICE Emission Calculations Company Name Permit No. AIRS Emissions - NCRPs Bill Barrett Corporation 18WE0234; 18WE0233; 18WE0236 123/9F6A/002, 003, 005 Colorado Department of Public Health Envrionment Air Pollution Control Division Pollutant Formaldehyde Methanol 67561 C 348.7 348.7 348.7 Acetaldehyde 75070 A 318.0 318.0 318.0 Acrolein Benzene 1,3 -Butadiene 106990 A 75.6 75.6 75.6 Toluene 108883 C 63,6 63.6 63.6 X lene 1330207 C 22.2 22.2 22.2 PAH 0 0 16.1 16.1 16.1 Naphthalene 91203 B 11.1 11.1 11.1 Methylene Chloride 75092 A 4.7 4.7 4.7 1,1,2,2-Tetrachloroethane 79345 A 2.9 2.9 2.9 Ethylbenzene 100414 C 2.8 2.8 2.8 Ethylene Dibromide Carbon Tetrachloride 1,1,2-Trichloroethane Chloroform Chlorobenzene 1,3-Dichloropropene Styrene 1,1-Dichloroethane Vinyl Chloride 2-Methylnaphthalene 2,2,4-Trimethylpentane 540841 C 0.0 Acenaphthene Acenaphthylene Anthracene Benz(a)anthracene Benzo(a)pyrene Benzo(b)fluoranthene Benzo(e)pyrene Benzo(g, h, i)perylene Benzo(k)fluoranthene Biphenyl Chrysene Fluoranthene Fluorene I ndeno(1, 2, 3-c, d) pyren e CAS BIN Requested Controlled Uncontrolled PTE Actual Controlled Uncontrolled lb/yr Cont. Req. actual>Rep lb/yr PTE >Reportable lb/yr Unc. Requested actual>Rep lb/yr lb/yr lb/yr lb/yr 50000 A 1622.2 1622.2 1622.2 107028 A 299.7 299.7 299.7 71432 A 180.1 180.1 180.1 106934 A 2.4 2.4 2.4 56235 A 2.0 2.0 2.0 79005 A 1.7 67663 A 1.6 108907 A 1.5 542756 A 1.4 100425 C 1.4 75343 B 1.3 75014 A 0.8 91 576 0 0.0 0.0 0.0 1.7 1.7 1.6 1.6 1.5 1.5 1.4 1.4 1.4 1.4 1.3 1.3 0.8 0.8 0.0 0.0 0 0 0.0 0.0 0.0 0 0 0.0 0.0 0.0 0 0 0.0 0.0 0.0 0 0 0.0 0.0 0.0 0 0 0.0 0.0 0.0 0 0 0.0 0.0 0.0 0 0 0.0 0.0 0.0 0 0 0.0 0.0 0.0 0 0 0.0 0.0 0.0 92524 C 0.0 0.0 0.0 0 0 0.0 0.0 0.0 0 0 0.0 0.0 0.0 7782414 C 0.0 0.0 0.0 0 0 0.0 0.0 0.0 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 1622.2 348.7 318.0 299.7 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 O.O 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Printed 5/30/2019 Page 6 of 9 Preliminary Analysis: RICE n -Hexane 110543 C 0.0 0.0 0.0 Colorado Department of Public Health Envrionment Air Pollution Control Division 0.0 0.0 0.0 Printed 5/30/2019 Page 7 of 9 Preliminary Analysis: RICE Emission Calculations Company Name Bill Barrett Corporation Permit No. 18WE0234; 18WE0233; 18WE0236 AIRS 123/9F6A/002, 003, 005 Emission Factors - NCRPs Colorado Department of Public Health Envrionment Air Pollution Control Division Pollutant CAS Controlled Uncontrolled Emission Factor ib/MMBtu Ig/bhp-hr % Control Notes Emission Factor lb/MMBtu ig/bhp-hr Notes Formaldehyde Methanol 50000 0.014234372 0.05 0.0% 0 0.01 0.05 manufacturer Acetaldehyde Acrolein Benzene 1,3 -Butadiene Toluene Xylene PAH Naphthalene Methylene Chloride 1,1,2,2-Tetrachloroethane Ethylbenzene Ethylene Dibromide Carbon Tetrachloride 1,1,2-Trichloroethane Chloroform Chlorobenzene 1,3-Dichloropropene Styrene 1,1-Dichloroethane Vinyl Chloride 2-Methylnaphthalene 2,2,4-Trimethylpentane Acenaphthene Acenaphthylene Anthracene Benz(a)anthracene Benzo(a)pyrene Benzo(b)fluoranthene Benzo(e)pyrene Benzo(g,h,i)perylene Benzo(k)fluoranthene Biphenyl Chrysene Fluoranthene Fluorene Indeno(1,2, 3-c,d)pyrene 0 0.00306 0.01074863 0.0% No Control 0.00306 0.010749 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.00279 0.009800221 0.0% No Control 0.00279 0.0098 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.00263 0.009238202 0.0% No Control 0.00263 0.009238 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.00158 0.005549946 0.0% No Control 0.00158 0.00555 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.000663 0.00232887 0.0% No Control 0.000663 0.002329 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.000558 0.001960044 0.0% No Control 0.000558 0.00196 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.000195 0.000684962 0.0% No Control 0.000195 0.000685 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.000141 0.00049528 0.0% No Control 0.000141 0.000495 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000971 0.000341076 0.0% No Control 0.0000971 0.000341 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000412 0.00014472 0.0% No Control 0.0000412 0.000145 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000253 8.88694E-05 0.0% No Control 0.0000253 8.89E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000248 8.71131E-05 0.0% No Control 0.0000248 8.71E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000213 7.48189E-05 0.0% No Control 0.0000213 7.48E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000177 6.21734E-05 0.0% No Control 0.0000177 6.22E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000153 5.37432E-05 0.0% No Control 0.0000153 5.37E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000137 4.8123E-05 0.0% No Control 0.0000137 4.81E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000129 4.53129E-05 0.0% No Control 0.0000129 4.53E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000127 4.46103E-05 0.0% No Control 0.0000127 4.46E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000119 4.18002E-05 0.0% No Control 0.0000119 4.18E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.0000113 3.96927E-05 0.0% No Control 0.0000113 3.97E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0.00000718 2.52206E-05 0.0% No Control 7.18E-06 2.52E-05 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/01 No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas Printed 5/30/2019 Page 8 of 9 Preliminary Analysis: RICE Colorado Department of Public Health Envrionment Air Pollution Control Division n -Hexane 0 0 0 #DIV/0! No Control 0 0 AP -42; Table 3.2-3 (7/2000); Natural Gas Printed 5/30/2019 Page 9of9 COLORADO Air Pollution Control Division Department of Public Health ft Environment Dedicated to protecting and improving the health and environment of the people of Colorado CONSTRUCTION PERMIT Permit number: 18WE0228 Date issued: Issued to: Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Bill Barrett Corporation Anschutz Equus Farms 4-62-28 NWNW 123/9F6A NWNW SEC 28 T4N R62W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment 113 AIRS Point EquipmentDescription Emissions Control Description Hydrocarbon Loadout- Compression Condensate Tanks 006 Truck loadout of condensate by submerged fill Enclosed Flare This permit is granted subject to alt rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/cdphe/air/manage-permit. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be Page 1 of 9 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/cdphe/air- permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 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. (Reference: Regulation Number 3, Part B, Section II.A.4) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NOX VOC CO Hydrocarbon Loadout- Compression Condensate Tanks 006 --_ --- 0.4 --- Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits for both criteria and hazardous air pollutants shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. Page 2 of 9 COLORADO Air Pollution Control Division Department of Public Health Er Environment Dedicated to protecting and improving the health and environment of the people of Colorado 6. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled Hydrocarbon Loadout- Compression Condensate Tanks 006 Enclosed Flare VOC and HAP 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 Number 3, Part B, II.A.4) Process/Consumption Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Hydrocarbon Loadout- Compression Condensate Tanks 006 Condensate Loaded 44,051 barrels The owner or operator shall calculate monthly process rates based on the calendar month. 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. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation Number 3, Part B, III.E) STATE AND FEDERAL REGULATORY REQUIREMENTS 9. No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Regulation Number 1, Section II.A.5.) Page 3 of 9 c. e. COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado 10. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 11. This source is located in an ozone non -attainment or attainment -maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill and emissions shall be controlled by a flare. (Reference: Regulation 3, Part B, III.D.2) 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. 12. 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): The owner or operator shall inspect onsite loading equipment to ensure that hoses, couplings, and valves are maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 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. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. Inspect pressure relief devices (PRD) annually for proper operation and replace as necessary. PRDs shall be set to release at a pressure that will ensure flashing, working and breathing losses are not vented through the PRD under normal operating conditions. Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. 13. For this controlled loading operation, the owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.D.2): a. Install and operate the vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks. b. Include devices to prevent the release of vapor from vapor recovery hoses not in use. c. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. d. Operate all recovery and disposal equipment at a back -pressure less than the pressure relief valve setting of transport vehicles. Page 4 of 9 COLORADO Air Pollution Control Division Department of Public Health B Environmern Dedicated to protecting and improving the health and environment of the people of Colorado OPERATING £t MAINTENANCE REQUIREMENTS 14. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&tM) 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 Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 15. This source is not required to conduct initial testing, unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements 16. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 17. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II .C.) Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) andnitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of VOC or NO,t 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. For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or Page 5 of 9 COLORADO Air Pollution Control Division Department of Public Health fi Environment Dedicated to protecting and improving the health and environment of the people of Colorado • No later than 30 days before the existing APEN expires. GENERAL TERMS AND CONDITIONS 18. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 19. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 20. 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'sagents. It is valid only for the equipment and operations or activity specifically identified on the permit. 21. 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. 22. 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. 23. 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. 24. 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. Page 6 of 9 By: COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Bill Barrett Corporation Page 7 of 9 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division s analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 006 n -Hexane 110543 259 13 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 006: Pollutant CAS # Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl (*exept as noted) Source NOx 0.068 (*lb/MMBtu) AP 42 CO 0.310 (*lb/MMBtu) VOC 0.2999 Site Specific n -Hexane 110543 0.00588 Site Specific 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) Page 8 of 9 COLORADO Air Pollution Control Division Department of Pubirc Health 8 Environment Dedicated to protecting and improving the health and environment of the people of Colorado P (true vapor pressure) = 8.16 psia M (vapor molecular weight) = 60 lb/lb-mol T (temperature of liquid loaded) = 512 °R The uncontrolled non -criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors by the VOC emission factor. Controlled emission factors are based on a flare efficiency of 95% and a collection efficiency of 100%. 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 facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, NOx, nHEX PSD or NANSR Synthetic Minor Source of: VOC, NOx, CO 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX Page 9 of 9 COLORADO Air Pollution Control Division Department of Pubirc Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado CONSTRUCTION PERMIT Permit number: 18WE0229 Issuance: 1 Date issued: Issued to: Bill Barrett Corporation Facility Name: Anschutz Equus Farms 4-62-28 NWNW Plant AIRS ID: 123/9F6A Physical Location: NWNW SEC 28 T4N R62W County: Weld County General Description: Well Production Facility Equipment or activity subject to this permit: Facility Equipment (p AIRS Point Equipment Description Emissions Control Description Hydrocarbon Loadout- Production Condensate Tanks 007 Truck loadout of condensate by submerged fill Enclosed Flare This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/cdphe/air/manage-permit. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be Page 1 of 10 COLORADO Air Pollution Control Division Department of Pubhc Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/cdphe/air- permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section I I I. 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. (Reference: Regulation Number 3, Part B, Section II.A.4) Annual Limits:, Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NO), VOC CO Hydrocarbon Loadout- Production Condensate Tanks 007 --_ --- 6.8 --- Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits for both criteria and hazardous air pollutants shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. Page 2 of 10 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 6. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled Hydrocarbon Loadout- Production Condensate Tanks 007 Enclosed Flare VOC and HAP 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 Number 3, Part B, II.A.4) Process/Consumption Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Hydrocarbon Loadout- Production Condensate Tanks 007 . Condensate Waded 1,471,000 barrels The owner or operator shall calculate monthly process rates based on the calendar month. 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. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation Number 3, Part B, III.E) STATE AND FEDERAL REGULATORY REQUIREMENTS 9. No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Regulation Number 1, Section II.A.5.) Page 3 of 10 COLORADO Air Pollution Control Division Department of Pubic Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 10. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 11. This source is located in an ozone non -attainment or attainment -maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill and emissions shall be controlled by a flare. (Reference: Regulation 3, Part B, III.D.2) 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. 12. The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.D.2): a. The owner or operator shall inspect onsite loading equipment to ensure that hoses, couplings, and valves are maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. The inspections shall occur at least monthly. Each inspection shall be -documented in a log available to the Division on request. 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, cr safety of personnel and equipment. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. Inspect pressure relief devices (PRD) annually for proper operation and replace as necessary. PRDs shall be set to release at a pressure that will ensure flashing, working and breathing losses are not vented through the PRD under normal operating conditions. e. Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. 13. For this controlled loading operation, the owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.D.2): a. Install and operate the vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks. b. Include devices to prevent the release of vapor from vapor recovery hoses not in use. c. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. d. Operate all recovery and disposal equipment at a back -pressure less than the pressure relief valve setting of transport vehicles. Page 4 of 10 COLORADO Air Pollution Control Division Department of Pub=ic Health Environment Dedicated to protecting and improving the health and environment of the people of Colorado OPERATING a MAINTENANCE REQUIREMENTS 14. 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 OEtM plan are subject to Division approval prior to implementation. (Reference: Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 15. This source is not required to conduct initial testing, unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements 16. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 17. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs follows: For any criteria pollutant: as For sources emitting less than 10O tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of VOC or NO), per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted. For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or Page 5 of 10 COLORADO Air Pollution Control Division Department of Fublic Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado • No later than 30 days before the existing APEN expires. GENERAL TERMS AND CONDITIONS 18. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 19. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 20. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is' conditioned upon conduct ofthe activity, or construction, installation and; operation of the source, in accordance with this information and with representations made by the owner or operator orowner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 21. 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. 22. 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. 23. 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. 24. 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. Page 6 of 10 By: COLORADO Air Pollution Control Division Department of Public Heath Et Environment Dedicated to protecting and improving the health and environment of the people of Colorado Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Bill Barrett Corporation Page 7 of 10 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 007 Benzene 71432 475 24 n -Hexane 110543 4211 211 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 007: Pollutant CAS # Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl (*exept as noted) Source NOx 0.068 (*lb/MMBtu) AP 42 CO 0.310 (*lb/MMBtu) VOC 0.18254 Site Specific Benzene 71432 .00032 Site Specific n -Hexane 110543 0.00286 The uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.2, Equation 1 (version 1/95) using the following values: Page 8 of 10 COLORADO Air Pollution Control Division Department of Public Health 6 Environment Dedicated to protecting and improving the health and environment of the people of Colorado L = 12.46*S*P*M/T S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 4.45 psia M (vapor molecular weight) = 67 lb/lb-mol T (temperature of liquid loaded) = 512 °R The uncontrolled non -criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors by the VOC emission factor. Controlled emission factors are based on a flare efficiency of 95% and a collection efficiency of 100%. 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 facility is classified as follows. Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, NOx, nHEX PSD or NANSR Synthetic Minor Source of: VOC, NOx, CO 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE -Subpart PPP MACT 63.1440-63.6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX Page 9 of 10 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Page 10 of 10 COLORADO Air Pollution Control Division Department of Public Health 6 Environment Dedicated to protecting and improving the health and environment of the people of Colorado Permit number: Date issued: Issued to: CONSTRUCTION PERMIT 18WE0230 Issuance: 1 Bill Barrett Corporation Facility Name: Plant AIRS ID: Physical Location: County: Description: Anschutz Equus Farms 4-62-28 NWNW 123/9F6A NWNW SEC 28 T4N R62W Weld County Well Production Facility, Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description Pw 008 Four (4) 400 barrel fixed roof storage vessels used to store produced water Enclosed Flare This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/cdphe/air/manage-permit. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify Page 1 of 8 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado compliance as required by this permit may be obtained online at www.colorado.gov/cdphe/air- permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) I. F.4. ) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The 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 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NO,t VOC CO PW 008 --- --- 0.7 --- Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The owner or operator must use the emission factors found in "Notes to Permit Holder" to calculate emissions and show compliance with the limits. The owner or operator must submit an Air Pollutant Emission Notice (APEN) and receive a modified permit prior to the use of any other method of calculating emissions. Page 2 of 8 COLORADO Air Pollution Control Division Department of Public Healih 6 Environment Dedicated to protecting and improving the health and environment of the people of Colorado 8. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled PW '008 Enclosed Flare VOC and HAP PROCESS LIMITATIONS AND RECORDS 9. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit PW 008 Produced Water- throughput 1,098,000 barrels The owner or operator shall monitor monthly process rates based on the calendar month. 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. STATE AND FEDERAL REGULATORY REQUIREMENTS 10. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 11. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 12. 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 device, or by other Page 3 of 8 COLORADO Air Pollution Control Division Department of Public Health 6 Environment Dedicated to protecting and improving the health and environment of the people of Colorado means approved by the Division, determine whether it is operating properly. (Regulation Number 7, Section XII.C.) (State only enforceable) 13. The source is subject to Regulation Number 7, Section XII.G. The operator shall comply with all applicable requirements of Section XII. 14. 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. 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. 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. OPERATING £t MAINTENANCE REQUIREMENTS 17. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OEM) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the OEM plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 18. This source is not required to conduct initial testing, unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements Page 4 of 8 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado 19. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 20. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOa) in ozone nonattainment areas emitting less than 100 tons of VOC or NO,� per year,,a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last. APEN submitted to the Division. Whenever there is a change in the owner or operator of any facility, process, or activity; or Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. GENERAL TERMS AND CONDITIONS 21. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 22. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all Page 5 of 8 COLORADO Air Pollution Control Division Department of Public 1-leaith 6 Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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. 23. 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. 24. 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. 25. 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. 26. 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. 27. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Bill Barrett Corporation Page 6 of 8 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard., A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 008 Benzene 71432 373 19 n -Hexane 110543 1197 60 Note: All non -criteria reportable pollutants in the table above with uncontrolled emiss'on rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 2.40E-2 Site Specific 71432 Benzene 3.40E-4 Site Specific 110543 n -Hexane 1.09E-3 Site Specific Note: The controlled emissions factors for this point are based on a control efficiency of 95%. 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 Page 7 of 8 COLORADO Air Pollution Control Division Department of Pubitc Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, NOx, nHEX PSD or NANSR Synthetic Minor Source of: VOC, NOx, CO MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Not Applicable 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 Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX Page 8 of 8 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado Permit number: Date issued: Issued to: CONSTRUCTION PERMIT 18WE0231 Issuance: 1 Bill Barrett Corporation Facility Name: Plant AIRS ID: Physical Location: County: Description: Anschutz Equus Farms 4-62-28 NWNW 123/9F6A NWNW SEC 28 T4N R62W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description COMP 009 Four (4) 400 barrel fixed roof storage vessels used to store condensate Enclosed Flare This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1 YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/cdphe/air/manage-permit. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify Page 1 of 9 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado compliance as required by this permit may be obtained online at www.colorado.gov/cdphe/air- permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) I. F.4. ) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The 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 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NOX VOC CO COMP 009 - --- 6.8 1.8 Point Note: '>See `'"Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The owner or operator must use the emission factors found in "Notes to Permit Holder" to calculate emissions and show compliance with the limits. The owner or operator must submit an Air Pollutant Emission Notice (APEN) and receive a modified permit prior to the use of any other method of calculating emissions. Page 2 of 9 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado 8. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled COMP 009 Enclosed Flare VOC and HAP PROCESS LIMITATIONS AND RECORDS 9. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit COMP 009 Condensate throughput 44,051 barrels The owner or operator shall monitor monthly process rates based on the calendar month. 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. STATE AND FEDERAL REGULATORY REQUIREMENTS 10. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 11. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 12. 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 device, or by other Page 3 of 9 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado means approved by the Division, determine whether it is operating properly. (Regulation Number 7, Section XII.C.) (State only enforceable) 13. The source is subject to Regulation Number 7, Section XII.G. The operator shall comply with all applicable requirements of Section XII. 14. 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. 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. 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. OPERATING £t MAINTENANCE REQUIREMENTS 17. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OEtM) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the OEtM plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 18. 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) Page 4 of 9 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado Periodic Testing Requirements 19. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 20. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of VOC or NO), per year, a change in annual actual emissions of. one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. GENERAL TERMS AND CONDITIONS 21. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 22. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD Page 5 of 9 COLORADO Air Pollution Control Division Department of Public Health El Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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. 23. 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. 24. 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. 25. 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 faith). 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. 26. 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. 27. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Bill Barrett Corporation Page 6 of 9 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions > (lb/yr) Controlled Emissions (lb/yr) 009 Benzene 71432 639 32 Toluene 108883 410 20 n -Hexane 110543 5617 281 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl (*exept as noted) Source NOx 0.068 (*lb/MMBtu) AP -42 CO 0.310 (*lb/MMBtu) AP -42 VOC 6.171 Site Specific 71432 Benzene 1.45E-2 Site Specific 108883 Toluene 9.30E-3 Site Specific Page 7 of 9 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl (*exept as noted) Source 110543 n -Hexane 1.28E-1 Site Specific Note: The controlled emissions factors for this point are based on a control efficiency of 95%. 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 permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, NOx, nHEX PSD or NANSR Synthetic Minor Source of: VOC, NOx, CO MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Not Applicable 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 Page 8 of 9 MACT COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 63.8980 -End Subpart NNNNN - Subpart XXXXXX Page 9 of 9 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Permit number: Date issued: Issued to: CONSTRUCTION PERMIT 18WE0232 Issuance: 1 Bill Barrett Corporation Facility Name: Plant AIRS ID: Physical Location: County: Description: Anschutz Equus Farms 4-62-28 NWNW 123/9F6A NWNW SEC 28 T4N R62W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description COND 010' Thirteen (13) 400 barrel fixed roof storage vessels used to store condensate Enclosed Flare This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C.R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/cdphe/air/manage-permit. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify Page 1 of 8 COLORADO Air Pollution Control Division Department of Public Health S Environment Dedicated to protecting and improving the health and environment of the people of Colorado compliance as required by this permit may be obtained online at www.colorado.Qov/cdphe/air- permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) I. F.4. ) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The 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 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NOX VOC CO COND 010 - - 1.1 32.4 5.1 Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. Facility -wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The owner or operator must use the emission factors found in "Notes to Permit Holder" to calculate emissions and show compliance with the limits. The owner or operator must submit an Air Pollutant Emission Notice (APEN) and receive a modified permit prior to the use of any other method of calculating emissions. Page 2 of 8 COLORADO Air Pollution Control Division Department of Public Health Et Environment Dedicated to protecting and improving the health and environment of the people of Colorado 8. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled COND 010 Enclosed Flare VOC and HAP PROCESS LIMITATIONS AND RECORDS 9. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit COND 010 Condensate throughput 1,171,200 barrels The owner or operator shall monitor monthly process rates based on the calendar month. 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. STATE AND FEDERAL REGULATORY REQUIREMENTS 10. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 11. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 12. 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 device, or by other Page 3 of 8 COLORADO Air Pollution Control Division Department of Public Health 8 Environment Dedicated to protecting and improving the health and environment of the people of Colorado means approved by the Division, determine whether it is operating properly. (Regulation Number 7, Section XII.C.) (State only enforceable) 13. The source is subject to Regulation Number 7, Section XII.G. The operator shall comply with all applicable requirements of Section XII. 14. 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. 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. 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. OPERATING £t MAINTENANCE REQUIREMENTS 17. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (0&tM) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the 08M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 18. 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) Page 4 of 8 COLORADO Air Pollution Control Division Department of Pubic Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado Periodic Testing Requirements 19. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 20. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO.) in ozone nonattainment areas emitting less than 100 tons of VOC or NO. per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. GENERAL TERMS AND CONDITIONS 21. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 22. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD Page 5 of 8 COLORADO Air Pollution Control Division Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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. 23. 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. 24. 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. 25. 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. 26. 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. 27. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Bill Barrett Corporation Page 6 of 8 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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 shalt pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listedto inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 010 Benzene 71432 1907 95 Toluene 108883 933 47 n -Hexane 110543 16927 846 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl (*exept as noted) Source NOx 0.068 (*lb/MMBtu) AP -42 CO 0.310 (*lb/MMBtu) AP -42 VOC 8.80E-1 Site Specific 71432 Benzene 1.60E-3 Site Specific 108883 Toluene 8.00E-4 Site Specific 110543 n -Hexane 1.38E-2 Site Specific Note: The controlled emissions factors for this point are based on a control efficiency of 95%. Page 7 of 8 COLORADO Air Pollution Control Division Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado 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 permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, NOx, nHEX PSD or NANSR Synthetic Minor Source of: VOC, NOx, CO MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Not Applicable 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 Page 8 of 8 STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303 692-31.50 PERMIT NO: 18WE0233 CO STRUCTION PERMIT Issuance 1 DATE ISSUED: ISSUED TO: Bill Barrett Corporation THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Anschutz Equus Farms 4-62-28 NWNW, located in NWNW SEC 28 T4N R62W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Point Description C-12839/1 003 One (1) Waukesha, Model L7044GSI, Serial Number C- 12839/1, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1,680 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air - fuel ratio control. This emission unit is used for natural gas compression. This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Waukesha L7044GSI 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 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 www.colorado.gov/cdphe/air/manage-permit. 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 III.G.1 and can result in the revocation of the permit. AIRS ID: 123/9F6A/003 Page 1 of 15 NGEngine Version 2014-1 loradr epartt f Public Health and Environment Air Pollution Control Division 2. Within one hund -`e eig a ) o "'°- -r 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 perms nce: Regulation No. 3, Part B, III.G.2). 3. This permit shall expire if the own issued: (i) does not commence con 18 months after either, the date of or operator of the source for which this permit was uction/modification or operation of this source within nce 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 complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 5. The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • manufacture date • construction date • order date • date of relocation into Colorado • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, III.E.) 6. The operator shall retain the permit final authorization letter issued by the Division after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations (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 NO. VOC CO C-12839/1 003 9.8 11.4 24.4 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. AIRS ID: 123/9F6A/003 Page 2 of 15 f Public Health and Environment Air Pollution Control Division Facility -wide emi of to a = �.• a I -"' is shall be less than 20.0 tpy. 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 rollin• twelve (12) month total. By the end of each month a new twelve-month total shall ted based on the previous twelve months' data. The permit holder shall calculate e .sions each month and keep a compliance record on site or at a local field office with e responsibility, for Division review. This rolling twelve-month total shall apply to a-rmitted emission units, requiring an APEN, at this facility. 8. 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 C-12839/1 003 NSCR and air/fuel ratio controller VOC and CO PROCESS LIMITATIONS AND RECORDS 9. 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 C-12839/1 003 Consumption of natural gas as a fuel 119 MMscf/yr Fuel consumption shall be measured by one of the following methods: individual engine fuel meter; facilty-wide fuel meter attributed to fuel consumption rating and hours of operation; or manufacturer -provided fuel consumption rate. The owner or operator shall calculate monthly process rates based on the calendar month. 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. 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) AIRS ID: 123/9F6A/003 Page 3 of 15 f Public Health and Environment Air Pollution Control Division 11. Visible emission not %) 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 Y e no visible emissions. (Reference: Regulation No. 1, Section I I.A.1. & 4.) 12. This source is subject to the ode requirements of Regulation No. 2. (State only enforceable) 13. This equipment is subject to the control requirements for stationary and portable engines in the 8 -hour ozone control area under Regulation No. 7, Section XVI.B.1. For rich burn reciprocating internal combustion engines, a non -selective catalyst reduction system and an air fuel controller shall be required. 14. This equipment is subject to the control requirements for natural gas -fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas -fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Maximum' Engine HP Construction or Relocation Date Emission Standard in g/hp-hr NOx CO VOC <100HP Any N/A N/A N/A ≥100HP and <500HP January 1, 2008 January 1, 2011 2.0 1.0 4.0 2.0 1.0 0.7 ≥500HP July 1, 2007 July 1, 2010 2.0 1.0 4.0 2.0 1.0 0.7 1 account for deration. Note: Per Regulation No. 7, Section XVII.B.5, internal combustion engines that are subject to an emission standard or an emissions control requirement in a federal maximum achievable control technology ("MACT") standard under 40 CFR Part 63, a Best Available Control Technology ("BACT") limit, or a New Source Performance Standard under 40 CFR Part 60 are not subject to this Section XVII. OPERATING & MAINTENANCE REQUIREMENTS 15. 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.) AIRS ID: 123/9F6A/003 Page 4 of 15 f Public Health and Environment Air Pollution Control Division COMPLIANCE TESTI D P Periodic Testing Requirements 16. This engine is subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan a :. l=ed by the Division. Revisions to your O&M plan are subject to Division approv.. epcements of this unit completed as Alternative Operating Scenarios may be subj to additional testing requirements as specified in Attachment A. ADDITIONAL REQUIREMENTS 17. All previous versions of this permit are cancelled upon issuance of this permit. 18. This permit replaces the following permits and/or points, which are cancelled upon issuance of this permit. Existing Permit No. Existing Emission Point New Emission Point GP02 123/9F6A/003 123/9F6A/003 19. 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 (NO)) 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. AIRS ID: 123/9F6A/003 Page 5 of 15 loradf 1epart f Public Health and Environment Air Pollution Control Division 20. Federal regulato • :ram - • it- (i. - . .r 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 �'� T he source shall not exceed the Federal program threshold until a permit is grant-. lation No. 3 Part D). GENERAL TERMS AND CONDITION 21. 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. 22. 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. 23. 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. 24. 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. 25. 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. 26. 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. AIRS ID: 123/9F6A/003 Page 6 of 15 f Public Health and Environment Air Pollution Control Division 27. Violation of the of - •- mf tions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Timothy Sharp Permit Engineer Permit Histo Issuance Date Description Issuance 1 This Issuance Issued to Bill Barrett Corporation. AIRS ID: 123/9F6A/003 Page 7 of 15 Notes to Permit Holder at t of t Ioradr?epart -nt '•f Public Health and Environment Air Pollution Control Division nc 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 I its 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 providin• here is no exceedance of any specific emission control regulation or any ambient air quality sta •: . 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.qov/pacific/cdphe/aqcc-reqs 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 # BIN Uncontrolled Emission Rate (Ib/yr) Are the emissions reportable? Controlled Emission Rate (lb/yr) 003 Formaldehyde 50000 A 1,622 Yes 1,622 Methanol 67561 C 349 Yes 349 Acetaldehyde 75070 A 318 Yes 318 Acrolein 107028 A 300 Yes 300 Benzene 71432 A 180 No 180 1,3 -Butadiene 106990 A 76 No 76 Toluene 108883 C 64 No 64 5) The emission levels contained in this permit are based on the following emission factors: Point 003: CAS Pollutant Emission Uncontrolled Ib/MMBtu Factors - g/bhp-hr Emission Controlled Ib/MMBtu Factors — g/bhp-hr NOx 3.7863 13.30 0.1704 0.60 CO 3.1885 11.20 0.4145 1.46 VOC 0.1993 0.70 0.1993 0.70 50000 Formaldehyde 0.0142 0.05 0.0142 0.05 67561 Methanol 0.0031 0.01 0.0031 0.01 75070 Acetaldehyde 0.0028 0.01 0.0028 0.01 107028 Acrolein 0.0026 0.01 0.0026 0.01 71432 Benzene 0.0016 0.01 0.0016 0.01 106990 1,3 -Butadiene 0.0007 0.00 0.0007 0.00 AIRS ID: 123/9F6A/003 Page 8 of 15 Ioradepart ,?ent f Public Health and Environment Air Pollution Control Division CAS Pollutant Uncontrolled lb/MMBtu g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr 108883 Toluene 0.0006 0.00 0.0006 0.00 Emission factors are based on a Br >_ fic Fuel Consumption Factor of 7744 Btu/hp-hr, a site - rated horsepower value of 1680, a a el eat value of 962 Btu/scf. Emission Factor Sources: CAS Pollutant Un • ntrolled EFSource Controlled EF Source NOx ma + "- urer manufacturer CO manufacturer manufacturer VOC manufacturer manufacturer 50000 Formaldehyde manufacturer manufacturer 67561 Methanol AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 75070 Acetaldehyde AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 107028 Acrolein AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 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 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 facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, NOx, nHEX PSD/NANSR Synthetic Minor Source of: VOC, NOx, CO 8) 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 AIRS ID: 123/9F6A/003 Page 9 of 15 f Public Health and Environment Air Pollution Control Division MACT 63.600-6 . •9 ubpa — u•pa .-mIDD MACT 63.1200-63.1439 Subpart EEE — Subpart PPP MACT 63.1440-63.6175 Subpart QQQ — Subpart YYYY MACT 63.6580-63.8830 �• - ZZ - Subpart MMMMM MACT 63.8980 -End Sub w rt NNNNN — Subpart X)OCXXX 9) 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: 123/9F6A/003 Page 10 of 15 f Public Health and Environment Air Pollution Control Division ALTERNATIVE OPERATING SCENARIOS RECIPROCATING IN 2. Alternative Operating Scenarios L COMBUSTION ENGINES Oc ber 12, 2012 The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with an engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/9F6A/003 Page 11 of 15 loradri?epart entf Public Health and Environment Air Pollution Control Division 2.1.2 The owner or operat. - r per = nt - ` ce - - g 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 d compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that i "' ludes the specific manufacturer, model and serial number and horsepower of the permanent replacemenE!-ngine shall be filed with the Division for the permanent replacement engine within 14 calendar days • "'•mmencing 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 www.colorado.gov/cdphe/air/AOS. 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: www.colorado.pov/cdphe/portable-analvzer-monitorina-protocol Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement AIRS ID: 123/9F6A/003 Page 12 of 15 f Public Health and Environment Air Pollution Control Division engine will be subject to, t s of to the appropriate units as described in the above -mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance absence of credible evidence to the contra both the NOX and CO emission limitations Subject to the provisions of C.R.S. 25-7-123.1 the portable analyzer results fail to demonstrate the engine will be considered to be out of c portable analyzer test indicates compliance with engine is taken offline. with both the NOX and CO emission limitations, in the rce may certify that the engine is in compliance with vant time period. d in the absence of credible evidence to the contrary, if mpliance with either the NOX or CO emission limitations, nce from the date of the portable analyzer test until a both the NOX and CO emission limitations or until the 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. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. AIRS ID: 123/9F6A/003 Page 13 of 15 epartu;-nt f Public Health and Environment Air Pollution Control Division The source shall submit copies of the relevant Applicability Reports required under Condition Emission Standards: Section XVII.E — State -only requirements Any permanent engine that is either constr after the date listed in the table below sh manufacturer's written instructions or procedure limitations and good engineering and mainten achieves the emission standards required in t 2.1.2. located to the state of Colorado from another state, operate and maintain each engine according to the o the extent practicable and consistent with technological ce practices over the entire life of the engine so that it le below: Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 500<Hp July 1, 2007 July 1,2010 2.0 1.0 4.0 2.0 1.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § 1.8 (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, AIRS ID: 123/9F6A/003 Page 14 of 15 if approved in advance by tsion, in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with new emissions unit, not "routine replacement" advanced construction permit review. The AO site; an engine that is being installed as an entir replacement of an existing onsite engine permitting process prior to installation. f Public Health and Environment Air Pollution Control Division uc = inducted within the time frame specified gine is viewed by the Division as the installation of a f an existing unit. The AOS is therefore essentially an annot be used for additional new emission points for any new emission point and not as part of an AOS-approved go through the appropriate Construction/Operating AIRS ID: 123/9F6A/003 Page 15 of 15 STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303 692-3150 PERMIT NO: 18WE0234 CO STRUCTION PERMIT Issuance 1 DATE ISSUED: ISSUED TO: Bill Barrett Corporation THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Anschutz Equus Farms 4-62-28 NWNW, located in NWNW SEC 28 T4N R62W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Point Description C -13678/1A/1 002 One (1) Waukesha, Model L7044GS1, Serial Number C - 13678/1A/1, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1,680 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air - fuel ratio control. This emission unit is used for natural gas compression. This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Waukesha L7044GSI 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 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 www.colorado.aov/cdphe/air/manage-permit. 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 III.G.1 and can result in the revocation of the permit. AIRS ID: 123/9F6A/002 Page 1 of 15 NGEngine Version 2014-1 f Public Health and Environment Air Pollution Control Division 2. Within one hund -• • eig a r 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 permi nce: Regulation No. 3, Part B, III.G.2). 3. This permit shall expire if the own or operator of the source for which this permit was issued: (i) does not commence con uction/modification or operation of this source within 18 months after either, the date of ' - nce 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 complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 5. The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • manufacture date • construction date • order date • date of relocation into Colorado • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, III.E.) 6 The operator shall retain the permit final authorization letter issued by the Division after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations (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 NO. VOC CO C -13678/1A/1 002 9.8 11.4 24.4 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. AIRS ID: 123/9F6A/002 Page 2 of 15 epart - nt f Public Health and Environment Air Pollution Control Division Facility -wide emi `"' :"` of to - a ` • . a is shall be less than 20.0 tpy. 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 rollin• twelve (12) month total. By the end of each month a new twelve-month total shall • c u bw ted based on the previous twelve months' data. The permit holder shall calculate e -sions each month and keep a compliance record on site or at a local field office with e responsibility, for Division review. This rolling twelve-month total shall apply to a rmitted emission units, requiring an APEN, at this facility. 8. 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 C -1367811A11 002 NSCR and air/fuel ratio controller VOC and CO PROCESS LIMITATIONS AND RECORDS 9. 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 C -13678/1A/1 002 Consumption of natural gas as a fuel 119 MMscf/yr Fuel consumption shall be measured by one of the following methods: individual engine fuel meter; facilty-wide fuel meter attributed to fuel consumption rating and hours of operation; or manufacturer -provided fuel consumption rate. The owner or operator shall calculate monthly process rates based on the calendar month. 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. 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) AIRS ID: 123/9F6A/002 Page 3 of 15 ent f Public Health and Environment Air Pollution Control Division 11. Visible emission ' : " not %) 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 e no visible emissions. (Reference: Regulation No. 1, Section I I.A.1. & 4.) 12. This source is subject to the od' requirements of Regulation No. 2. (State only enforceable) 13. This equipment is subject to the control requirements for stationary and portable engines in the 8 -hour ozone control area under Regulation No. 7, Section XVI.B.1. For rich burn reciprocating internal combustion engines, a non -selective catalyst reduction system and an air fuel controller shall be required. 14. This equipment is subject to the control requirements for natural gas -fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas -fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Maximum' Engine HP Construction or Relocation Date Emission Standard in g/hp-hr NOx CO VOC <100HP Any N/A N/A N/A ≥100HP and <500HP January 1, 2008 January 1, 2011 2.0 1.0 4.0 2.0 1.0 0.7 ≥500HP July 1, 2007 July 1, 2010 2.0 1.0 4.0 2.0 1.0 0.7 ' Maximum engine horsepower is the nameplate rating of the engine and does not account for deration. Note: Per Regulation No. 7, Section XVII.B.5, internal combustion engines that are subject to an emission standard or an emissions control requirement in a federal maximum achievable control technology ("MACT") standard under 40 CFR Part 63, a Best Available Control Technology ("BACT') limit, or a New Source Performance Standard under 40 CFR Part 60 are not subject to this Section XVII. OPERATING & MAINTENANCE REQUIREMENTS 15. 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.) AIRS ID: 123/9F6A/002 Page 4 of 15 COMPLIANCE TESTI D ent f Public Health and Environment Air Pollution Control Division Periodic Testing Requirements 16. This engine is subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan ad by the Division. Revisions to your O&M plan are subject to Division approv 'T. ep'. cements of this unit completed as Alternative Operating Scenarios may be subj to additional testing requirements as specified in Attachment A. ADDITIONAL REQUIREMENTS 17. All previous versions of this permit are cancelled upon issuance of this permit. 18. This permit replaces the following permits and/or points, which are cancelled upon issuance of this permit. Existing Permit No. Existing Emission Point New Emission Point GP02 123/9F6A/002 123/9F6A/002 19. 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 polutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or 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. AIRS ID: 123/9F6A/002 Page 5 of 15 lorad'i, epart ent f Public Health and Environment Air Pollution Control Division 20. Federal regulato ram -. rir- - (I . ■ r 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 thehe source shall not exceed the Federal program threshold until a permit is grant-:. e• lation No. 3 Part D). GENERAL TERMS AND CONDITION 21 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. 22. 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. 23. 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. 24. 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. 25. 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. 26. 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. AIRS ID: 123/9F6A/002 Page 6 of 15 f Public Health and Environment Air Pollution Control Division 27. Violation of the ions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Timothy Sharp Permit Engineer Permit Histo Issuance Date Description Issuance 1 This Issuance Issued to Bill Barrett Corporation. AIRS ID: 123/9F6A/002 Page 7 of 15 Notes to Permit Holder at t - of t IoradFepart� -nt f Public Health and Environment Air Pollution Control Division 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 I F its and emission limits contained in this permit are based on the consumption rates requested in th permit application. These limits may be revised upon request of the owner or operator providin• here is no exceedance of any specific emission control regulation or any ambient air quaity sta •_ . 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/adcc-reqs 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 # BIN Uncontrolled Emission Rate (Ib/yr) Are the emissions reportable? Controlled Emission Rate (Ib/yr) 002 Formaldehyde 50000 A 1,622 Yes 1,622 Methanol 67561 C 349 Yes 349 Acetaldehyde 75070 A 318 Yes 318 Acrolein 107028 A 300 Yes 300 Benzene 71432, A 180 No 180 1,3 -Butadiene 106990 A 76 No 76 Toluene 108883 C 64 No 64 5) The emission levels contained in this permit are based on the following emission factors: Point 002: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr NOx 3.7863 13.30 0.1704 0.60 CO 3.1885 11.20 0.4145 1.46 VOC 0.1993 0.70 0.1993 0.70 50000 Formaldehyde 0.0142 0.05 0.0142 0.05 67561 Methanol 0.0031 0.01 0.0031 0.01 75070 Acetaldehyde 0.0028 0.01 0.0028 0.01 107028 Acrolein 0.0026 0.01 0.0026 0.01 71432 Benzene 0.0016 0.01 0.0016 0.01 106990 1,3 -Butadiene 0.0007 0.00 0.0007 0.00 AIRS ID: 123/9F6A/002 Page 8 of 15 f Public Health and Environment Air Pollution Control Division CAS Pollutant Uncontrolled lb/MMBtu g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr 108883 Toluene 0.0006 0.00 0.0006 0.00 Emission factors are based on a Br rated horsepower value of 1680, a Emission Factor Sources: c Fuel Consumption Factor of 7744 Btu/hp-hr, a site - eat value of 962 Btu/scf. CAS Pollutant Urr_::• ntrolled EFSource Controlled EF Source NOx ma urer manufacturer CO manufacturer manufacturer VOC manufacturer manufacturer 50000 Formaldehyde manufacturer manufacturer 67561 Methanol AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 75070 Acetaldehyde AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 107028 Acrolein AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 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 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 facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, NOx, nHEX PSD/NANSR Synthetic Minor Source of: VOC, NOx, CO 8) 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 AIRS ID: 123/9F6A/002 Page 9 of 15 f Public Health and Environment Air Pollution Control Division MACT 63.600-6. ' 9 ubpa �— u • pa • DD MACT 63.1200-63.1439 Subpart EEE — Subpart PPP MACT 63.1440-63.6175 Subpart QQQ — Subpart YYYY MACT 63.6580-63.8830 ZZ — Subpart MMMMM MACT 63.8980 -End Sub rt NNNNN — Subpart XXXXXX 9) 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: 123/9F6A/002 Page 10 of 15 f Public Health and Environment Air Pollution Control Division ALTERNATIVE OPERATING SCENARIOS RECIPROCATING IN 2. Alternative Operating Scenarios L COMBUSTION ENGINES Oc _ber 12, 2012 The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with an engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/9F6A/002 Page 11 of 15 loradfj epart ent f Public Health and Environment Air Pollution Control Division 2.1.2 The owner or operatper ' • '= nt ".``-ce - g 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 -• it, d compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that i _°` ludes the specific manufacturer, model and serial number and horsepower of the permanent replacemen -ngine shall be filed with the Division for the permanent replacement engine within 14 calendar days •mmencing 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 www.colorado.qov/cdphe/air/AOS. 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. Nothing in this AOS shall preclude the Division from taking an action, based on any permanent engine replacement(s), for circumvention of any state or federal PSD/NANSR requirement. Additionally, in the event that any permanent engine replacement(s) constitute(s) a circumvention of applicable PSD/NANSR requirements, nothing in this AOS shall excuse the owner or operator from complying with PSD/NANSR and applicable permitting requirements. 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: www.colorado.ciov/cdphe/portable-analyzer-rnonitorinq-protocol 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 AIRS ID: 123/9F6A/002 Page 12 of 15 the test results will be mult applies. Iorad"A epart ent f Public Health and Environment Air Pollution Control Division y the �' - :emu _ "o b �� •` • : in the month or year (8760), whichever For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) to. isting unit is currently subject to or the replacement engine will be subject to, the results of the st a°`•e converted to the appropriate units as described in the above -mentioned Portable Analyzer Monito g Protocol document. If the portable analyzer results indicate complia e with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary,'' - ource 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 feel 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. AIRS ID: 123/9F6A/002 Page 13 of 15 Lean burn engine catalyst to reduce emissions. lorad ma I _ _ ur ... s..sig apart nt f Public Health and Environment Air Pollution Control Division ter than 500 hp shall use an oxidation The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer mk. ions. The source shall submit copies of the relevant t )plicability Reports required under Condition 2.1.2. Emission Standards: Section XVILE — State -on 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 NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500≤Hp July 1, 201D 1.0 2.0 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, § LB (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 AIRS ID: 123/9F6A/002 Page 14 of 15 f Public Health and Environment Air Pollution Control Division �-" ^ _ 'r source is to the requirements A permanent replacement - + � - _ oca `= : =' e - = a - - subject q in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT ca . the testing required by this AOS under Condition 2.2, if approved in advance by the Division, pro ;ae• a °.uch 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: 123/9F6A/002 Page 15 of 15 STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303 692-3150 PERMIT NO: 18WE0236 CO STRUCTION PERMIT Issuance 1 DATE ISSUED: ISSUED TO: Bill Barrett Corporation THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Anschutz Equus Farms 4-62-28 NWNW, located in NWNW SEC 28 T4N R62W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Point Description C-14789/1 005 One (1) Waukesha, Model L7044GSI, Serial Number C- 14789/1, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1,680 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air - fuel ratio control. This emission unit is used for natural gas compression. This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Waukesha L7044GSI 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 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 www.colorado.aov/cdphe/air/manage-permit. 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 III.G.1 and can result in the revocation of the permit. AIRS ID: 123/9F6A/005 Page 1 of 15 NGEngine Version 2014-1 f Public Health and Environment Air Pollution Control Division 2. Within one hund :eig r 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 permince: Regulation No. 3, Part B, III.G.2). 3. This permit shall expire if the own or operator of the source for which this permit was issued: (i) does not commence con uction/modification or operation of this source within 18 months after either, the date of • - nce 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 complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 5. The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • manufacture date • construction date • order date • date of relocation into Colorado • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, III.E.) 6. The operator shall retain the permit final authorization letter issued by the Division after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations (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 NO. VOC CO C-14789/1 005 9.8 11.4 24.4 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. AIRS ID: 123/9F6A/005 Page 2 of 15 lorad epartf Public Health and Environment Air Pollution Control Division Facility -wide emi . ` of to - a •: u a .'.I r - ` is shall be less than 20.0 tpy. 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 rollin• twelve (12) month total. By the end of each month a new twelve-month total shall u:=ted based on the previous twelve months' data. The permit holder shall calculate e -sions each month and keep a compliance record on site or at a local field office with .'e responsibility, for Division review. This rolling twelve-month total shall apply to a - mitted emission units, requiring an APEN, at this facility. 8. 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 C-14789/1 005 NSCR and air/fuel ratio controller VOC and CO PROCESS LIMITATIONS AND RECORDS 9. 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 C-14789/1 005 Consumption of natural gas as a fuel 119 MMscf/yr Fuel consumption shall be measured by one of the following methods: individual engine fuel meter; facilty-wide fuel meter attributed to fuel consumption rating and hours of operation; or manufacturer -provided fuel consumption rate. The owner or operator shall calculate monthly process rates based on the calendar month. 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. 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) AIRS ID: 123/9F6A/005 Page 3 of 15 loradei depart f Public Health and Environment Air Pollution Control Division 11. Visible emission - not %) 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 . rt e no visible emissions. (Reference: Regulation No. 1, Section I I.A.1. & 4.) 12. This source is subject to the od requirements of Regulation No. 2. (State only enforceable) 13. This equipment is subject to the control requirements for stationary and portable engines in the 8 -hour ozone control area under Regulation No. 7, Section XVI.B.1. For rich burn reciprocating internal combustion engines, a non -selective catalyst reduction system and an air fuel controller shall be required. 14. This equipment is subject to the control requirements for natural gas -fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas -fired reciprocating internal combustion engine that is either constructed or relocated to the state of Colorado from another state after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Maximum' Engine HP Construction or Relocation Date Emission Standard in g/hp-hr NOx CO VOC <100HP Any N/A N/A N/A ≥100HP and <500HP January 1, 2008 January 1, 2011 2.0 1.0 4.0 2.0 1.0 0.7 ≥500HP July 1, 2007 July 1, 2010 2.0 1.0 4.0 2.0 1.0 0.7 Maximum engine horsepower is the nameplate rating of the engine and does not account for deration. Note: Per Regulation No. 7, Section XVII.B.5, internal combustion engines that are subject to an emission standard or an emissions control requirement in a federal maximum achievable control technology ("MACT") standard under 40 CFR Part 63, a Best Available Control Technology ("BACT") limit, or a New Source Performance Standard under 40 CFR Part 60 are not subject to this Section XVII. OPERATING & MAINTENANCE REQUIREMENTS 15. 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.) AIRS ID: 123/9F6A/005 Page 4 of 15 COMPLIANCE TESTI " • D • " P f Public Health and Environment Air Pollution Control Division Periodic Testing Requirements 16. This engine is subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan a are subject to Division approv Operating Scenarios may be subj Attachment A. ed by the Division. Revisions to your O&M plan ep -cements of this unit completed as Alternative to additional testing requirements as specified in ADDITIONAL REQUIREMENTS 17. All previous versions of this permit are cancelled upon issuance of this permit. 18. This permit replaces the following permits and/or points, which are cancelled upon issuance of this permit. Existing Permit No. Existing Emission Point New Emission Point GP02 application (permit not issued) 123/9F6A/005 123/9F6A/005 19. 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 AIRS ID: 123/9F6A/005 Page 5 of 15 f Public Health and Environment Air Pollution Control Division d. Wheneve=°`•-rmit I io ` e t b .e -.; or e. No later than 30 days before the existing APEN expires. 20. Federal regulatory program requirements (i.e. PSD or NANSR) shall apply to this source at any such time that this soures major solely by virtue of a relaxation in any permit condition. Any relaxatio ' h t in eases the potential to emit above the applicable Federal program threshold will req e a full review of the source as though construction had not yet commenced on the sou a-. The source shall not exceed the Federal program threshold until a permit is granted. "< S gulation No. 3 Part D). GENERAL TERMS AND CONDITIONS 21. 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. 22. 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. 23. 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. 24. 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. 25. 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 Qualify Control Commission (AQCC), including failure to meet any express term or condition ofthe 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. 26. 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 AIRS ID: 123/9F6A/005 Page 6 of 15 loradfA�apart -nt f Public Health and Environment Air Pollution Control Division administration. urce ". ct � � E,� to • ntinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 27. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or t °_'- r • u tons of the AQCC may result in administrative, civil or criminal enforcement acti s under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), - 2.1 (criminal penalties), C.R.S. By: Timothy Sharp Permit Engineer Permit Histo Issuance Date Description Issuance 1 This Issuance Issued to Bill Barrett Corporation. AIRS ID: 123/9F6A/005 Page 7 of 15 loradepart ent=if Public Health and Environment Air Pollution Control Division Notes to Permit Holder at t - of th . -r nc 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 I its and emission limits contained in this permit are based on the consumption rates requested in th permit application. These limits may be revised upon request of the owner or operator providin•y.here is no exceedance of any specific emission control regulation or any ambient air quality sta ` . 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/aocc-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 # BIN Uncontrolled Emission Rate (Ib/yr) Are the emissions reportable? Controlled Emission Rate (lb/yr) 005 Formaldehyde 50000 A 1,622 Yes 1,622 Methanol 67561 C 349 Yes 349 Acetaldehyde 75070 A 318 Yes 318 Acrolein 107028 A 300 Yes 300 Benzene 71432 A 180 No 180 1,3 -Butadiene 106990 A 76 No 76 Toluene 108883 C 64 No 64 5) The emission levels contained in this permit are based on the following emission factors: Point 005: CAS Pollutant Emission Uncontrolled Ib/MMBtu Factors - g/bhp-hr Emission Controlled Ib/MMBtu Factors — g/bhp-hr NOx 3.7863 13.30 0.1704 0.60 CO 3.1885 11.20 0.4145 1.46 VOC 0.1993 0.70 0.1993 0.70 50000 Formaldehyde 0.0142 0.05 0.0142 0.05 67561 Methanol 0.0031 0.01 0.0031 0.01 75070 Acetaldehyde 0.0028 0.01 0.0028 0.01 107028 Acrolein 0.0026 0.01 0.0026 0.01 71432 Benzene 0.0016 0.01 0.0016 0.01 106990 1,3 -Butadiene 0.0007 0.00 0.0007 0.00 AIRS ID: 123/9F6A/005 Page 8 of 15 f Public Health and Environment Air Pollution Control Division CAS Pollutant io Uncontrolled lb/MMBtu gym. - g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr 108883 Toluene 0.0006 0.00 0.0006 0.00 Emission factors are based on a Br c Fuel Consumption Factor of 7744 Btu/hp-hr, a site - rated horsepower value of 1680, aa el eat value of 962 Btu/scf. Emission Factor Sources: CAS Pollutant Untrolled EFSource Controlled EF Source NOx ma - urer manufacturer CO manufacturer manufacturer VOC manufacturer manufacturer 50000 Formaldehyde manufacturer manufacturer 67561 Methanol AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 75070 Acetaldehyde AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 107028 Acrolein AP -42; Table 3.2-3 (7/2000); Natural Gas No Control 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 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 facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, NOx, nHEX PSD/NANSR Synthetic Minor Source of: VOC, NOx, CO 8) 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 Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A — Subpart Z AIRS ID: 123/9F6A/005 Page 9 of 15 oradepart--nt '•f Public Health and Environment Air Pollution Control Division MACT 63.600-6 . • 9 ubpa A A — u • pa • DD MACT 63.1200-63.1439 Subpart EEE — Subpart PPP MACT 63.1440-63.6175 Subpart QQQ — Subpart YYYY MACT 63.6580-63.8830 r • ZZ - Subpart MMMMM MACT 63.8980 -End Sub rt NNNNN — Subpart XX)OCXX 9) 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: 123/9F6A/005 Page 10 of 15 f Public Health and Environment Air Pollution Control Division ALTERNATIVE OPERATING SCENARIOS RECIPROCATING IN 2. Alternative Operating Scenarios L COMBUSTION ENGINES Ocr'ber12, 2012 The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with an engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/9F6A/005 Page 11 of 15 loradepart ent=if Public Health and Environment Air Pollution Control Division 2.1.2 The owner or operatper _; nt ce g 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 - • • • - d compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that i ludes the specific manufacturer, model and serial number and horsepower of the permanent replacemen :-ngine shall be filed with the Division for the permanent replacement engine within 14 calendar days • ` '•mmencing 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 www.colorado.gov/cdphe/air/AOS. 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. Nothing in this AOS shall preclude the Division from taking an action, based on any permanent engine replacement(s), for circumvention of any state or federal PSD/NANSR requirement. Additionally, in the event that any permanent engine replacement(s) constitute(s) a circumvention of applicable PSD/NANSR requirements, nothing in this AOS shall excuse the owner or operator from complying with PSD/NANSR and applicable permitting requirements. 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: www.colorado.dov/cdphe/Dortable-analyzer-monitorind-protocol 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 AIRS ID: 123/9F6A/005 Page 12 of 15 lorad �,y; epart „„ ent f Public Health and Environment Air Pollution Control Division the test results will be mult • • the in the month or year (8760), whichever applies. For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) t� . isting unit is currently subject to or the replacement engine will be subject to, the results of the zest a •e converted to the appropriate units as described in the above -mentioned Portable Analyzer Monito g Protocol document. If the portable analyzer results indicate complia ' e with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, ource 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. AIRS ID: 123/9F6A/005 Page 13 of 15 Lean burn engine catalyst to reduce emissions. f Public Health and Environment Air Pollution Control Division maur : =sig =_ter than 500 hp shall use an oxidation The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer •- .,�ons. The source shall submit copies of the relevant nplicability Reports required under Condition 2.1.2. Emission Standards: Section XVII. E — State -on 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 NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500≤Hp July 1, 2010 1.0 2.0 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, § 1.8 (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 AIRS ID: 123/9F6A/005 Page 14 of 15 epart f Public Health and Environment Air Pollution Control Division A permanent replacement - oca a -- = :r source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT ca r - the testing required by this AOS under Condition 2.2, if approved in advance by the Division, pro uch 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: 123/9F6A/005 Page 15 of 15 Hydrocarbon Liquid Loading APEN - Form APCD-208 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and m x be reed c� esult in longer application processing times. You may be charged an additional APEN fee if the 4PEN I incorrectly or is missing information and requires re -submittal. This APEN is to be used for Hydrocarbon Liquid Loading only. If your emission unit does not fall -into this cate there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: AIRS ID Number: 123 /9F6A / G G [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: Hydrocarbon Loadout - Compression Condensate Tanks [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Bill Barrett Corporation Site Name: Anschutz Equus Farms 4-62-28 NWNW Site Location: NWNW Sec 28, T4N, R62W Mailing Address: (Include Zip Code) 1099 18th Street, Ste 2300 Denver, CO 80202 E -Mail Address2: CDPHE_Corr@billbarrettcorp.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Marsha Sonderfan Phone Number: 303-312-8524 lUse the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 375831 Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev 02/2017 I COLORADO 7 N!e!M63nNrvnment Permit Number: AIRS ID Number: 123 /9F6A/ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑✓ NEW permit OR newly -reported emission source ❑✓ Request coverage under construction permit ❑ Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN Filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Change permit limit O Transfer of ownership3 ❑ Other (describe below) - OR • APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: Compression condensate tank battery with (4) 400 -bbl tanks. Individual permit. Loadout will be controlled. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Hydrocarbon loadout, controlled by ECDs. For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: r / 3/ 5 /2018 Will this equipment be operated in any NAAQS nonattainment area? Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Does this source load gasoline into transport vehicles? Is this source located at an oil and gas exploration and production site? If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Does this source splash fill less than 6750 BBL of condensate per year? Does this source submerge fill less than 16308 BBL of condensate per year? ✓❑ Yes O No O Yes ❑✓ No ❑ Yes 0 No O Yes O No O Yes ❑ No (] Yes ❑ No ❑ Yes ❑✓ No Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 2 I TITZI ` 4 mfn, AT Permit Number: AIRS ID Number: 123 /9F6A/ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: ✓❑ Condensate ❑ Crude Oil ❑ Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded4: 44,051 Bbl/yr Actual Volume Loaded: 36,710 Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth This product is loaded from tanks at this facility into: (eg, "rail tank cars" or "tank trucks") tank trucks If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: 0.6 Average temperature of bulk liquid loading: 52.45 , F True Vapor Pressure Q 860 .16displaced Psia @ 60 °F Molecular weight of vapors Lb/lb-mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Actual Volume s Bbl/yr Loaded : Loaded: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Bbl/yr Product Density: Lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume ft3/truckload Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 3 I 'COLORADO 0.pu[ment°1 Pottle Npglth 6hViln�in9Pt Permit Number: AIRS ID Number: 123 / 9F6At [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Geographical Information Geographical Coordinates (Latitude/Longitude or UTM) 40.287881, -104.337456 operator Stack ID `No'� Discharge Height or,*.Ground Level iFeet) Temp ) Flow Rate (ACFM1 Velocity t/sec)` ECDs 30 -- -- -- Indicate the direction of the stack outlet: (check one) E Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap Section 6 - Control Device Information El Loading occurs using a vapor balance system: Requested Control Efficiency ❑ Combustion Device: Pollutants Controlled: Rating: Type: VOC, I-IAPs 10 ECD Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: MMBtu/ hr Make/Model: (3) Cimarron 7'x30' ECDs 95 98 500 F Waste Gas Heat Content -2520 Btu/scf Constant Pilot Light: El Yes ❑ No Pilot burner Rating 0.1 MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested 0/0 Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO 4 I --a;, ® a`, m;�; - H ales FryVp,nn,_.9{�; .ks Permit Number: AIRS ID Number: 123 /9F6A/ [Leave blank unless APCD has already assigned a permit 4 and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM NA NA SOX NA NA NO NA NA CO NA NA VOC ECDs 95 HAPs ECDs 95 Other: ❑ Using State Emission Factors (Required for GP07) VOC ❑ Condensate 0.236 Lbs/BBL ❑ Crude 0.104 Lbs/BBL Benzene n -Hexane 0.00041 Lbs/BBL 0.0036 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? 2018 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual Emissions, ., Requested Annual Permit mission Ei_imit(sj .; Uncontrolled (Tons/year) Controlled5 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) PM SOX NOx 0.01 0.01 VOC 0.29999 lb/bbl AP -42 5.51 0.28 6.61 0.33 CO 0.04 0.05 Benzene Toluene Ethylbenzene Xylenes n -Hexane 0.00588 lb/bbl AP -42, ProMax 0.11 0.01 0.13 0.01 2,2,4- Trimethylpentane Other: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLOaAbo tit;:meefAta 5 � _ `R!�R6 h&��vr!onmx�t a (° Permit Number: AIRS ID Number: 123 /9F6A/ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. j- Signature of Legally Authorized Person (not a vendor or consultant) Date Marsha Sonderfan EHS Specialist Name (print) Title Check the appropriate box to request a copy of the: E Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term,. or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $250 as applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 ----- COLORADO fitOb Fnvt,semetri Hydrocarbon Liquid Loading APEN - Form APCD-208 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, in ding updates. An application with missing information may be determined incomplete and may be retur d or longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Hydrocarbon Liquid Loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: U e0 ZZA AIRS ID Number: 123 /9F6A /60 �-- [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: Hydrocarbon Loadout - Production Condensate Tanks [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Bill Barrett Corporation Site Name: Anschutz Equus Farms 4-62-28 NWNW Site Location: NWNW Sec 28, T4N, R62W Mailing Address: (Include Zip Code) 1099 18th Street, Ste 2300 Denver, CO 80202 E -Mail Address2: CDPHE_Corr@billbarrettcorp.com Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Marsha Sonderfan Phone Number: 303-312-8524 'Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 375830 Form APCD-208 - Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORADO ntgksoi .auc Permit Number: AIRS ID Number: 123 /9F6A/ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑✓ NEW permit OR newly -reported emission source ❑✓ Request coverage under construction permit ❑ Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN Filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name O Change permit limit O Transfer of ownership3 ❑ Other (describe below) - OR ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ▪ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: New site with 16 wells. Production condensate tank battery with (13) 400 -bbl tanks. Individual permit. Loadout will be controlled. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Hydrocarbon loadout, controlled by ECDs. For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 12/ 6 /2017 / / Will this equipment be operated in any NAAQS nonattainment area? Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Does this source load gasoline into transport vehicles? Is this source located at an oil and gas exploration and production site? If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Does this source splash fill less than 6750 BBL of condensate per year? Does this source submerge fill less than 16308 BBL of condensate per year? 2 Yes El No O Yes ❑✓ No ❑ Yes I] No ❑✓ Yes O No ❑✓ Yes O No ❑✓ Yes O No ❑ Yes ❑✓ No Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 2® COLD RAbo aw�=esynu� Permit Number: AIRS ID Number: 123 /9F6A/ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: ❑✓ Condensate ❑ Crude Oil ❑ Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded: 4 Requested values will become permit Limitations. Requested limit(s) should consider future process growth 1,471,000 Bbl/yr Actual Volume Loaded: 1,226,000 Bbl/yr This product is loaded from tanks at this facility into: (eg, "rail tank cars" or "tank trucks") tank trucks If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: 0.6 Average temperature of bulk liquid loading: 52.45 °F True Vapor Pressure 4.4465 Psia @ 60 °F Molecular weight of displaced vapors 67 Lb/lb-mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: Bbl/yr Actual Volume Loaded: Bbl/yr 4 Requested values will become permit limitations. Requested limit s) should consider future process growth Product Density: Load Line Volume: Lb/ft3 ft3/truckload Vapor Recovery Line Volume ft3/truckload Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 COLORA O Permit Number: AIRS ID Number: 123 /9F6A/ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Geographical Information Geographical Coordinates (Latitude/Longitude or UTM) 40.287881, -104.337456 Operator Stack ID No Discharge Height b gTep Above around Level (Feet) ( f) Flour Rate (ACFId) elocit Vy "{ft/sec) ECDs ECDs 30 -- -- -- Indicate the direction of the stack outlet: (check one) Q Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap Section 6 - Control Device Information ❑ Loading occurs using a vapor balance system: Requested Control Efficiency ❑ Combustion Device: Pollutants Controlled: VOC, HAPs Rating: 10 Type: ECD Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency Minimum Temperature: MMBtu/hr Make/Model: 3) Cimarron 7'x30' ECDs 95 98 500 F Waste Gas Heat Content —2520 Btu/scf Constant Pilot Light: ✓❑ Yes ❑ No Pilot burner Rating 0.1 MMBtu/hr ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested 0 Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 4I COLORADO Deµwnmtd f4E!lc Permit Number: AIRS ID Number: 123 /9F6A/ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): is Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM NA NA SOX NA NA NO„ NA NA CO NA NA VOC ECDs 95 HAPs ECDs 95 Other: ❑ Using State Emission Factors (Required for GP07) VOC ❑ Condensate ❑ Crude 0.236 Lbs/BBL 0.104 Lbs/BBL Benzene n -Hexane 0.00041 Lbs/BBL 0.0036 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? 2018 Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Pollutant Uncontrolled Emission Factor Emission Factor Units Emission Factor Source (AP -42, Mfg. etc) Actual Annual5Emissions r Requested Annual Permit; ,7,-- - Sion Limas s ' ' Uncontrolled (Tons/year) Controlled5 (Tons/year) ` Uncontrolled (Tons/year) Controlled (Tons/year)' PM SOX NO„ 0.18 0.21 VOC 0.18254 lb/bbl AP -42 111.90 5.59 134.28 6.71 CO 0.81 0.98 Benzene 0.00032 lb/bbl AP -42, Flash 0.20 0.01 0.24 0.01 Toluene Ethylbenzene Xylenes n -Hexane 0.00286 lb/bbl AP -42, Flash 1.75 0.09 2.11 0.11 2,2,4- Trimethylpentane Other: 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 5Annual. emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 .cotoaAba 5 I - --. Het!��.4€nPlrcr+nCnt Permit Number: AIRS ID Number: 123 /9F6A/ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. Signature of Legally Authorized Pers' (not a vendor or consultant) Date Marsha Sonderfan EHS Specialist Name (print) Title Check the appropriate box to request a copy of the: 0 Draft permit prior to issuance ✓l Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $250'as applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-208 -Hydrocarbon Liquid Loading APEN - Rev 02/2017 6I AVCO LOR.4ao a�=, Produced Water Storage Tank(s) APEN - Form APCD-207 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store produced water associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, condensate storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/pacific/cdDhe/air-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 11 ui 067.1D O AIRS ID Number: 123 / 9F6A / 0 0 8' [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Site Name: Bill Barrett -Corporation Anschutz Equus Farms 4-62-28 NWNW Site Location: NWNW Sec 28, T4N, R62W lu Address: 1099 18th Street, Ste 2300 (Include Zip Code) Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Marsha Sonderfan Phone Number: 303-312-8524 E -Mail Address2: CDPHE_Corr@billbarrettcorp.com I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 375829 Amp, COLORADO Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 1 I M.V. Permit Number: AIRS ID Number: 123 / 9F6A / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑✓ NEW permit OR newly -reported emission source ✓❑ Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP05 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN filing fee. OR - • MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership3 ❑ Other (describe below) - OR ▪ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info £t Notes: New site with 16 wells. New water tank battery with (4) 400 -bbl tanks. Cover under individual permit. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: 4 produced water tanks For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 Storage tank(s) located at: 12/6/2017 hours/day 7 days/week 52 weeks/year ✓❑ Exploration & Production (E&P) site ❑ Midstream or Downstream (non EEtP) site Will this equipment be operated in any NAAQS nonattainment area? 0 Yes ■ No Are Flash Emissions anticipated from these storage tanks? 0 Yes • No Are these storage tanks located at a commercial facility that accepts oil production wastewater for processing? Yes No Ill 0 Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? ■ Yes 0 No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No • 0 Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes No 0 ■ Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 COLORADO Me«� 2 l _ ,Nc?4n49�wlart.= Permit Number: AIRS ID Number: 123 / 9F6A / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl /year) Requested Annual Permit Limit' (bbl /year) Produced Water Throughput: 915,000 1,098,000 From what year is the actual annual amount? Tank design: E Fixed roof 2018 ❑ Internal floating roof ❑ External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) PW 4 1,600 11/2017 12/2017 Wells Serviced by this Storage Tank or Tank Battery5 (EEtP Sites On y) API Number Name of Well Newly Reported Well - - See attached addendum ❑ - ❑ - - O O 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The E&P Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.287881, -104.337456 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) ECDs 30 -- -- -- Indicate the direction of the stack outlet: (check one) El Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) O Circular Interior stack diameter (inches): O Square/rectangle O Other (describe): ❑ Upward with obstructing raincap Interior stack width (inches): Interior stack depth (inches): Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 3 COLORADO DcFuin ,,t o!P btic a+nr�?nrmon� Permit Number: AIRS ID Number: 123 / 9F6A / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: % ❑ Combustion Device: Pollutants Controlled: VOC, HAPs Rating: 10 Type: ECD MMBtu/hr Make/Model: (3) Cimarron 7'x30' ECDs Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: 500 F Waste Gas Heat Content: Constant Pilot Light: ❑✓ Yes ❑ No Pilot Burner Rating: —1064 0.1 Btu/scf MMBtu/hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 -Gas/Liquids Separation Technology Information (E&P Sites Only) What is the pressure of the final separator vessel- prior to discharge to the storage tank(s)? 43 psig Describe the separation process between the well and the storage tanks: Stream from wells to (16) high-pressure inlet separators, then to (2) heater treaters, then to produced water tanks. Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 4 COLORADO ➢cpu;mcnt o; "0 cn 14c�:ittk€nu q.._.- Permit Number: AIRS ID Number: 123 / 9F6A / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form6. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) VOC ECDs 95 NOx NA NA CO NA NA HAPs ECDs 95 Other: From what year is the following reported actual annual emissions data? 2018 Criteria Pollutant Emissions Inventory Pollutant Emission Factor6 Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/ ear y ) Controlled Emissions7 (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) VOC 0.0235 lb/bbl Flash 10.75 0.54 12.91 0.65 NOx 0.068 lb/MMBtu AP -42 0.06 0.07 CO 0.31 lb/MMBtu AP -42 0.27 0.32 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor6 Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg. etc) g Uncontrolled Emissions Pounds/ ear (Pounds/year) ) Controlled Emissions7 (Pounds/year) Benzene 71432 0.00034 lb/bbl Flash 307 15 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 0.00109 lb/bbl Flash 997 50 2,2,4- Trimethylpentane 540841 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 Attach produced water laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 5 I COLORADO D,7anm.nt of 1...11. Permit Number: AIRS ID Number: 123 / 9F6A / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP05 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. Signature of Legally Authorized Person Thot a vendor or consultant) Marsha Sonderfan Date EHS Specialist Name (print) Title Check the appropriate box to request a copy of the: ® Draft permit prior to issuance ® Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 07/2017 6 I COLORADO ❑u.u.ns aerau. }{e,3t�Cb FSev:SP�ept E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Forml Company Name: Bill Barrett Corporation Source Name: Anschutz Equus Farms 4-62-28 NWNW Produced Water Tanks Emissions Source AIRS ID2: 123 / 9F6A /CO S Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 -123 - 42738 Anschutz Equus Farms 4-62-29-2417C 05 -123 - 42734 Anschutz Equus Farms 4-62-29-0916C ►5 05 -123 - 43687 Anschutz Equus Farms 4-62-29-0801CS ►.1 05 - 123 - 43682 Anschutz Equus Farms 4-62-29-0801CNB .1 05 - 123 - 42730 Anschutz Equus Farms 4-62-28-3225C ►5 05 -123 - 42724 Anschutz Equus Farms 4-62-28-1724C ►� 05 -123 - 42740 Anschutz Equus Farms 4-62-28-1609C ►5 05 -123 - 43686 Anschutz Equus Farms 4-62-28-0108CS /5 05 - 123 - 43694 Anschutz Equus Farms 4-62-28-0108CNB 05 -123 - 42723 Anschutz Equus Farms 4-62-29-2532CN L 05 -123 - 42732 Anschutz Equus Farms 4-62-29-2532CS /1 05 -123 - 42733 Anschutz Equus Farms 4-62-29-4033C /1 05 - 123 - 42727 Anschutz Equus Farms 4-62-29-4148C -w 05 05 - 123 - 42735 Anschutz Equus Farms 4-62-28-3240C ►ZI 05 -123 - 42728 Anschutz Equus Farms 4-62-28-3340C @ 05 - 123 - 42744 Anschutz Equus Farms 4-62-28-4841C ►i4 - - ❑ - - ❑ - - ❑ - - ❑ Footnotes: 1 Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 10 AP FormAPCD-212-EP-StorageTank-APEN-Addendum.docx Condensate Storage Tank(s) APEN - Form APCD-205 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store condensate associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/pacific/cdphe/air-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 1-c6 g 674)1 AIRS ID Number: 123 / 9F6A / g Oct [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Bill Barrett Corporation Site Name: Anschutz Equus Farms 4-62-28 NWNW Site Location: NWNW Sec 28, T4N, R62W Mailing Address: (Include Zip Code) 1099 18th Street, Ste 2300 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Marsha Sonderfan Phone Number: 303-312-8524 E -Mail Address2: CDPHE_Corr@billbarrettcorp.com ' Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 31 828 Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 1 I AV COLORADO ueuma'tlw onm n* Permit Number: AIRS ID Number: 123 / 9F6A / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ✓❑ NEW permit OR newly -reported emission source ✓❑ Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP01 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN filing fee. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) El Change in equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership3 ✓❑ Other (describe below) - OR - • APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - DI APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: "Compression condensate tank battery" Condensate from compression processes. Tank battery with (4) 400 -bbl tanks. Cover under individual permit. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: For existing sources, operation began on: (4) 400 -bbl condensate tanks For new or reconstructed sources, the projected start-up date is: 3/5/2018 Normal Hours of Source Operation: 24 hours/day 7 days/week 52 Storage tank(s) located at: ❑✓ Exploration & Production (E&P) site weeks/year ❑ Midstream or Downstream (non EEtP) site Will this equipment be operated in any NAAQS nonattainment area? 0 Yes • No Are Flash Emissions anticipated from these storage tanks? • Yes • No Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? • Yes ■ No If "yes", identify the stock tank gas -to -oil ratio: 0.0067 m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No • A Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes No 0 ■ Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 2 I 407 COLORADO v>a.,rm2E!WgV , xe,,:in4 .. v r?1.mam Permit Number: AIRS ID Number: 123 / 9F6A / [Leave blank unless APCD has already assigned a permit ft and AIRS ID] Section 4 - Storage Tank(s) Information Condensate Throughput: Actual Annual Amount (bbl/year) 36,710 Requested Annual Permit Limit4 (bbl /year) 44,051 From what year is the actual annual amount? 2018 Average API gravity of sales oil: 73.1 degrees ❑ Internal floating roof Tank design: ['Fixed roof RVP of sales oil: 17.6 psi ❑ External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) COMP 4 1,600 11/2017 12/2017 Wells Serviced by this Storage Tank or Tank Battery5 (EEP Sites On y) API Number Name of Well Newly Reported Well See attached addendum ❑ Ei 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The E&P Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.287881, -104.337456 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) ECDs 30 -- -- -- Indicate the direction of the stack outlet: (check one) E Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular ❑ Square/rectangle ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack width (inches): Interior stack depth (inches): Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 3 COLORADO ❑eCarn'zut ofQ.uuc 11,4t , 4, Ga;,,nme.0 Permit Number: AIRS ID Number: 123 / 9F6A / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Vapor ❑ Recovery Unit (VRU): Size: Make/Model: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): ❑ Combustion Device: Pollutants Controlled: VOC. HAPs Rating: 10 Type: ECD Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: Minimum Temperature: 500 F MMBtu/hr Make/Model: (3) Cimarron 7'x30' ECDs 95 98 % Waste Gas Heat Content: Constant Pilot Light: ✓❑ Yes ❑ No Pilot Burner Rating: —2746 0.1 Btu/scf MMBtu/hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 -Gas/Liquids Separation Technology Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 8 psig Describe the separation process between the well and the storage tanks: Inlet gas stream to (2) high-pressure inlet separators, gas to compression, liquids go to (1) heater treater, then (1) vapor recovery tower (VRT), then to condensate storage tanks. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 4 COLORADO 77 D...tb n r PutLc Permit Number: AIRS ID Number: 123 / 9F6A / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form6. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) VOC ECDs 95 NOx NA NA CO NA NA HAPs ECDs 95 Other: From what year is the following reported actual annual emissions data? 2018 Criteria Pollutant Emissions Inventory Pollutant Emission Factor° Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions? (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) VOC 6.171 lb/bbl ProMax 113.27 5.66 135.93 6.80 NOx 0.068 Ib/MMBtu AP -42 0.31 0.37 CO 0.31 Ib/MMBtu AP -42 1.42 1.71 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service CAS (CAS) Number Emission Factor6 Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions Pounds/ ear ( y ) Controlled Emissions7 (Pounds/year) Benzene 71432 0.0145 lb/bbl ProMax 533 27 Toluene 108883 0.0093 lb/bbl ProMax 340 17 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 0.1275 lb/bbl ProMax 4,681 234 2,2,4- Trimethylpentane 540841 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 Attach condensate liquid laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 5i COLORADO Des+rm:,nt of r wk H au n I, n.v�rov�,n, . kb Permit Number: AIRS ID Number: 123 / 9F6A / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP01 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. Vv C Signature of Legally Authorized Person (n t a vendor or consultant) w r -Lk( Date Marsha Sonderfan EHS Specialist Name (print) Title Check the appropriate box to request a copy of the: 0✓ Draft permit prior to issuance ✓0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 COLORADO n�y,.V.X. vsuc 6 I - �!aunaA nAe�n,an, Condensate Storage Tank(s) APEN - Form APCD-205 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store condensate associated with oil and gas industry o emission source does not fall into this category, there may be a more specific APEN available f crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/pacific/cdohe/air-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: i D W 0-222 AIRS ID Number: 123 / 9F6A / d Q [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Bill Barrett Corporation Site Name: Anschutz Equus Farms 4-62-28 NWNW Site Location: NWNW Sec 28, T4N, R62W MailingAddress: Zip Code) (Include 1099 18th Street, Ste 2300 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Marsha Sonderfan Phone Number: 303-312-8524 E -Mail Address2: CDPHE_Corr@billbarrettcorp.com ' Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Pemlits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 375827 COLORADO I A�IDePtnaanlNAtfitle VV HntAbEnwonmsnt Permit Number: AIRS ID Number: 123 / 9F6A / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ✓❑ NEW permit OR newly -reported emission source ✓❑ Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP01 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $250 must be submitted along with the APEN filing fee. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership' E Other (describe below) -OR - ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info a Notes: "Production condensate tank battery" - New site with 16 wells. Tank battery with (13) 400 -bbl tanks. Cover under individual permit. 3 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: (13) 400 -bbl condensate tanks For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: Storage tank(s) located at: 24 hours/day 12/6/2017 7 ❑✓ Exploration Et Production (EEtP) site days/week 52 weeks/year ❑ Midstream or Downstream (non EEtP) site Will this equipment be operated in any NAAQS nonattainment area? 0 Yes • No Are Flash Emissions anticipated from these storage tanks? • Yes ■ No Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? p Yes • No If "yes", identify the stock tank gas -to -oil ratio: 0.0022 m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)• 805 series rules? If so, submit Form APCD-105. Yes No p Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? Yes No 0 ■ Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 (COLORADO 2 I Oe utfr,i o!h5U }fe.,:N4a.Nrcq,-gym Permit Number: AIRS ID Number: 123 / 9F6A / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl/year) Requested Annual Permit Limit4 (bbl /year) Condensate Throughput: 1,226,000 From what year is the actual annual amount? 2018 Average API gravity of sales oil: 38.1 degrees ❑ Internal floating roof Tank design: ❑✓ Fixed roof 1,471,200 RVP of sales oil: 8.7 psi ❑ External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) COND D 13 5,200 11/2017 12/2017 Wells Serviced by this Storage Tank or Tank Battery' (EEP Sites On!y) API Number Name of Well I Newly Reported Well See attached addendum ❑ El El 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The EEtP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.287881, -104.337456 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) ECDs 30 -- -- -- Indicate the direction of the stack outlet: (check one) 0 Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular ❑ Square/rectangle ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack width (inches): Interior stack depth (inches): Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 [COLORADO 3 I - in�y,.e neor�rau� �msM� • f Permit Number: AIRS ID Number: 123 / 9F6A / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Vapor ❑ Recovery Unit (VRU): Size: Make/Model: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): ❑✓ Combustion Device: Pollutants Controlled: VOC, HAPs Rating: 10 MMBtu/hr Type: ECD Make/Model: (3) Cimarron 7'x30' ECDs Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: 500 F Waste Gas Heat Content: -2520 Btu/scf MMBtu/hr Constant Pilot Light: ✓❑ Yes ❑ No Pilot Burner Rating: 0.1 ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 -Gas/Liquids Separation Technology Information (E£tP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 7 psig Describe the separation process between the well and the storage tanks: Stream from wells to (16) high-pressure inlet separators, then to (2) heater treaters, then to (5) vapor recovery towers (VRTs) then to condensate storage tanks. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 4 I COLORADO new cns of Public Permit Number: AIRS ID Number: 123 / 9F6A / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form6. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant - Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) VOC ECDs 95 NOx NA NA CO NA NA HAPs ECDs 95 Other: From what year is the following reported actual annual emissions data? 2018 Criteria Pollutant Emissions Inventory Pollutant Emission Factor6 Actual Annual Emissions Requested Annual Permit Emission Limit(s)4 Uncontrolled Basis Units Source (AP -42, Mfg. etc) ) Uncontrolled Emissions (Tons/year) Controlled Emissions7 (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) VOC 0.8803 lb/bbl Flash 539.65 26.98 647.58 32.38 NOx 0.068 lb/MMBtu AP -42 0.93 1.10 CO 0.31 lb/MMBtu AP -42 4.22 5.01 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor6 Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg. etc) g Uncontrolled Emissions Pounds/ ear (Pounds/year) ) Controlled Emissions7 (Pounds/year) Benzene 71432 0.0016 lb/bbl Flash 1,907 95 Toluene 108883 0.0008 lb/bbl Flash 933 47 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 0.0138 lb/bbl Flash 16,927 846 2,2,4- Trimethylpentane 540841 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 Attach condensate liquid laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 7 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 COLORADO �ro,o 5I *,ra�3m�„ Permit Number: AIRS ID Number: 123 / 9F6A / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under General Permit GP01 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. 1 -Mar- t% Signature of Legally Authorized Person (not a endor or consultant) Date Marsha Sonderfan EHS Specialist Name (print) Title Check the appropriate box to request a copy of the: Draft permit prior to issuance Q✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit registration fee of $250, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 07/2017 61 AV COLORADO Nc:,010 #nnmo!nm+ •• E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Form' Company Name: Bill Barrett Corporation Source Name: Anschutz Equus Farms 4-62-28 NWNW Production Condensate Tanks Emissions Source AIRS ID2: 123 / 9F6A / p lD Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 -123 - 42738 Anschutz Equus Farms 4-62-29-2417C I 05 -123 - 42734 Anschutz Equus Farms 4-62-29-0916C I 05 -123 - 43687 Anschutz Equus Farms 4-62-29-0801CS /5 05 -123 - 43682 Anschutz Equus Farms 4-62-29-0801CNB // 05 -123 - 42730 Anschutz Equus Farms 4-62-28-3225C 05 -123 - 42724 Anschutz Equus Farms 4-62-28-1724C ►5 05 -123 - 42740 Anschutz Equus Farms 4-62-28-1609C 05 -123 - 43686 Anschutz Equus Farms 4-62-28-0108CS ►.t 05 -123 - 43694 Anschutz Equus Farms 4-62-28-0108CNB I 05 -123 - 42723 Anschutz Equus Farms 4-62-29-2532CN @ 05 -123 - 42732 Anschutz Equus Farms 4-62-29-2532CS /1 05 -123 - 42733 Anschutz Equus Farms 4-62-29-4033C @ 05 -123 - 42727 Anschutz Equus Farms 4-62-29-4148C @ 05 -123 - 42735 Anschutz Equus Farms 4-62-28-3240C 0 05 -123 - 42728 Anschutz Equus Farms 4-62-28-3340C 05 -123 - 42744 Anschutz Equus Farms 4-62-28-4841C I - - ❑ - - ❑ - - ❑ - - ❑ Footnotes: 1 Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 6 AP_FormAPCD-212-EP-StorageTank-APEN-Addendum.docx ,K Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, updates. An application with missing information may be determined incomplete and may be returned o longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Qov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: IcuiL (f -2:2D' [Leave blank unless APCD has already assigned a permit # and AIRS ID] AIRS ID Number: 123 /9F6A /003 Section 1 - Administrative Information Company Name: Site Name: Site Location: Bill Barrett Corporation Anschutz Equus Farms 4-62-28 NWNW Site Location NWNW Sec 28, T4N, R62W County: Weld Mailing Address: (Include Zip Code) 1099 18th Street, Ste 2300 Portable Source Home Base: Denver, CO 80202 NAICS or SIC Code: 1311 Permit Contact: Marsha Sonderfan Phone Number: 303-312-8524 E -Mail Address2: CDPHE_Corr@billbarrettcorp.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 375832 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 1 ,p P U Hh11444Attn�4Nnln! Permit Number: AIRS ID Number: 123 / 9F6A / 003 :3 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action El NEW permit OR newly -reported emission source (check one below) r❑ STATIONARY source ❑ PORTABLE source ❑✓ Request coverage under a Construction Permit O Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR- ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name O Add point to existing permit ❑✓ Change permit limit O Transfer of ownership4 p Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ▪ APEN submittal for permit-exempt/grandfathered source O Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info Et Notes: Revised Emission Factor for NOx, previously covered by GP02, request individual permit 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? No If yes, provide the Company Equipment Identification No. General description of equipment and purpose: used for natural gas compression C-12839/1 Waukesha L7044GSI Compressor Engine For existing sources, operation began on: 2/28/18 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://ww.v.colorado.gov/cdphe/attainment) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 25 D Yes ❑ No hours/day 7 days/week 52 weeks/year Mar -May: 25 June -Aug: 25 Sept -Nov: 25 ;'I Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 Avg COLORADO 2, I Mk: Z=111= iii. Permit Number: AIRS ID Number: 123 /9F6A / 003 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: ❑r Compression What is the maximum number of hours this engine will be used for emergency back-up power? Engine Make: Waukesha NA hours/year Engine Model: L7O44GSI Serial Number': C-12839/1 What is the maximum designed horsepower rating? 1680 hp What is the engine displacement? 9.6 l/cyl What is the maximum manufacturer's site -rating? hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,744 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke 0 4 -Stroke Combustion: ❑ Lean Burn ❑✓ Rich Burn Ignition Source: ❑✓ Spark ❑ Compression Aspiration: ❑ Natural ❑✓ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ✓❑ Yes ❑ No If yes, what type of AFRC is in use? ❑ O2 Sensor (mV) ❑NOX Sensor (ppm) Is this engine equipped with a Low-NOx design? ❑ Yes ❑✓ No Engine Dates: What is the manufactured date of this engine? 1/21/2000 What date was this engine ordered? unknown ❑✓ Other: What is the date this engine was first located to Colorado? 2O17 What is the date this engine was first placed in service/operation? unknown What is the date this engine commenced construction? unknown What is the date this engine was last reconstructed or modified? NA Is this APEN reporting an AOS replacement engine? ❑ Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 „COLORADO 3 o Hcatih6 F.vitanment Permit Number: AIRS ID Number: 123 /9F6A / 003 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.287881/-104.337456 Stack ID"No." Discharge Height Operator Temp. evel Above Ground L (Feet) (°F) Flow Rate '` (ACFM) `" Velocity (ft/sac) 25 1,179 8,162 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 15 ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100% Load (SCF/ hour) Actual Annual Fuel Use . (MMSCF/ year) - Requested Annual Permit Limit' (MMSCF/year) 13,524 119 From what year is the actual annual amount? NA Indicate the type of fuel used8: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑r Field Natural Gas Heating value: 962 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 :COLORADO Hcallh Fr F :vito=t Permit Number: AIRS ID Number: 123 /9F6A / 003 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.5 SOX NO X NSCR/AFRC 95.5% VOC CO NSCR/AFRC 87 Other: HAPs: NSCR/AFRC Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions9 Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) 0.01941 lb/mmBtu AP -42 Table 3.2-3 NA PM 10 0.01941 lb/mmBtu AP -42 Table 3.2-3 NA PM2.5 0.01941 lb/mmBtu AP -42 Table 3.2-3 NA SOX 0.00059 lb/mmBtu AP -42 Table 3.2-3 NA NOx 13.30 g/hp-hr Manuf./Reg 7Table 1 215.76 9.73 VOC 0.70 g/hp-hr Manuf./Reg 7 Table 1 11.36 11.36 CO 11.50 g/hp-hr Manuf./Reg 7 Table 1 181.69 24.33 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: ❑✓ Yes ❑ No Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions9 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions Controlled (Pounds/year) Formaldehyde 50000 0.05 g/hp-hr Manufacturer Data 1622 NA Acetaldehyde 75070 0.0028 lb/mmBtu AP -42 Table 3.2-3 318 NA Acrolein 107028 0.0026 lb/mmBtu AP -42 Table 3.2-3 300 NA Benzene 71432 Other: 67561 0.0031 lb/mmBtu AP -42 Table 3.2-3 349 NA 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 5 COLORADO , bcoarmcntcfPubUc • Hca,Ith a Env:tonmmt .F; Permit Number: AIRS ID Number: 123 /9F6A /003 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. Signature of Legally Authorized Person' not a vendor or consultant) Date Marsha Sonderfan EHS Specialist Name (please print) Title Check the appropriate box to request a copy of the: ✓❑ Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 COLORADO Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 6 I .: 12/20/2018 State.co.us Executive Branch Mail - Air Permit Application; Anschutz Equss Farms 4-62-28 . STATE OF • COLORADO Sharp - CDPHE, Timothy <timothy.sharp@state.co.us> Air Permit Application; Anschutz Equss Farms 4-62-28 Marsha Sonderfan <msonderfan@hpres.com> Wed, Aug 15, 2018 at 11:51 AM To: "Sharp - CDPHE, Timothy" <timothy.sharp@state.co.us>, CDPHE_Corr <CDPHE_Corr@hpres.com> Hi Tim, We had previously provided the spec sheets with the applications for the engines original coverage under GP02, so we did not include them with this submittal to avoid repeat. My apologies if this has caused some confusion. I have attached the manufacturer and catalyst spec sheets that were provided with the original applications. I do also now notice that the uncontrolled CO on the APEN is listed as 11.5 g/hp-hr, but it is calculated based on 11.2 g/hp-hr CO as reflected on the Waukesha spec sheet. Please redline the uncontrolled basis emission factor for CO to 11.2 g/hp-hr. Please let me know if this is sufficient data, or if this does not address your concerns. Thanks, Marsha Sonderfan High Point Resources Corporation 303-312-8524 Please note our new email address! MSonderfan@hpres.com From: Sharp - CDPHE, Timothy <timothy.sharp@state.co.us> Sent: Monday, August 13, 2018 9:16 AM To: Marsha Sonderfan <msonderfan@hpres.com>; CDPHE_Corr <CDPHE_Corr@hpres.com> Subject: Air Permit Application; Anschutz Equss Farms 4-62-28 [Quoted text hidden] 2 attachments ito 04c 7044 Spec Sheet.pdf 247K https://mail.google.com/mail/u/0?ik=01917fb514&view=pt&search=all&permmsgid=msg-f%3A1608888362405512573&simpl=msg-f%3A16088883624... 1/2 Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit ALL sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled ut incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a die ignition engine or your emission unit does not fall into the RICE category, there may be a more speciiiZrAPENr your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Qov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: AIRS ID Number: 123 /9F6A /002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Site Name: Bill Barrett Corporation Anschutz Equus Farms 4-62-28 NWNW Site Location: NWNW Sec 28, T4N, R62W Mailing Address: (Include Zip Code) 1099 18th Street, Ste 2300 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Marsha Sonderfan Phone Number: 303-312-8524 E -Mail Address2: CDPHE_Corr@billbarrettcorp.com i Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 31583 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 1 I _ _ Department d F [atnc Permit Number: N AIRS ID Number: 123 /9F6A / 002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] :3 Section 2 - Requested Action El NEW permit OR newly -reported emission source (check one below) ❑✓ STATIONARY source ❑ PORTABLE source ❑✓ Request coverage under a Construction Permit O Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR- (] MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O Change company name O Add point to existing permit ❑✓ Change permit limit O Transfer of ownership4 ❑r Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El APEN submittal for permit-exempt/grandfathered source O Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info a Notes: Revised Emission Factor for NOx, previously covered by GP02, request individual permit 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? No If yes, provide the Company Equipment Identification No. C -13678/1A/1 General description of equipment and purpose: Waukesha L7044GSI Compressor Engine used for natural gas compression For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.Rov/cdphe/attainment) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 25 3/12/2018 ✓❑ Yes ❑ No hours/day 7 days/week 52 weeks/year Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADb 2 I� rwparhamat et Public Nw,. ti Permit Number: AIRS ID Number: 123 /9F6A /002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] .N Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking El Pump El Water Pump El Emergency Back-up El Other: ❑✓ Compression What is the maximum number of hours this engine will be used for emergency back-up power? NA hours/year Engine Make: Waukesha Engine Model: L7044GSI Serial Number': C -13678/1A/1 What is the maximum designed horsepower rating? 1680 hp What is the engine displacement? 9.6 l/cyl What is the maximum manufacturer's site -rating? hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,744 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke p 4 -Stroke Combustion: El Lean Burn ❑✓ Rich Burn Ignition Source: ❑r Spark El Compression Aspiration: El Natural ❑✓ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑✓ Yes ❑ No If yes, what type of AFRC is in use? ❑ 02 Sensor (mV) ❑NOX Sensor (ppm) Is this engine equipped with a Low-NOx design? El Yes El No Engine Dates: What is the manufactured date of this engine? 3/21/2001 What date was this engine ordered? unknown ❑✓ Other: What is the date this engine was first located to Colorado? 2017 What is the date this engine was first placed in service/operation? unknown What is the date this engine commenced construction? unknown What is the date this engine was last reconstructed or modified? NA Is this APEN reporting an AOS replacement engine? El Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO Oepanacne�Publ�c 3 �,� 'e�imsurvo-on,n.n< Permit Number: AIRS ID Number: 123 i9F6A / 002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (LatitudelLongitude or UTM) 40.287881/-104.337456 Operator Stack ID No. Discharge Height .- Above Ground Level (Feet) Temp. (°F) Flow Rate (ACFhi) Velocity (ft/sec) 25 1,179 8,162 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ✓❑ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 15 ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100% Load (SCF/ hour) Actual Annual Fuel Use (MMSCF/ year) Requested Annual Permit Limit? (MMSCF/year) „ . 13,524 119 From what year issthe actual annual amount? NA Indicate the type of fuel used8: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑✓ Field Natural Gas Heating value: 962 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. s If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 4 I '1== =, , Permit Number: AIRS ID Number: 123 i9F6A /002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] • t; Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM 2.5 SOX NO X NSCR/AFRC 95.5% VOC CO NSCR/AFRC 87% Other: HAPs: NSCR/AFRC Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions9 Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) 0.01941 lb/mmBtu AP -42 Table 3.2-3 NA PM10 0.01941 lb/mmBtu AP -42 Table 3.2-3 NA PM2.5 0.01941 lb/mmBtu AP -42 Table 3.2-3 NA SOX 0.00059 lb/mmBtu AP -42 Table 3.2-3 NA NO 13.30 g/hp-hr Manuf./Reg 7 Table 1 215.76 9.73 VOC 0.70 g/hp-hr Manuf./Reg 7 Table 1 11.36 11.36 CO —44,613. it. 2 g/hp-hr Manuf./Reg 7 Table 1 181.69 24.33 eew- Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: 0 Yes ❑ No Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions9 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds/year) Formaldehyde 50000 0.05 g/hp-hr Manufacturer Data Acetaldehyde 75070 0.0028 lb/mmBtu AP -42 Table 3.2-3 Acrolein 107028 0.0026 lb/mmBtu AP-42Table3.2-3 Benzene 71432 Other: 67561 0.0031 lb/mmBtu AP -42 Table 3.2-3 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 5 COLORADO Dcpvment of Public Heath & E vstomneet Permit Number: AIRS ID Number: 123 /9F6A /002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. JkAa _ l - .1i 4f - t.S� Signature of Legally Authorized Per se6 (not a vendor or consultant) Date Marsha Sonderfan EHS Specialist Name (please print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance O Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 coLoRADd 6 IMt' :iIr= 12/20/2018 State.co.us. Executive Branch Mail - Air Permit Application; Anschutz Equss Farms 4-62-28 STATE OF COLORADO Sharp - CDPHE, Timothy <timothy.sharp@state.co.us> Air Permit Application; Anschutz Equss Farms 4-62-28 Marsha Sonderfan <msonderfan@hpres.com> Wed, Aug 15, 2018 at 11:51 AM To: "Sharp - CDPHE, Timothy" <timothy.sharp@state.co.us>, CDPHE_Corr <CDPHE_Corr@hpres.com> Hi Tim, We had previously provided the spec sheets with the applications for the engines original coverage under GP02, so we did not include them with this submittal to avoid repeat. My apologies if this has caused some confusion. I have attached the manufacturer and catalyst spec sheets that were provided with the original applications. I do also now notice that the uncontrolled CO on the APEN is listed as 11.5 g/hp-hr, but it is calculated based on 11.2 g/hp-hr CO as reflected on the Waukesha spec sheet. Please redline the uncontrolled basis emission factor for CO to 11.2 g/hp-hr. Please let me know if this is sufficient data, or if this does not address your concerns. Thanks,. Marsha Sonderfan HighPoint Resources Corporation 303-312-8524 Please note our new email address! MSonderfan@hpres.com From: Sharp - CDPHE, Timothy <timothy.sharp@state.co.us> Sent: Monday, August 13, 2018 9:16 AM To: Marsha Sonderfan <msonderfan@hpres.com>; CDPHE_Corr <CDPHE_Corr@hpres.com> Subject: Air Permit Application; Anschutz Equss Farms 4-62-28 [Quoted text hidden] 2 attachments tom 04c 7044 Spec Sheet.pdf 247K https://mail.google.com/mail/u/0?ik=01917fb514&view=pt&search=all&permmsgid=msg-f%3A1608888362405512573&simpl=msg-f%3A16088883624... 1/2 Reciprocating Internal 'Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including N updates. An application with missing information may be determined incomplete and may be returned or t in longer application processing times. You may be charged an additional APEN fee if the APEN is filled ou incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compressi ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Qov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 'U3�6 AIRS ID Number: 123 /9F6A /005 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Bill Barrett Corporation Site Name: Anschutz Equus Farms 4-62-28 NWNW Site Location: NWNW Sec 28, T4N, R62W Mailing Address: (Include Zip Code) 1099 18th Street, Ste 2300 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Marsha Sonderfan Phone Number: 303-312-8524 E -Mail Address2: CDPHE_Corr@billbarrettcorp.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. 375834 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 1 I Motgl PUnon HeaBR53»vllanmms Permit Number: AIRS ID Number: 123 / 9F6A / 005 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action El NEW permit OR newly -reported emission source (check one below) ✓❑ STATIONARY source ❑ PORTABLE source O Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR- ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit O Change permit limit ❑ Transfer of ownership4 E Other (describe below) -OR- ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info £t Notes: Revised Emission Factor for NOx, previously covered by GP02, request individual permit 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 5 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc)? Yes If yes, provide the Company Equipment Identification No. General description of equipment and purpose: used for natural gas compression C-14789/1 Waukesha L7044GSI Compressor Engine For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: / /www.colorado. Rov/cdphe /attainment) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 25 3/19/18 ❑� Yes ❑ No hours/day 7 days/week 52 weeks/year Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 AV COLORADO 2 I I Mallhbaaviemun.n Permit Number: AIRS ID Number: 123 i9F6A / 005 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking ❑ Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: 0 Compression What is the maximum number of hours this engine will be used for emergency back-up power? NA Engine Make: Waukesha hours/year Engine Model: L7044GSI Serial Number': C-14789/1 What is the maximum designed horsepower rating? 1680 hp What is the engine displacement? 9.6 l/cyl What is the maximum manufacturer's site -rating? hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 7,744 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke 0 4 -Stroke Combustion: ❑ Lean Burn 0 Rich Burn Ignition Source: ❑✓ Spark ❑ Compression Aspiration: ❑ Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? E Yes ❑ No If yes, what type of AFRC is in use? ❑ 02 Sensor (mV) ❑NOX Sensor (ppm) Is this engine equipped with a Low-NOX design? ❑ Yes 0 No Engine Dates: What is the manufactured date of this engine? 11/2003 What date was this engine ordered? unknown 0 Other: What is the date this engine was first located to Colorado? 2017 What is the date this engine was first placed in service/operation? unknown What is the date this engine commenced construction? unknown What is the date this engine was last reconstructed or modified? NA Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO ➢epvtsenv PuMlc r�eai:ns Envtronmam Permit Number: AIRS ID Number: 123 /9F6A 1005 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.287881/-104.337456 Operator Stack ID No. Discharge Height Above Ground Level (Feet) Temp. ('F) . Flow Rate . (ACFM) , Velocity. - (ft/sec) `. . C-14789/1 25 1,179 8,162 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 15 ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate 0 100% Load , (SCFI hour) Actual Annual Fuel Use' (MMSCFI year) , Requested Annual Permit Limit? (MMSCFlyear) . 13,524 119 From what year is the actual annual amount? NA Indicate the type of fuel used8: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑ Field Natural Gas Heating value: 962 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 5s 5' COLORADO Hcdht� L 4vianment Permit Number: AIRS ID Number: 123 / 9F6A / 005 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.5 SOX NOX NSCR/AFRC 95.5 VOC CO NSCR/AFRC 87 Other: Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions9 Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) 0.01941 Ib/mmBtu AP -42 Table 3.2-3 1.11 PM10 0.01941 Ib/mmBtu AP -42 Table 3.2-3 0.54 PM 2.5 0.01941 Ib/mmBtu AP -42 Table 3.2-3 0.54 SOX 0.00059 lb/mmBtu AP -42 Table 3.2-3 0.03 NOx 13.30 g/hp-hr Manuf./Reg 7 Table 1 215.76 9.73 VOC 0.70 g/hp-hr Manuf./Reg 7 Table 1 11.36 11.36 CO 11.2 g/hp-hr Manut./Reg 7 Table 1 181.69 24.33 Does the emissions source have any uncontrolled actual emissions of non -criteria 0 Yes pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: ❑ No Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions9 Uncontrolled Basis Units Source AP -42 Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds/year) Formaldehyde 50000 0.05 g/hp-hr Manufacturer Data Acetaldehyde 75070 0.0028 Ib/mmBtu AP -42 Table 3.2-3 Acrolein 107028 0.0026 lb/mmBtu AP -42 Table 3.2-3 Benzene 71432 Other: 67561 0.0031 lb/mmBtu AP -42 Table 3.2-3 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-2O1 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 5 COLORADO bcparmient of Public Health&acc torment Permit Number: AIRS ID Number: 123 /9F6A /005 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for coverage under general permit GP02, I further certify that this source is and will be operated in full compliance with each condition of general permit GP02. iLkatAr- Signature of Legally Authorized Person (clot a vendor or consultant) Date Marsha Sonderfan EHS Specialist Name (please print) Title Check the appropriate box to request a copy of the: ❑ Draft permit prior to issuance ❑ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $1,500, if applicable to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 �1 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 6 I COLORADO bepvementalF hllc Hh:.IST b£avi annn. 12/20/2018 State.co.us Executive Branch Mail - Air Permit Application; Anschutz Equss Farms 4-62-28 STATE OF COLORADO Sharp - CDPHE, Timothy <timothy.sharp@state.co.us> Air Permit Application; Anschutz Equss Farms 4-62-28 Marsha Sonderfan <msonderfan@hpres.com> Wed, Aug 15, 2018 at 11:51 AM To: "Sharp - CDPHE, Timothy" <timothy.sharp@state.co.us>, CDPHE_Corr <CDPHE_Corr@hpres.com> Hi Tim, We_had previously provided the spec sheets with the applications for the engines original coverage under GP02, so we did not include them with this submittal to avoid repeat. My apologies if this has caused some confusion. I have attached the manufacturer and catalyst spec sheets that were provided with the original applications. I do also now notice that the uncontrolled CO on the APEN is listed as 11.5 g/hp-hr, but it is calculated based on 11.2 g/hp-hr CO as reflected on the Waukesha spec sheet. Please redline the uncontrolled basis emission factor for CO to 11.2 g/hp-hr. Please let me know if this is sufficient data, or if this does not address your concerns. Thanks, Marsha Sonderfan HighPoint Resources Corporation 303-312-8524 Please note our new email address! MSonderfan@hpres.Com From: Sharp - CDPHE, Timothy <timothy.sharp@state.co.us> Sent: Monday, August 13, 2018 9:16 AM To: Marsha Sonderfan <msonderfan@hpres.com>; CDPHE_Corr <CDPHE_Corr@hpres.com> Subject: Air Permit Application; Anschutz Equss Farms 4-62-28 [Quoted text hidden] 2 attachments ski 04c 7044 Spec Sheet.pdf 247K r https://mail.google.com/mail/u/0?ik=01917fb514&view=pt&search=all&permmsgid=msg-f%3A1608888362405512573&simpl=msg-f%3A16088883624... 1/2 Hello