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Home My WebLink About20193979.tiffPobl,c Revlet-) 12/►ip9 COLORADO Department of Public Health Et Environment Weld County - Clerk to the Board 1150O St PO Box 758 Greeley, CO 80632 November 27, 2019 Dear Sir or Madam: RECEIVED DEC 0 5 2019 WELD COUNTY COMMISSIONERS On November 28, 2019, the Air Pollution Control Division will begin a 30 -day public notice period for Enerplus Resources (USA) Corporation - Canadian Slang Well Pad. 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 &t Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Public Notice Coordinator 4300 Cherry Creek Drive S., Denver, Co 80246-1530 P 303-692-2000 www.colorado.gov/cdphe Jared Polis, Governor I Jill Hunsaker Ryan, MPH, Executive Director CC'. PI..Ct P), HI..(uc), pwattisi avcw), o&(3m) l2/09 /s9 A.-:-(O4-1of c zoW979 a Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Enerplus Resources (USA) Corporation - Canadian Slang Well Pad - Weld County Notice Period Begins: November 28, 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: Enerplus Resources (USA) Corporation Facility: Canadian Slang Well Pad Well Pad Facility SESW SEC 36 T8N R67W Weld County The proposed project or activity is as follows: Modification to existing well pad equipment including (separator, loadout, storage tanks, engine); addition of 2 engines for power generation and gas -lift. 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 19WE0536 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.Rov/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 (COLORADO Department of Finale Health Cr Environment Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Timothy Sharp Package If: 397749 Received Date: 4/30/2019 Review Start Date: 8/1/2019 Section 01 - Facility Information Company Name: County AIRS ID: Enerplus Resources (USA) Corporation Quadrant Section Township Range 123 Weld SESW 3E, EN 57 Plant AIRS ID: 9F50 Facility Name: Canadian Slang Well Pad Physical Address/Locatio SESW quadrant of Section 36, Township 8N, Range 67W, in Weld County, Colorado 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?on Monoxide (CO) Section 02 - Emissions Units In Permit Application Pa iculate Matter (PM) ne (NOx & VOC) AIRs Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks Natural Gas RICL GLENG01 19WE0536 Permit Initial Issuance Crude Oil Tank TANKS 17WE1204 Permit Modification Hydrocarbon Liquid Loading LOAD 17WE1205 Permit Modification Separator Venting SEPARATOR 17WE1206 Permit Modification Natural Gas RICE GEN01 19WE0537 yes Permit Initial Issuance 008(tbd) Natural Gas RICE TBD yes TBD CP1 Permit Initial Issuance ADDITIONAL APEN sent during processing Section 03 - Description of Project Modification to existing WPF. Converting existing GP02 permits to individual permits. Updating process and emission limits for new production/weil(s). Adding point 008. Section 04 - Public Comment Requirements Is Public Comment Required? If yes, why? Section 05 - Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? 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? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) 502 NOx Is this stationary source a major source? If yes, explain what programs and which pollutants her€ SO2 Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) CO VOC PM2.5 PM10 TSP HAPs No NOx CO VOC J PM2.5 PM10 TSP HAPs Crude Oil Storage Tank(s) Emissions Inventory Section 01 - Administrative Information (Facility AIRs ID: 13 County Plant 0O4 Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Three (3) 400 -bbl fixed roof crude oil storage tanks. Two (2) enclosed combustors (GCO Beast 3200) 9., Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput = Secondary Emissions- Combustion Device(s) Heat content of waste gas = Volume of waste gas emitted per BBL of liquids produced = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = Barrels (bbl) per year Barrels (bbl) per year Barrels (bbl) per year Btu/scf scf/bbl 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? Actual Crude Oil Throughput While Emissions Controls Operating = "'Secondary emissions are accounted for in point 006 (Separator)'=' 0 MMBTU per year 0 MMBTU per year 0 MMBTU per year Emission Factors Crude Oil Tank Uncontrolled Controlled Emission Factor Source Pollutant (lb/bbl) (lb/bbl) (Crude Oil Throughput) (Crude Oil Throughput) VOC 3.59 0.18 Site Specific E.F. (includes flash) Benzene 0.026 0.001 Site Specific ES. (includes flash) Toluene 0.007 0.0004 Site Specific ES. (includes flash) Site Specific E.F. (includes flash) Site Specific E.F. (includes flash) Site Specific E.F. (includes flash) Site Specific ES. (includes flash) Ethylbenzene 0.001 0.00004 Xylene 0.002 0.0001 n -Hexane 0.154 0.008 224 TMP 0.005 0.0003 Control Device Emission Factor Source Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) (lb/bbl) (waste heat combusted) (Crude Oil Throughput) PM10 PM2.5 NOx CO Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) VOC PM10 PM2.5 NOx CO 242.3 120.1 6.0 242.33 12.12 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene 3510 1740 87 3510 176 988 490 24 988 49 96 48 2 96 5 270 134 7 270 14 n -Hexane 224 TMP 20790 10305 515 20790 1040 736 365 18 736 37 Section 06 - Regulatory Summary Analysis Regulation 3, Parts AM Source requires a permit 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 0000a Storage Tank is not subject to NSPS 0000a Regulation 8, Part E, MACT Subpart HH Storage Tank is not subject to MALT HH (See regulatory applicability worksheet for detailed analysis) 66,913 2 of 5 K:\PA\2O17\17WE12O4.CP2 Crude Oil 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 20 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 14-03 Does the company use a site specific emissions factor to estimate emissions? Yes` If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample of crude oil drawn at the facility being permitted? If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03. Does the company request a control device efficiency greater than 95% for a flare or combustion device? No 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 Applicant used E&P TANKS based on a site -specific pressurized liquid sample (collected 10/9/17) to model flash/working/breathing losses. Secondary emissions (NOx, CO, PM) for all points at the facility are accounted for in point 006, which is acceptable because they all use the same bank of two combustors. Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 004 Process # SCC Code 01 • •04-00342 Fixed Roof Tank, Crude Oil, working•breatfiing.ffashing losses Uncontrolled Emissions Pollutant Factor Control % Units VOC 85.476 95 lb/1,000 gallons crude oil throughput Benzene 0.619 95 lb/1,000 gallons crude oil throughput Toluene 0.174 95 lb/1,000 gallons crude oil throughput Ethylbenzene 0.017 95 lb/1,000 gallons crude oil throughput Xylene 0.048 95 lb/1,000 gallons crude oil throughput n -Hexane 3.667 95 lb/1,000 gallons crude oil throughput 224 TMP 0.130 95 lb/1,000 gallons crude oil throughput 3 of 5 K:\PA\2017\17WE1204.CP2 Crude Oil Storage 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 prior to 4/14/2014 and not modified after 4/14/14 (See PS Memo 14-03 for additional guidance on grandfather applicability)? 2a. If answer to #2 is yes, is the crude oil throughput less than 40,000 gallons per year? 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 prior to 4/14/2014 and not modified after 4/14/14 (See PS Memo 14-03 for additional guidance on grandfather applicability)? 2a. If answer to #2 is yes, is the crude oil throughput less than 40,000 gallons per year? 3. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section II.D.2)? Yes No NA Yep Source requires a permit Colorado Regulation 7, Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this crude oil storage tank' located at an oil and gas exploration and production operation , well production facility, natural gas compressor station3 or natural gas processing plant? 3. Is this crude oil 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 Ye 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 crude oil 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 XV I.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 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"' in 60.111b? 5. Does the storage vessel store a "volatile organic liquid (VOL)"5as 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 pressure6 less than 3.5 kPa (60.110b(b))?; or c. The design capacity is greater than or equal to 75 M3 [^'472 BBL] but less than 151 m3 L950 BBL] and stores a liquid with a maximum true vapor pressure" less than 15.0 kPa(60.110b(b))? No Source Req Go to next Source Req Continue -' Continue -' Go to then Source is si. Source is sL 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 OOOO, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Is this crude oil 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 crude oil 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 crude oil 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] 40 CFR, Part 63, Subpart MACT HH, Oil and Gas Production Facilities 2. 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 enters the natural gas transmission and storage source category or is delivered to a final end user{ (63.760(a)(3))? 1. Is the tank located at a facility that is majors for HAPs? 3. Does the tank meet the definition of "storage vessel"4 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 OOOO? 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 - Record keeping §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 "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 Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Timothy Sharp Package #: 397749 Received Date: 4/30/2019 Review Start Date: 8/1/2019 Section 01 - Facility Information Company Name: County AIRS ID: Enerplus Resources (USA) Corporation Quadrant Section Township Range 123 Weld SESW _ : 67 Plant AIRS ID: Facility Name: 9FS0 Canadian Slang Well Pad Physical Address/Locatio SESW quadrant of Section 36, Township 8N, Range 67W, in Weld County, Colorado 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? pion Monoxide (CO) Section 02 - Emissions Units In Permit Application Pa iculate Matter (PM) e (NOx & VOC) AIRs Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks Natural Gas RICE GLENG01 19WE0536 Permit Initial Issuance Crude Oil Tank TANKS 17WE1204 Permit Modification Hydrocarbon Liquid Loading LOAD 17WE120S Permit Modification Separator Venting SEPARATOR 17WE1206 Permit Modification Natural Gas RICE GEN01 19WE0537 Permit Initial Issuance 008(tbd) Natural Gas RICE TEL TBD Permit Initial Issuance ADDITIONAL APEN sent during processing Section 03 - Description of Project Modification to existing WPF. Converting existing GPU2 permits to individual permits. Updating process and emission limits for new production/well(s). Adding point 008. Section 04 - Public Comment Requirements Is Public Comment Required? If yes, why? Section 05 - Ambient Air Impact Analysis Requirement: Was a quantitative modeling analysis required? 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? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) N c Yes SO2 Is this stationary source a major source? If yes, explain what programs and which pollutants here SO2 Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) NOx NOx CO VOC PM2.5 PM10 TSP HAPs ,f// CO VOC PM2.5 PM10 TSP HAPs i _ R n i Hydrocarbon Loadout Emissions Inventory Section 01 - Administrative Information Facility AIRs ID: 123 County 9F50 Plant 005 Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Is this loadout controlled? Collection Efficiency: Control Efficiency: Loadout of crude oil to tank trucks by submerged fill. ECD Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Hydrocarbon Loadout Actual Volume Loaded = Requested Permit Limit Throughput = Potential to Emit (PTE) Volume Loaded = Vs 100.0 95 95.00 135,000 135,000 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 = Barrels (bbl) per year Barrels (bbl) per year Barrels (bbl) per year Btu/scf 103061 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 Actual Volume Loaded While Emissions Controls Operating = 0 MMBTU per year 0 MMBTU per year 0 MMBTU per year No Factor Meaning Value Units Source S Saturation Factor 0.6 AP -42 Chapter 5.2 Table 5.2-1 Submerged Loading: Dedicated Normal Service (520.6) P True Vapor Pressure 3.4 psia M Molecular Weight of Vapors 50 lb/lb-mol T Liquid Temperature 530 Rankine L Loading Losses 2.397962264 lb/1000 gallons 0.100714415 lb/bbl Component Mass Fraction Emission Factor Units Source Benzene 0.006629 0.000667598 Ib/bbl E&P TANKS Toluene 0.001953 0.000196724 lb/bbl E&P TANKS Ethylbenzene 0.000118 1.18508E-05 lb/bbl E&P TANKS Xylene 0.000698 7.0315E-05 lb/bbl E&P TANKS n -Hexane 0.039089 0.003936851 lb/bbl E&P TANKS 224 TMP 0.001581 0.000159196 lb/bbl E&P TANKS Emission Factors Hydrocarbon Loadout Emission Factor Source Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) (Volume Loaded) (Volume Loaded) VOC 0.10071 5.04E-03 Site Spetilc - AP -42: Chapter S.Z, Equation 1 -.iteSpecific- AP4Z: Chapter 5.2, Equation 1 Situ Specific - AP -42: Chapter 5.?. Equation y Site Specific- AP -4Z: Chapter 5.2, Equation 1 Benzene 0.00067 3.34E-05 Toluene 0.00020 9.84E-06 Ethylbenzene 0.00001 5.93E-07 Xylene 0.00007 3.52E-06 n -Hexane 0.00394 1.97E-04 224 TMP 0.00016 7.96E-06 Control Device Emission Factor Source Uncontrolled Uncontrolled Pollutant (lb/MMBtu) (lb/bbl) (waste heat combusted) (Volume Loaded) PM 10 0.00E+00 P M 2.5 0.00E+00 SOx 0.00E+00 NOx 0.00E+00 CO 0.00E+00 135,000 Barrels (bbl) per year 2 of 4 K:\PA\2017\17WE1205.CP2 Hydrocarbon Loadout Emissions Inventory Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 SOx NOx VOC CO 6.80 6.SU 0 -3,1 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 IMP 90 90 5 27 27 1 2 2 0 9 9 0 531 531 27 21 21 1 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 efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes HAP weight fractions are from E&P TANKS run used to model ER for crude tanks (point 004). Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 005 Process # 01 SCC Code 4-06-001-32 Crude Oil: Submerged Loading Normal Service (S=0.6) Uncontrolled Emissions Pollutant Factor Control % Units VOC 2.3980 0 lb/1,000 gallons transferred Benzene 0.0159 0 lb/1,000 gallons transferred Toluene 0.0047 0 lb/1,000 gallons transferred Ethylbenzene 0.0003 0 lb/1,000 gallons transferred Xylene 0.0017 0 lb/1,000 gallons transferred n -Hexane 0.0937 0 lb/1,000 gallons transferred 224 TMP 0.0038 0 lb/1,000 gallons transferred 3 of 4 K:\PA\2017\17WE1205.CP2 Hydrocarbon Loadout Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements 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.l)? 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 greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? Source is in the Non -Attainment Area 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.l)? 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? S. 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 5 TPY (Regulation 3, Part B, Section II.D.2)? Source requires a permit Yes Yes No No No Yes 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 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. Go to next Go to the n Go to next Go to next Go to next The loadou The loadou Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Timothy Sharp Package #: 397749 Received Date: 4/30/2019 Review Start Date: 8/1/2019 Section 01 - Facility Information Company Name: County AIRS ID: Enerplus Resources (USA) Corporaticr Quadrant Section Township Range 123 Weld SESW 35 EN Plant AIRS ID: Facility Name: 9F50 Canadian Slang Well Pad Physical Address/Locatio SESW quadrant of Section 36, Township 8N, Range 67W, in Weld County, Colorado 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? ca on Monoxide (CO) Section 02 - Emissions Units In Permit Application Pa iculate Matter (PM) e (NOx & VOC) AIRs Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks Separator Venting SEPARATOR 171 E120t) Yes Permit Modification Section 03 - Description of Project Modification to increase throughput. Section 04 - Public Comment Requirements Is Public Comment Required? If yes, why? Section 05 - Ambient Air Impact Analysis Requirement: No Was a quantitative modeling analysis required? 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? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) Yes 5O2 NOx i Is this stationary source a major source? No If yes, explain what programs and which pollutants herE SO2 NOx Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) CO OPEIIMMI CO VOC VOC PM2.5 PM10 TSP HAPs J PM2.5 PM10 TSP HAPs • Separator Venting Emissions Inventory Section 01 - Administrative Information Facility AIRs ID: 123 County 9150 Plant 006 Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Flaring of separator gas until pipeline is tied -in. Two (2) enclosed combustors (GCO Beast 3200 and Questor O5000), and backup Steffes open flare during startup/upset Requested Overall VOC & HAP Control Efficiency %: Limited Process Parameter Gas meter Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Separator Actual Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput = Process Control (Recycling) Equipped with a VRU: No Is VRU process equipment: 93.3 MMscf per year 127.9 MMscf per year 127.9 MMscf per year Secondary Emissions - Combustion Device(s) for Air Pollution Control Overall Combined Heat Value Volume of waste gas emitted per BBL of liquids throughput: Section 04 - Emissions Factors & Methodologies 1394.2 Btu/scf scf/bbl l Description Site -specific gas sample collected 10/9/2017. Using Displacement Equation. Displacement Equation Ex=Q*MW*Xx/C MW 25.32 Weight % Helium 0.0000 CO2 3.7819 N2 2.8504 methane 40.7429 ethane 15.6380 propane 18.2230 isobutane 2.9649 n -butane 8.3417 isopentane 2.1104 n -pentane 2.3272 cyclopentane 0.1224 n -Hexane 0.4758 cyclohexane 0.0568 Other hexanes 0.7355 heptanes 0.8988 methylcyclohexane 0.0935 224-TMP 0.0122 Benzene 0.0410 Toluene 0.0630 Ethylbenzene 0.0864 Xylenes 0.1145 C8+ Heavies 0.3199 Total I'm -. VOC Wt % Ib/Ib-mol 2 of S K:\PA\2017\17WE1206.CP4 Separator Venting Emissions Inventory i inissiun Factors Separator Venting Pollutant Uncontrolled Controlled (Ib/MMscf) (lb/MMscf) Emission Factor Source (Gas Throughput) (Gas Throughput) VOC 24704.73 1235.2365 Extended gas analysis Benzene 27.4143 1.3707 Extended gas analysis Toluene 42.0634 2.1032 Extended gas analysis Extended gas analysis Extended gas analysis Extended gas analysis r -- ' - .: analysis Ethylbenzene 57.7074 2.8854 Xylene 76.4763 3.8238 n -Hexane 317.8895 15.8945 224 TMP 8.1378 0.4069 Primary Control Device Emission Factor Source Uncontrolled Uncontrolled Pollutant (lb/MMBtu) lb/MMscf (Waste Heat Combusted) (Gas Throughput) PM10 0.0075 10.388 AP -42 Table 1.4-2 (PM10/PM., . AP -42 Table 1.4-2 (PM10/PM,2.Ss AP -42 Table 1.4--2 (sox) AP -42 Chapter 13.5 Industrial Flares (PtOx) AP -42 Chapter 13.5 Industrial Flares (CO) PM2.5 0.0075 10.388 SOx 0.0006 0.820 NOx 0.068 94.806 CO _ 0.310 432.202 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) PM10 PM2.5 SOx NOx VOC CO 0.69 0.48 0.48 0.69 0.69 0.69 0.48 0.48 0.69 0.69 0.05 0.04 0.04 0.05 0.05 6.31 4.42 4.42 6.31 6.31 1579.87 1152.60 57.63 1579.87 78.99 28.78 20.16 20.16 28.78 28.78 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 3506 2558 128 3506 175 Toluene 5380 3925 196 5380 269 Ethylbenzene 7381 5385 269 7381 369 Xylene 9731 7136 357 9781 489 n -Hexane 40658 29662 1483 40658 2033 224 TMP 1041 759 38 1041 52 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XVII.B, G Source is subject to Regulation 7, Section XVII.B.2, G Regulation 7, Section XVII.B.2.e The control device for this separator is subject to Regulation 7, Section XVII.B.2.e (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Using Gas Throughput to Monitor Compliance Does the company use site specific emission factors based on a gas sample to estimate emissions? This sample should represent the gas outlet of the equipment covered under this AIRs ID, and should have been collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. Yes aY rs'+ Are facility -wide permitted emissions of V0C greater than or equal to 90 tons per year? If yes, the permit will contain: - An "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. XIS - A "Periodic Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application on an annual basis. Will the operator have a meter installed and operational upon startup of this point? Yes If no, the permit will contain a condition that requires the operator to calculate gas throughput using the liquid throughput until the meter is installed and operational (not to exceed 180 days). This condition will use the "Volume of waste gas emitted per BBL of liquids throughput" (scf/bbl) value in section 03. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling You have indicated above that the monitored process parameter is natural gas vented. The following questions do not require an answer. Section 08 - Technical Analysis Notes No 3 of 5 K:\PA\2017\17WE1206.CP4 Separator Venting Emissions Inventory Only process and emissions limits modifications requested. See note below from previous modification detailing aggrigation of secondary emissions: Secondary emissions (NO; CO, and PM) include gas inflow from the crude oil tanks and the produced water tanks. Thus, the secondary emissions limits on the permit will only be placed on this point 006. This approach is acceptable because a bank of two combustors control all of these sources. The NOx, CO, and PM emission factors entered above reflect this combined setup. Applicant estimated potential tank vapor rate of 14.0 Mscf/d. Pilot gas at 20.8 scf/hr= 0.499 Mscf/d. Combining pilot and tank gas = 14.499 Mscf/d = 5.2922 MMscf/yr. Tank gas heat value: 2623 Btu/scf (verified from E&P TANKS run); pilot gas heat value: 1394.2 Btu/scf. Tank heat input = 2623 * 14.0 = 36.722 MMBtu/d = 13403.53 MMBtu/yr. Applicant also assumed pilot gas heat input of 254.00 MMBtu/yr, calculated by 20.8 Mscfd * 1394 Btu/scf. Combined heat input from tanks and pilot is 13403.53 + 254.00 = 13657.53 MMBtu/yr Y Below are the calculations made for tank vapors and pilot gas: 1 N.1.4:;:.:.;$1! r: 4'i, z.. _'.2sJ �`Y ct" Zr, l':i t`k. _ Y Y 71,0. t4 n 1t l T -t • c z�N Fitll a••3 , n %.r^�1 11 x�1 Itr (? xll�� 11%K..42g •„�'= 9 7 ! ' - X t .i a ts- 1 ut Y S LYr` a Y "1.= J'J 3 N• -1 .1 l _� - 1 l IiC rz-TT I x. 'NNt “'•-•••1'Ir k••�..: y. < n n... .. n • - . '1 " ..• A 1 ♦ Ii. A. 1 1 .11.A w.:' .. - 'l l N..w iN.l 11 Il .1... -.n ..Y- ! Y .. n. Y • . ♦ .. .. r v'-"i-'m_ .: _.. K•:- x... s n•.ava .< 'L f L.z r-L..cF---r'. It 1] .sx- 9r .�u•r�]q� -... u�i ._ >, -.k.LI! . s..a..c. u1..11iN:IziiL im .v.:a lx.. -.vn. .a ce 1 .. :.� ..... '. _ .-`. x—. K ....r'T �. 1 ' .' ". 't1i:3 IX_ .l.Y' This 13657.53 MMBtu/yr is added to the 150852.44 MMBtu/yr contribution from the separator (108.2 MMscf/yr * 1394.2 Btu/scf) to arrive at an overall heat input of 164509.97 MMBtu/yr. This is divided by the total gas flow (5.2922 MMscf/yr + 108.2 Mmscf/yr) to arrive at an overall Btu/scf heat value of 1449.53 Btu/scf, which is entered above in cell B29. Also the calculation formulas in Section 05 were adjusted to include the flow (5.2922 MMscf/yr) from the tanks and pilot. Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 006 Process # SCC Code 01 3-10-001-60 Flares Pollutant PM10 PM2.5 SOx NOx VOC CO Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP Uncontrolled Emissions Factor 10.82 10.82 0.85 98.73 24704.73 450.09 27.41 42.06 57.71 76.48 317.89 8.14 Control % Units 0 Ib/MMSCF 0 lb/MMSCF 0 Ib/MMSCF 0 lb/MMSCF 95 Ib/MMSCF 0 Ib/MMSCF 95 lb/MMSCF 95 Ib/MMSCF 95 lb/MMSCF 95 Ib/MMSCF 95 lb/MMSCF 95 lb/MMSCF 4 of 5 K:\PA\2017\17WE1206.CP4 Separator Venting 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. 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. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section II.D.2)? Source requires a permit Yes Colorado Regulation 7, Section XVII 1. Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014? Source is subject to Regulation 7, Section XVII.B.2, G Section XV I.B.2 — General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XV I.G - Emissions Control Alternative Emissions Control (Optional Section) a. Is this separator controlled by a back-up or alternate combustion device (i.e., not the primary control device) that is not enclosed? Yes The control device for this separator is subject to Regulation 7, Section XVILB.2.e Section XVII.B.2.e — Alternative emissions control equipment Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act., its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," "may," "should," and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations. but this document does not establish legally binding requirements in and of itself. Source Req Source Req Source is si. The control Summary of Preliminary Analysis - NG RICE Company Name Enerplus Resources (USA) Corporation Facility Name Canadian Slang Pad Facility Location SESW SEC 36 T8N R67W Facility Equipment ID GLENG01 Permit No. AIRS Review Date Permit Engineer 19WE0536 123/9F50/002 08/21/2019 timothy sharp Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) Caterpillar, Model G3306TB, Serial Number R6S00735, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 203 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control This emission unit is used for natural gas compression. Natural Gas Consumption Requested (mmscf/yr) 11.46 Requested (mmscf/m) 0.97 Fuel Heat Value (btu/scf) 1394 BSCF (Btu/hp-hr) 8985 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) 8760 Permit limits calculated at (hpy) 8760 Uncontrolled Controlled NOx manuf. catalyst spec VOC manuf. catalyst spec CO manuf. catalyst spec Formaldehyde manuf. catalyst spec SOX 0 No Control TSP 0 No Control PM 10 0 No Control PM2.5 0 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 30.0 2.0 30.0 93.5% VOC 1.4 1.4 1A 0.0% CO 30.0 3.9 r 30.0 86.9% SOx 0.0 0.0 0.0 TSP 0.0 0.0 0.0 PM 10 0.0 0.0 0.0 PM2.5 0.0 0.0 0.0 Total HAPs* 0.0 0.0 0.5 50.0% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (Ib/yr) HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Efficiency Control Formaldehyde 941 470 941 50.0% Acetaldehyde * #DIV/0! Acrolein * * * #DIV/0! Methanol * * * #DIV/0! n -Hexane * * * #DIV/0! Benzene * * * #DIV/0! Toluene * * * #DIV/0! *Uncontrolled requested and controlled requested values are shown only UNCONTROLLED is greater than de minimus for pollutants where REQUESTED Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment not required MACT ZZZZ New/Recon 4SRB less than or equal to 500 HP located at a(n) Area Source Reg Standards 7 XVI I . (g/hp-hr) E NOx: 1.0 CO: 2.0 VOC: 0.7 Reg requirements) 7 XVI.B (Ozone applies? NAA No MACT ZZZZ (area source) Is source this engine requirements? subject to MACT ZZZZ area TBD NSPS JJJJ Is this engine subject to NSPS JJJJ? TBD Note: been JJJJ adopted requriements into Reg are not currently 6. included as permit conditions because the reg has not Comments/Notes Convert from G P02 Summary of Preliminary Analysis - NG RICE Company Name Enerplus Resources (USA) Corporation Facility Name Canadian Slang Pad Facility Location SESW SEC 36 T8N R67W Facility Equipment ID GEN01 Permit No. AIRS Review Date Permit Engineer 19WE0537 123/9F50/007 08/21/2019 timothy sharp Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) Doosan, Model 8.1 L CAC, Serial Number EEPOG-402082, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 199 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control NG Generator Natural Gas Consumption Requested (mmscf/yr) 13.48 Requested (mmscf/m) 1.15 Fuel Heat Value (btu/scf) 1394 BSCF (Btu/hp-hr) 10782 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) 8760 Permit limits calculated at (hpy) 8760 Uncontrolled Controlled NOx manuf. catalyst spec VOC manuf. catalyst spec CO manuf. catalyst spec Formaldehyde manuf. catalyst spec 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 20.8 1.9 20.8 90.8% VOC 1.3 1.1 1.3 21.4% CO 35.0 3.8 35.0 89.0% SOx 0.0 0.0 0.0 0.0% TSP 0.2 0.2 0.2 0.0% PM 10 0.2 0.2 0.2 0.0% PM2.5 0.2 0.2 0.2 0.0% Total HAPs* 0.0 0.0 0.3 31.6% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (lb/yr) HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Efficiency Control Formaldehyde 385 193 385 50.0% Methanol 58 0.0% Acetaldehyde * * 52 0.0% Acrolein * * 49 0.0% Benzene * * 30 0.0% 1,3 -Butadiene * * 12 0.0% Toluene * * 10 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minims Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment not required MACT ZZZZ New/Recon 4SRB less than or equal to 500 HP located at a(n) Area Source Reg Standards 7 XVII.E . (g/hp-hr) E NOx: 1.0 CO: 2.0 VOC: 0.7 Reg 7 XVI.B requirements) (Ozone applies? NAA No MACT ZZZZ (area source) Is source this engine requirements? subject to MACT ZZZZ area TBD NSPS JJJJ Is this engine subject to NSPS JJJJ? TBD Note: been JJJJ adopted requriements into are not 6. currently included as permit conditions because the reg has not Reg Comments/Notes Convert from GP02 Summary of Preliminary Analysis - NG RICE Company Name Enerplus Resources (USA) Corporation Facility Name Canadian Slang Pad Facility Location SESW SEC 36 T8N R67W Facility Equipment ID GLENG02 Permit No. AIRS Review Date Permit Engineer 19WExxxx 123/9F50/008 08/21/2019 timothy sharp Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) Caterpillar, Model 3306TA, Serial Number G6X00250, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 203 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control This emission unit is used for natural gas compression. Natural Gas Consumption 10.69 Requested (mmscf/yr) Requested (mmscf/m) 0.91 Fuel Heat Value (btu/scf) 1394 BSCF (Btu/hp-hr) 8379 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) 8760 8760 Permit limits calculated at (hpy) Uncontrolled Controlled NOx manuf. catalyst spec VOC manuf. catalyst spec CO manuf. catalyst spec Formaldehyde manuf. catalyst spec SOX 0 No Control TSP 0 No Control PM10 0 No Control PM2.5 0 No Control Other Pollutants Describe EF sources - HAPs etc. Describe EF sources - HAPs, etc. Point Summary of Criteria Emissions (tp Uncontrolled Requested Controlled Requested PTE Proposed Efficiency Control NOx 28.3 2.0 28.3 93.1% VOC 1.4 1.4 1.4 0.0% CO 28.3 3.9 28.3 86.1% SOx 0.0 0.0 0.0 TSP 0.0 0.0 0.0 PM 10 0.0 0.0 0.0 PM2.5 0.0 0.0 0.0 Total HAPs* 0.0 0.0 0.5 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 calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (lb/yr) HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Efficiency Control Formaldehyde 980 980 980 0.0% Acetaldehyde #DIV/0! Acrolein * * * #DIV/0! Methanol * * * #DIV/0! n -Hexane * * * #DIV/0! Benzene * * * #DIV/0! Toluene * * * #DIV/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 not required MACT ZZZZ New/Recon 4SRB less than or equal to 500 HP located at a(n) Area Source Reg Standards 7 XVI I . (g/hp-hr) E NOx: 1.0 CO: 2.0 VOC: 0.7 Reg requirements) 7 XVI.B (Ozone applies? NAA No MACT ZZZZ (area source) Is source this engine requirements? subject to MACT ZZZZ area TBD NSPS JJJJ Is this engine subject to NSPS JJJJ? TBD Note: been JJJJ adopted requriements into Reg are not 6. currently included as permit conditions because the reg has not Comments/Notes NG RICE Permit number: Date issued: Issued to: COLORADO Air Pollution Control Division Department of Public Health & Environment CONSTRUCTION PERMIT 17WE 1204 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 2 Enerplus Resources (USA) Corporation Canadian Slang Well Pad 123/9F50 SESW Section 36 T8N R67W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description TANKS 004 Six (6) 400 barrel fixed roof storage vessels used to store crude oil. 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. This construction permit represents final permit approval and authority to operate this emissions source. Therefore, it is not necessary to self -certify. (Regulation Number 3, Part B, Section III.G.5.) EMISSION LIMITATIONS AND RECORDS 2. 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), VOC CO TANKS 004 --- --- 12.1 2.1 Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. COLORADO Mr Pollution Control Division Department of Public Peafth & Elvironment Page 1 of 7 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. 3. 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 TANKS 004 Two (2) enclosed flares (GCO Beast 3200) VOC and HAP PROCESS LIMITATIONS AND RECORDS 4. 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 TANKS 004 Crude Oil throughput 135,000 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 5. 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) 6. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 7. 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: COLORADO Air Pollution Control Division Department of Public Health & Environment Page 2 of 7 • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; 8. 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. 9. 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 10. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the 0&tM plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Periodic Testing Requirements 11. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 12. All previous versions of this permit are cancelled upon issuance of this permit. 13. 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 COLORADO Air Pollution Control Division Department of Public Health & Environment Page 3 of 7 • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. GENERAL TERMS AND CONDITIONS 14. 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. 15. 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. 16. 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. 17. 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. 18. 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. 19. 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. 20. 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 COLORADO Air Pollution Control Division Department of Rsf;tc Heaitf f' Environment Page 4 of 7 Permit History Issuance Date Description Issuance 1 March 1, 2018 Issued to Enerplus Resources (USA) Corporation. Issuance 2 This Issuance Modification issued to Enerplus Resources (USA) Corporation. Final Approval COLORADO Air Pollution Control Division Department of Litblic Health Er F.^.virbnment Page 5 of 7 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) 004 Benzene 71432 2255 113 Toluene 108883 664 33 Ethylbenzene 100414 48 2 Xylenes 1330207 134 7 n -Hexane 110543 13316 666 2,2,4- Trimethylpentane 540841 537 27 Note: All non -criteria reportable pot utants 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 004: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 3.59E00 1.80E-01 E&P TANK model based on a site - specific pressurized liquid sample collected 10/9/17. 71432 Benzene 2.60E-02 1.00E-03 108883 Toluene 7.32E-03 4.00E-04 100414 Ethylbenzene 7.11E-04 4.00E-05 1330207 Xylene 2.00E-03 1.00E-04 110543 n -Hexane 1.54E-01 8.00E-03 540841 2,2,4- Trimethylpentane 5 .45E-03 3.00E-04 CDPH COLORADO Air Pollution Control Division Department of Pubac Health 6 Environment Page 6 of 7 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. NOx and CO emissions are accounted for under permit 17WE1206 (point 123-9F50-006). 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, HAPs (total and n -hexane) NANSR Synthetic Minor Source of: VOC MACT HH 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 COLORADO Air Pollution Control Division Department of Public Health G Crwironment Page 7 of 7 Permit number: Date issued: Issued to: COLORADO Air Pollution Control Division Department of Public Health & Environment CONSTRUCTION PERMIT 17WE1205 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 2 Enerplus Resources (USA) Corporation Canadian Slang Well Pad 123/9F50 SESW Section 36 T8N R67W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description LOAD 005 Truck loadout of crude oil by submerged fill. Enclosed Combustor 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. This construction permit represents final permit approval and authority to operate this emissions source. Therefore, it is not necessary to self -certify. (Regulation Number 3, Part B, Section III.G.5.) EMISSION LIMITATIONS AND RECORDS 2. 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 LOAD 005 --- --- 0.4 --- Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. CDPHE I. COLORADO Mr Pollution Control Division Department of Pubic Health F Environment Page 1 of 7 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. 3. The emission points in the table below must 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.) Equipment ID AIRS Point Control Device Pollutants Controlled LOAD 005 Enclosed Flare VOC and HAP PROCESS LIMITATIONS AND RECORDS 4. 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 LOAD 005 Crude Oil Loaded 135,000 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. STATE AND FEDERAL REGULATORY REQUIREMENTS 5. No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Regulation Number 1, Section II.A.5.) 6. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 7. 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. Crude oil loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.D.2) COLORADO Mr Pollution Control Division Department of Rub Ifeaitn Er Environment. Page 2 of 7 8. 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. 9. 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 during loading operations 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 quarterly. Each inspection shall be documented in a log available to the Division on request. b. All compartment hatches at the facility (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. 10. For this controlled loading operation, the owner or operator must follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation Number 3, Part B, III.E): 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. OPERATING a MAINTENANCE REQUIREMENTS 11. Upon startup of these points, the owner or operator must 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 Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 12. This source is not required to conduct initial testing, unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements 13. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 14. All previous versions of this permit are cancelled upon issuance of this permit. 15. 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: COPHE Li COLORADO Air Pollution Control Division Department of Public Health & Environment Page 3 of 7 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 enitting 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 • No later than 30 days before the existing APEN expires. 16. The requirements of Colorado Regulation Number 3, Part D must apply at such time that any stationary source or modification becomes a major stationary source or major modification solely by virtue of a relaxation in any enforceable limitation that was established after August 7, 1980, on the capacity of the source or modification to otherwise emit a pollutant such as a restriction on hours of operation (Reference: Regulation Number 3, Part D, V.A.7.B). GENERAL TERMS AND CONDITIONS 17. 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. 18. 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. 19. 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. COLORADO Air Pollution Control Division Uenartmerit of Putiuc tiea;th & E1Nronment Page 4 of 7 20. 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. 21. 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. 22. 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. 23. 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 March 1, 2018 Issued to Enerplus Resources (USA) Corporation. Issued directly to Final Approval. Issuance 2 This Issuance Permit modification Issued to Enerplus Resources (USA) Corporation. COLORADO Air Pollution Control Division (Department of Public Health & Environment. Page 5 of 7 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 wilt 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 (Ib/yr) Controlled Emissions (lb/yr) 005 n -Hexane 110543 531 27 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 005: Pollutant CAS # Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source V0C 0.10071 5.04E-03 AP -42, Ch. 5.2 n -Hexane 110543 0.00394 1.97E-04 Eng. Calc. The uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L = 12.46*S*P*M/T S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 3.4 psia M (vapor molecular weight) = 50 lb/lb-mol T (temperature of liquid loaded) = 530 °R The uncontrolled non -criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors (from the EEtP TANKS model) by the VOC emission factor. The controlled emission factors ate based on 95% 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 COLORADO Air Pollution Control Division Department of PontHeahh 6 Enwonrr+ent Page 6 of 7 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 and HAPs (total and n -hexane) PSD or NANSR Synthetic Minor Source of: VOC 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 COLORADO Air Pollution Control Division Department of Public t{ealth & Duironment Page 7 of 7 Permit number: Date issued: Issued to: COLORADO Air Pollution Control Division Department of Public Health & Environment CONSTRUCTION PERMIT 17WE 1206 Issuance: 4 Enerplus Resources (USA) Corporation Facility Name: Canadian Slang Well Pad Plant AIRS ID: 123/9F50 Physical Location: SESW Section 36 T8N R67W County: Weld County General Well Production Facility Description: Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description SEPARATOR 006 Produced gas from a Three-phase Separator. Enclosed Flare with Open Flare Backup 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 this specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. This construction permit represents final permit approval and authority to operate this emissions source. Therefore, it is not necessary to self -certify. (Regulation Number 3, Part B, Section III.G.5.) EMISSION LIMITATIONS AND RECORDS 2. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section I I.A.4. ) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NOX VOC CO SEPARATOR 006 --- 6.1 78.9 27.7 Point COLORADO Air Pollution Control Division Department of Pub:t[ Health b Environment Page 1 of 7 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. 3. 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 SEPARATOR 006 Two (2) enclosed flares (GCO Beast 3200 and Questor Q5000), with one (1) Steffes open flare as backup during well startup or upset conditions. VOC and HAP PROCESS LIMITATIONS AND RECORDS 4. 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 SEPARATOR 006 Natural Gas Venting 127.9 MMscf 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. 5. The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from the separator(s) using the flow meter. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. 6. The owner or operator shall maintain records of the number of instances and duration of time that the backup open flare is used to control emissions from this point. Facility Equipment ID AIRS Point Process Parameter Annual Limit SEPARATOR 006 Use of Steffes open flare for emissions control 120 hours per year Compliance with the annual limit on open flare operation 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 COLORADO Air Pollution Control Division Department of Pubic Heath & Environment Page 2 of 7 the previous twelve months' data. The permit holder shall calculate the amount of time the open flare is used 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 7. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/9F50/xxx) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 8. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 9. 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 combustiondevices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device. 10. The open flare covered by this permit has been approved as an alternative emissions control device under Regulation Number 7, Section XVII.B.2.e. The open flare must have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16, and be designed sothat an observer can, by means of visual observation from the outside of the open flare, or by other convenient means approved by the Division, determine whether it is operating properly. This open 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. 11. The separator covered by this permit is subject to Regulation 7, Section XVII.G. (State Only). On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be routed to a gas gathering line or controlled from the date of first production by 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. OPERATING ft MAINTENANCE REQUIREMENTS 12. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the O6M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Periodic Testing Requirements 13. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 14. 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: COLORADO Air Pollution Control Division Department of public Health & En ironment Page 3 of 7 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 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. 15. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes ' major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation Number 3, Parts C and D). GENERAL TERMS AND CONDITIONS 16. 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. 17. 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. 18. 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. COLORADO Air Pollution Control Division Department of Pubtic Heaith b Environment Page 4 of 7 19. 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. 20. 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. 21. 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. 22. , 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. Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 March 1, 2018 Issued to Enerplus Resources (USA) Corporation. Issuance 2 April 2, 2018 Issued to Enerplus Resources (USA) Corporation. Modification to allow use of open flare during well startup and during periods of noise and vibration. Issuance 3 July 2, 2018 Issued to Enerplus Resources (USA) Corporation. Modification to increase gas throughput amount, and to change control device equipment. Issued as Initial Approval. Issuance 4 This Issuance Issued to Enerplus Resources (USA) Corporation. Modification to increase process limit. Final Approval Issuance. !COLORADO Air Pollution Control Division Department of Public Health E Environment Page 5 of 7 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-reps 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Facility Equipment ID AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) SEPARATOR Benzene 71432 3506 175 Toluene 108883 5380 269 006 Ethylbenzene 100414 7381 369 Xylenes 1330207 9781 489 n -Hexane 110543 40658 2033 2,2,4- Trimethylpentane 540841 1041 52 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (tb/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: CAS # Pollutant Uncontrolled Emission Factors (lb/MMscf) Controlled Emission Factors (lb/MMscf) Source NOx 94.8056 94.8056 AP 42 Ch.13.5 CO 432.202 432.202 VOC 24669.25 1233.46 Displacement Equation (mass balance) based on a site -specific gas sample collected 10/9/2017. 71432 Benzene 27.4143 1.3707 108883 Toluene 42.0634 2.1032 100414 Ethylbenzene 57.7074 2.8854 1330207 Xylene 76.4763 3.8238 110543 n -Hexane 317.8895 15.8945 540841 2,2,4- Trimethylpentane 8.1378 0.4069 COLORADO Air Pollution Control Division Department of Publkt Neagh & EmArorrent Page 6 of 7 Note: The controlled emissions factors for this point are based on the flare 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 facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC and HAPs (total, and n -hexane) NANSR Synthetic Minor Source of: VOC 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 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 COLORADO Air Pollution Control Division Department of public Health b Environment Page 7 of 7 STATE OF COLORADO C 'R dDO @. _ RT1MENT O 1 # HEALS - -•`ND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 PERMIT NO: 19WE0536 CONSTRUCTION PERMIT Issuance 1 DATE ISSUED: ISSUED TO: Enerplus Resources (USA) Corporation THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Canadian Slang Pad, located in SESW SEC 36 T8N R67W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Point Description GLENG01 002 One (1) Caterpillar, Model G3306TB, Serial Number R6S00735, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 203 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 Caterpillar G3306TB 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 sec{), 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: 123/9F50/002 Page 1 of 14 NGEngine Version 2014-1 Iorad epa en�®. I Health and Environment ir" ollution Control Division 2. Within one hundre and s gh s (1 0) . the .tter of c mencement of operation or issuance of this m• pan w th on•itions co, ained in this permit shall be demonstrated toDivisi• It i the o -r-o .perat• t-`fesponsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, II I.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 4. The 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.) 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 (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 GLENG01 002 2.0 1.4 4.0 Point See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility -wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month AIRS ID: 123/9F50/002 Page 2 of 14 Health and Environment ir`ollution Control Division a new twelve-mon atectas o the pevious twelve months' data. The permit holder al lcute is onshwonth andkeep a compliance record on site or at a loc. -find offiMthespansi rhfy, for Dion review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 7. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility emission limitations as seen below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Total emissions from the facility, including permitted emissions and insignificant activities, shall not exceed: • 100 tons per year of any criteria pollutant 8. The emission points in the fable 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 GLENG01 002 Non -selective catalytic reduction and air/fuel ratio controller NOx, CO, HAPs 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 Process Parameter Annual Limit GLENG01 002 Consumption of natural gas as a fuel 11.46 MMscf/yr Fuel consumption shall be measured by one of the following methods: individual engine fuel meter; facility -wide fuel meter attributed to fuel consumption rating and hours of operation; or manufacturer -provided fuel consumption rate. The owner or operator shall calculate monthly process rates based on the calendar month. AIRS ID: 12319F50/002 Page 3 of 14 Compliance with t ann .1 t o y: hpuMimi = sha b= deter ined on a rolling twelve (12) month total. By t ve-mont' total is calculated based on the previous twee onths ta. - p ChoIder sffaircalculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. Health and Environment ir``ollution Control Division STATE AND FEDERAL REGULATORY REQUIREMENTS 10. The permit number and Alh ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 11. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. & 4.) 12. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 13. 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. OPERATING & 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 O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) AIRS ID: 123/9F50/002 Page 4 of 14 Health and Environment Pollution Control Division COMPLIANCE TESTI Periodic Testingrestrre 15. This engine is subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. ADDITIONAL REQUIREMENTS 16. All previous versions of this permit are cancelled upon issuance of this permit. 17. 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 (NOX) 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. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative -operating scenario and is installing a permanent replacement engine. 18. Federal regulatory program requirements (i.e. PSD or NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any AIRS ID: 123/9F50/002 Page 5 of 14 Health and Environment ollution Control Division permit condition. - y re a a n -at in rea s tl p.tenti. o emit above the applicable Federal program 'ill, re ire6 full vie = of the urce as though construction had not yet comrrmeed on ttie'ource—fh u n hall no exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS 19. 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. 20. 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. 21. 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. 22. 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. 23. 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. 24. 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. 25. 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, AIRS ID: 123/9F50/002 Page 6 of 14 Iorad epa men Health and Environment ollution Control Division civil or criminal forc a a ions -Lin. ®r Sns 2 7-115 (enforcement), -121 (injunctions), -122 JM:-na s) 121.1 (c in 3 enaltie -, C.R.S. By: Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Enerplus Resources (USA) Corporation. Point previously covered by General Permit AIRS ID: 12319F501002 Page 7 of 14 Health and Environment it ollution Control Division Notes to Permit Holder at th 1) The permit holder is reime fc permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cddhe/agcc-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 (Ib/yr) 002 Formaldehyde 50000 A 941 Yes 470 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 3.7492 15.28 0.2452 1.00 CO 3.7492 15.28 0.4908 2.00 VOC 0.1718 0.70 50000 Formaldehyde 0.0589 0.24 0.0294 0.12 Emission factors are based on a Brake -Specific Fuel Consumption Factor of 8985 Btu/hp-hr, a site - rated horsepower value of 203, and a fuel heat value of 1394 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Catalyst Specification CO Manufacturer Catalyst Specification VOC Manufacturer N/A 50000 Formaldehyde Manufacturer Catalyst Specification 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 AIRS ID: 123/9F501002 Page 8 of 14 Health and Environment ollution Control Division associated with this per . Fore y eons r gara, g a •eific ex ration date call the Division at (303)-692-3150. 7) This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting — effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.qovittn/atw/area/fr181a08.pdf 8) This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ia08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html 9) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, HAPs NANSR Synthetic Minor Source of: VOC MACT ZZZZ Major Source Requirements: Not Applicable Area Source Requirements: Applicable 10) 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 11) 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: 123/9F50/002 Page 9 of 14 lorad s_ eparien Health and Environment ollution Control Division C AL r ATV Fd' CEN RIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with an engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 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: 123/9F501002 Page 10 of 14 Health and Environment it `ollution Control Division 2.1.2 The owner or operatorfnayg eng.- e with another engine with the same manufacturer, model and _: ors o ermines �°. itho t modify- this permit so long as the permanent replacement en pli th it li a: ., and o -`equirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2_ An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at 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.gov/cdphe/portable-analvzer-monitoring-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: 123/9F50/002 Page 11 of 14 Health and Environment ollution Control Division engine will be subject to, th- 'esults®f t t shag benve d to the propriate units as described in the above -mentioned Portab If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State - Only conditions). Control Requirements: Section XVI Any permanent replacement engine bcated 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: 123/9F50/002 Page 12 of 14 The source shall submit cop Emission Standards: Section XVII.E — State -only requirements Health and Environment ollution Control Division under Condition 2.1.2. Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr NOx CO V0C January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 500≤Hp July 1, 2007 July 1,2010 2.0 1.0 4.0 2.0 1.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this 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: 123/9F50/002 Page 13 of 14 Iorad epa en i-Health and Environment ollution Control Division if approved in advance by th in Condition 2.2. 2.4 Additional Sources vied th._=suc'test c nduct within the time frame specified 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: 123/9F501002 Page 14 of 14 STATE OF COLORADO CQ O DEPARTMENT O _® HEALi - AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 PERMIT NO: 1 9YY E0537 CONSTRUCTION PERMIT Issuance 1 DATE ISSUED: ISSUED TO: Enerplus Resources (USA) Corporation THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Canadian Slang Pad, located in SESW SEC 36 T8N R67W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Point Description GEN01 007 One (1) Doosan, Model 8.1L CAC, Serial Number EEPOG-402082, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 199 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 Doosan, Model 8.1L CAC 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: 12319F501007 Page 1 of 14 NGEngine Version 2014-1 iw Health and Environment iriollution Control Division 2. Within one hundre and gh • s (10) the Otte -r of c mencement of operation or issuance of this • mi nom lance with th on "tions co Fained in this permit shall be demonstrated to Divisi0-n.4ft is the owne perato ? esponsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 4. The 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.) 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 (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 GEN01 007 2.0 1.1 3.9 Point See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility -wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month AIRS ID: 123/9F50/007 Page 2 of 14 Health and Environment A irollution Control Division a new twelve-mon tota h b alc to ase othe previous twelve months' data. 12x O The permit holder al - Icu to = m is ons .�ch2. - onth an keep a compliance record on site or at a loc offi th respiMitiT y, for Di iion review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 7. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility emission limitations as seen below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Total emissions from the facility, including permitted emissions and insignificant activities, shall not exceed: • 100 tons per year of any criteria pollutant 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 GEN01 007 Non -selective catalytic reduction and air/fuel ratio controller NOx, CO, HAPs 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 ID AIRSEquipment Point Parameter AL nmit I iProcess GEN01 007 Consumption of natural gas as a fuel .4 M M13scf8/yr Fuel consumption shall be measured by one of the following methods: individual engine fuel meter; facility -wide fuel meter attributed to fuel consumption rating and hours of operation; or manufacturer -provided fuel consumption rate. The owner or operator shall calculate monthly process rates based on the calendar month. AIRS ID: 123/9F50/007 Page 3 of 14 loradepaien� Ali Health and Environment ollution Control Division Compliance with the ann bdeter fined on a rolling twelve (12) month total. By th =_ erif each ont a ne. t -eve-mont— total is calculated based on the previous twe onth1 r to Tti pe It jder swat- 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) 11. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. & 4.) 12. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 13. 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. OPERATING & 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 O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) AIRS ID: 123/9F50/007 Page 4 of 14 Iorad epa en COMPLIANCE TESTI AN S °-'LIN Periodic Testing e:c11 re Health and Environment irPollution Control Division 15. This engine is subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. ADDITIONAL REQUIREMENTS 16. All previous versions of this permit are cancelled upon issuance of this permit. 17. 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 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. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative -operating scenario and is installing a permanent replacement engine. 18. Federal regulatory program requirements (i.e. PSD or NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any AIRS ID: 123/9F50/007 Page 5 of 14 permit condition. Federal program tf had not yet coma' threshold until a permit is granted. (Regulation. No. 3 Part D). Iorad == epa en(& • i K• potenti : Ito emit above the applicable fullvi of the )urce as though construction d on o he s hall no xceed the Federal program Health and Environment ollution Control Division GENERAL TERMS AND CONDITIONS 19. 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. 20. 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. 21. 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. 22. 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. 23. 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. 24. Section 25-7-114.7(2)(a), aR.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. 25. 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, AIRS ID: 123/9F50/007 Page 6 of 14 civil or criminal (injunctions), -122 By: I Health and Environment ir-Pollution Control Division 7-115 (enforcement), -121 C.R.S. Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Enerplus Resources (USA) Corporation. Point previously covered by General Permit AIRS ID: 12319F50/007 Page 7 of 14 Health and Environment ollution Control Division Notes to Permit Holder at th 1) The permit holder is r- e'_- p s pre s ime f is permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/agcc-reps 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) 007 Formaldehyde 50000 A 385 Yes 193 5) The emission levels contained in this permit are based on the following emission factors: Point 007: CAS Pollutant Emission Uncontrolled Ib/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr NOx 2.210 10.808 0.204 1.00 CO 3.720 18.193 0.409 2.00 VOC 0.143 0.70 50000 Formaldehyde 0.021 0.100 0.010 0.050 Emission factors are based on a Brake -Specific Fuel Consumption Factor of 10782 Btu/hp-hr, a site -rated horsepower value of 199, and a fuel heat value of 1394 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Catalyst Specification CO Manufacturer Catalyst Specification VOC Manufacturer N/A 50000 Formaldehyde Manufacturer Catalyst Specification 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 AIRS ID: 12319F501007 Page 8 of 14 Health and Environment it Pollution Control Division associated with this per . For y e ns gar ` g aedific ex ration date call the Division at (303)-692-3150. 7) This engine is subject to 40 CFR, Part 60, Subpart JJJJ-Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting — effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.qovittn/atw/area/frl 8i a08. pdf 8) This engine is subject to 40 CFR, Part 63, Subpart ZZZZ National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.qov/ttn/atw/area/fr18ia08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.qovittn/atw/area/arearules.html 9) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, HAPs NANSR Synthetic Minor Source of: VOC MACT ZZZZ Major Source Requirements: Not Applicable Area Source Requirements: Applicable 10) 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 11) A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at: http://vvww.colorado.qov/pacific/cdphe/air-permit-telf-teitifitatbii AIRS ID: 12319F501007 Page 9 of 14 ALTS ATI E �} SCEN BIOS Health and Environment ollution Control Division RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with an engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 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: 12319F501007 Page 10 of 14 i Health and Environment AiriDollution Control Division 2.1.2 The owner or operato ay • m : e ly reg ac e e .tir1g eng e with another engine with the same manufacturer, model andorsow a sines ith®t modify .; this permit so long as the permanent replacement en ® - p . pli- h • it It and o requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at 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. 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.gov/cdphe/portable-analyzer-monitorinq-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 (Ib/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: 123/9F50/007 Page 11 of 14 Health and Environment ollution Control Division engine will be subject to, thpropriate units as described in the above -mentioned Portab If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State - Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non -selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. AIRS ID: 123/9F50/007 Page 12 of 14 The source shall submit cop Iorad epa e i Health and Environment it ollution Control Division ren an its requi • under Condition 2.1.2. Emission Standards: Section XVII.E — State -only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date 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: 12319F50/007 Page 13 of 14 i Health and Environment irwPollution Control Division if approved in advance by th ivisi• ••vi•• th_suc test im c: ducts 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: 123/9F50/007 Page 14 of 14 STATE OF COLORADO d� HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 CONSTRUCTION PERMIT PERMIT NO: 19WE0791 Issuance 1 DATE ISSUED: ISSUED TO: Enerplus Resources (USA) Corporation THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Canadian Slang Pad, located in SESW SEC 36 T8N R67W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Point Description GLENG02 008 One (1) Caterpillar, Model G3306TA, Serial Number G6X00250, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 203 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 Caterpillar G3306TA 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: 123/9F50/008 Page 1 of 14 NGEngine Version 2014-1 2. Within one hundre and gh d " s (1 0) cs the tter of cPg ommencement of operation or issuance of this bons coained in this permit shall be demonstrated to-tt e-Divisi• ."It i o -r perat s responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). Health and Environment irPollution Control Division 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 4. The 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.) 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 (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 GLENG02 008 2.0 1.4 4.0 Point See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility -wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month AIRS ID: 123/9F5O/OO8 Page 2 of 14 lorad epa en Health and Environment ollution Control Division a new twelve-monr tota h be alcu -tee .ase o the p evious twelve months' data. The permit holder al lcu to is!ons ch } onth an keep a compliance record on site or at a local' i offic- th sT e responibti y, for vision review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 7. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility emission limitations as seen below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Total emissions from the facility, including permitted emissions and insignificant activities, shall not exceed: 100 tons per year of any criteria pollutant 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 GLENG02 008 Non -selective catalytic reduction and air/fuel ratio controller NOx, 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 Process Parameter Annual GLENG02 008 Consumption of natural gas as a fuel 10.69 MMscf/yr Fuel consumption shall be measured by one of the following methods: individual engine fuel meter; facility -wide fuel meter attributed to fuel consumption rating and hours of operation; or manufacturer -provided fuel consumption rate. The owner or operator shall calculate monthly process rates based on the calendar month. AIRS ID: 123/9F50/008 Page 3 of 14 Health and Environment ollution Control Division Compliance with the ann.l t you®hpu imi ` sha be dete fined on a rolling twelve (12) month total. By the a : Tf erch onttl a nve-monfi total is calculated based on the previous twelve monthsta T pe m holder sa'I -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) 11. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. & 4.) 12. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 13. 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. OPERATING & 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 O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) AIRS ID: 123/9F50/008 Page 4 of 14 COMPLIANCE TESTING AN Periodic Testing& .. e Health and Environment ollution Control Division 15. This engine is subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. ADDITIONAL REQUIREMENTS 16. 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 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. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative -operating scenario and is installing a permanent replacement engine. 17. Federal regulatory program requirements (i.e. PSD or NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction AIRS ID: 123/9F50/008 Page 5 of 14 Iorad epa, end i Health and Environment irollution Control Division had not yet comm ced e t e s rce. threshold until a pulati' our N s all n•_ exceed the Federal program 3 Part I. 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 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. 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 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. 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'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. AIRS ID: 12319F501008 Page 6 of 14 By: Health and Environment ollution Control Division Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Enerplus Resources (USA) Corporation. AIRS ID: 123/9F50/008 Page 7 of 14 Health and Environment 'AirPollution Control Division Notes to Permit Holder at th 1) The permit holder is r e pro r` ime fois permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: httos://www.colorado.gov/pacific/cdphe/agcc-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 (lb/yr) Are the emissions reportable? Controlled Emission Rate (Ib/yr) 008 Formaldehyde 50000 A 980 Yes 980 5) The emission levels contained in this permit are based on the following emission factors: Point 008: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Controlled lb/MMBtu Factors — g/bhp-hr NOx 3.797 14.43 0.263 1.00 CO 3.797 14.43 0.526 2.00 VOC 0.184 0.70 50000 Formaldehyde 0.066 0.25 Emission factors are based on a Brake -Specific Fuel Consumption Factor of 8379 Btu/hp-hr, a site - rated horsepower value of 203, and a fuel heat value of 1394 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Catalyst Specification CO Manufacturer Catalyst Specification VOC Manufacturer N/A 50000 Formaldehyde Manufacturer N/A 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 AIRS ID: 12319F501008 Page 8 of 14 i_ Health and Environment irli'ollution Control Division associated with this per . Ford y e eons r garg a •eific ex ration date call the Division at (303)-692-3150. 7) This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting — effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www. epa. qov/ttn/atw/area/fr18ja08. pdf 8) This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ja08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.gov/ttn/atw/area/arearules.html 9) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, HAPs NANSR Synthetic Minor Source of: VOC MACT ZZZZ Major Source Requirements: Not Applicable Area Source Requirements: Applicable 10) 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 11) 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: 12319F501008 Page 9 of 14 lorad , epa en :i Health and Environment it'pollution Control Division TS COW T AL® AT CE °ARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with an engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 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: 123/9F50/008 Page 10 of 14 Health and Environment ollution Control Division 2.1.2 The owner or operato twig eng e with another engine with the same manufacturer, model and orseow- e -• Ines ithot modify • this permit so long as the permanent replacement engr mpli- ith p nit I a : and o€ e equirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at 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. 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.qov/cdphe/portable-analwer-monitoring-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 (Ib/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: 12319F50/008 Page 11 of 14 engine will be subject to, th the above -mentioned Porta Health and Environment it Pollution Control Division propriate units as described in If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State - Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non -selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. AIRS ID: 123/9F50/008 Page 12 of 14 The source shall submit cop Emission Standards: Section XVII.E — State -only requirements Health and Environment ollution Control Division d under Condition 2.1.2. Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 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 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: 123/9F50/008 Page 13 of 14 Health and Environment ollution Control Division if approved in advance by th= , •zvi� �d th �suctest conduct 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: 123/9F50/008 Page 14 of 14 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, includin updates. An application with missing information may be determined incomplete and may be returned or re 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. RScEID APR 3 01010 .4Pr) Stationary This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: l`JWE(iS3b AIRS ID Number: 123 /9F50 /002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name1: Site Name: Enerplus Resources (USA) Corporation Canadian Slang Pad Site Location: SESW Sec. 36, T8N, R67W Mailing Address: (Include Zip Code) 950 17th Street, Suite 2200 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Kristin Van Flees Phone Number: 720-279-5515 E -Mail Address2: kvanhees@enerplus.com Use the full, legal company name registered vAth 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. 3977.43 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 I 'iC =": 1 ` SkPuEma�MP+Wv HCaIU,b Fiv:evMlrnl Permit Number: AIRS ID Number: 123 /9F50 / 002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action O NEW permit OR newly -reported emission source (check one below) STATIONARY source O PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR- ❑✓ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O Change company name O Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership4 ❑✓ Other (describe below) - OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info & Notes: Convert GP02 to 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. GLENG01 General description of equipment and purpose: Engine to drive gas lift For existing sources, operation began on: 10/7/2017 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: / /www. colorado. eov/cdphe/attainment) Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year ❑✓ Yes ❑ No Seasonal use percentage: Dec -Feb: `5:; Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 gri tCOLORADO 2 I teputmentetPublic HnnllhfeTnutronhxnt Permit Number: AIRS ID Number: 123 /9F50 / 002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking 0 Emergency Back-up ❑ Pump 0 Water Pump 0 Other: El Compression What is the maximum number of hours this engine will be used for emergency back-up power? 0 Engine Make: Caterpillar What is the maximum designed horsepower rating? 203 hp What is the engine displacement? 1.75 l/cyl What is the maximum manufacturer's site -rating? 203 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8985 BTU/hp-hr Engine Features: Cycle Type: 0 2 -Stroke ❑✓ 4 -Stroke Combustion: 0 Lean Burn ❑✓ Rich Burn Ignition Source: El Spark ❑ Compression Aspiration: 0 Natural ❑✓ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑✓ Yes 0 No 0 Other: hours/year Engine Model: G3306TB Serial Number6: R6S00735 If yes, what type of AFRC is in use? ❑✓ O2 Sensor (mV) ❑NOx Sensor (ppm) Is this engine equipped with a Low-NOx design? 0 Yes ❑✓ No Engine Dates: What is the manufactured date of this engine? 5/1/2013 What date was this engine ordered? NA What is the date this engine was first located to Colorado? NA What is the date this engine was first placed in service/operation? NA What is the date this engine commenced construction? NA What is the date this engine was last reconstructed or modified? NA Is this APEN reporting an AOS replacement engine? 0 Yes ✓❑ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 6 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1 /2017 3 i coioieauc' Department el Wilk WWI flu IOnntenl Permit Number: AIRS ID Number: 123 /9F50 / 002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.611048/-104.843942 erato © � c Stack lD T+�D Discharge Height � Above Ground Level eet Temp (�F) � Flow Rate A` {AC F M)j`) Velet Ity' #laec GLENG01 TBD -1064 -970 -46.3 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward ❑ Downward ❑ Horizontal ❑ Upward with obstructing raincap ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): 8 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 es (MMScF/year) Requested Annual Permit Liinit7 9MSCF/yearr) 1308 11.46 From what year is the actual annual amount? 2018 Indicate the type of fuel used': ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑✓ Field Natural Gas Heating value: 1394 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 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 41 C0LORADO ' noponm�moiv�suo { Haa1C�6Envitanmant Permit Number: AIRS ID Number: 123 /9F50 /002 [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? 12 Yes 0 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 93.46% VOC CO NSCR 86.91% Other: HAPs-NSCR 50% Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2018 Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions e Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tonslyear) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) 1.94E-2 Ib/MMBtu AP -42 0.16 0.16 PM1D 1.94E-2 Ib/MMBtu AP -42 0.16 0.16 PM2.5 1.94E-2 Ib/MMBtu AP -42 0.16 0.16 SOx • 5.88E-1 Ib/MMBtu AP -42 0.005 0.005 NOx 15.28 g/hp-hr Manufacturer 29.95 1.96 VOC 0.70 g/hp-hr Manufacturer 1.37 1.37 CO 15.28 g/hp-hr Manufacturer 29.95 3.92 Does the emissions source have any uncontrolled actual emissions of non-criteriaID 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: 0 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 0.24 g/hp-hr Manufacturer 940.9 470.45 Acetaldehyde 75O70 Acrolein 107028 Benzene 71432 Other: 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 . 5 COLORADO Dcp,nment el Pupa. malt a Errmammq Permit Number: AIRS ID Number: 123 /9F50 / 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. Li /2,3 /Pi Sign ture of Legally Authorized Person (not a vendor or consultant) Date Kristin Van Hees Environmental Coordinator 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 Or visit the APCD website at: Denver, CO 80246-1530 Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 CoI.ORADO 6 f ceP„ OV,rtr nroca l� -FIPiI dYi:vt�Pnmcal • 2 vre.a, APR 302019 APCD Stationary Deereez Crude Oil Storage Tank(s) APEN - Form APCD-210 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 crude oil 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. condensate 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 alt 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: 17WE1204 REcEP : c) APR 3 L APO ,•.. algr.: AIRS ID Number: 123 / 9F50 / 004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name1: Enerplus Resources (USA) Corporation Site Name: Canadian Slang Well Pad Site Location: SESW Sec 36, T8N, R67W Mailing Address: (include Zip Code) 950 17th Street, Suite 2200 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 211111 Permit Contact: Kristin Van Flees Phone Number: 720-279-5515 E -Mail Address2: KVanHees@enerplus.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. • 397746 Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 07/2017 Aviv COLORADO 111=t1 DTflltbLLL9nt Permit Number: 17WE1204 AIRS ID Number: 123 / 9F50 / 004 [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 General Permit 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 0 Change company name ❑✓ Change permit limit 0 Transfer of ownership3 0 Other (describe below) - OR ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ▪ APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Ft Notes: 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: 6, 400 bbl Crude Oil Tanks For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: rage tank(s) located at: 24 hours/day 7 8/18/2017 days/week 52 weeks/year p Exploration.Et Production (EEtP) site 0 Midstream or Downstream (non EEO) site Will this equipment be operated in any NAAQS nonattainment area? A Yes ■ No Are Flash Emissions anticipated from these storage tanks? • Yes ■ No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. I Yes • No 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-210 - Crude Oil Storage Tank(s) APEN - Revision 07/2017 2 1 Permit Number: 17WE 1204 AIRS ID Number: 123 / 9F50 / 004 (Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information I. Crude Oil Throughput: Actual Annual Amount,' (bbl/year). 66,913 From what year is the actual annual amount? Average API gravity of sales oil: ^-37 Tank design: ✓❑ Fixed roof 2018 `Requested_Annual Permit Lirnit4<_ (bbl/year) degrees ❑ Internal floating roof Storage Tank ID Maple # of Liquid Manifold Storage Vessels in Storage Tank 3 Total Volume of Storage Tank (bbl) 1200 135,000 RVP of sales oil.: —5.6 O External floating roof ,Installation Dateof`Most Recent Storage Vessel in Storage Tank (month/year) 8/2017 Date of First Production (month/year) 8/2017 Beaufort 3 1200 TBD TBD Wells Serviced_ by this_StorageTank or Tank Battery5 (MP Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 44539 Maple 8-67-36-25C ■ 05 - 123 - 49310 Beaufort 8-67-36-25C N ■ ■ ■ 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 5 The EftP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.611048/-104.843942 Operator Stack ' ID No. Discharge. Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) ECD1/ECD2 32.8 1000 variable variable Indicate the direction of the stack outlet: (check one) El Upward O Downward ❑ Horizontal O Other (describe): Indicate the stack opening and size: (check one) El Circular ❑ Square/rectangle O Other (describe): Interior stack diameter (inches): Interior stack width (inches): ❑ Upward with obstructing raincap 91 and 144 Interior stack depth (inches): Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 07/2017 31��COLORADO a=== Permit Number: 17WE 1204 AIRS ID Number: 123 / 9F50 / 004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information O Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor O Recovery Unit (VRU): Pollutants Controlled: Size: Make/Model: Requested Control Efficiency: % VRU Downtime or Bypassed (emissions vented): % ❑ Combustion Device: Pollutants Controlled: V0Cs, HAPs Rating: MMBtu/hr Type: 2-ECDs Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: Minimum Temperature: NA Make/Model: GCO Beast 3200 and Questor Q5000 95 98 Waste Gas Heat Content: Constant Pilot Light: ❑✓ Yes O No Pilot Burner Rating: 2405 0.015 Btu/scf MMBtu/hr O Closed Loop System Description of the closed loop system: O Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 -Gas/Liquids Separation Technology Information (E&tP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? -20 psig Describe the separation process between the well and the storage tanks: Gas and liquids from each well enter a heater treater. Gas, that isn't used for gas lift or fuel, is sent to flare. Oil is sent to crude oil tanks and water is sent to produced water tanks. Separate battery for each well. Form APCD-210 - Crude Oil Storage Tank(s) APEN - Revision 07/2017 A COLO,i2APO 4 I / I lr-1.PnlcffvW Permit Number: 17WE 1204 AIRS ID Number: 123 / 9F50 / 004 [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 wed to state the overall (or combined) control efficiency (%reduction): Pollutant Description of Control Method(s) Overall Requested Control ' Efficiency (% reduction in emissions) VOC 2-ECDs 95 NOx CO HAPs 2-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 Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) VOC 3.59 lb/bbl E&P Tanks 169.96 8.50 242.33 12.12 NOx 0.068 lb/MMBtu AP -42 0.28 0.28 0.45 0.45 CO 0.31 Ib/MMBtu AP -42 1.29 1.29 2.07 2.07 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) Uncontrolled Emissions • (Pounds/year) Controlled Emissions (Pounds year) Benzene 71432 2.60E-2 lb/bbl E&P Tanks 2255 113 Toluene 108883 7.32E-3 lb/bbl E&P Tanks 664 33 Ethylbenzene 100414 7.11E-4 lb/bbl E&P Tanks Xylene 1330207 2.00E-3 lb/bbl E&P Tanks n -Hexane 110543 1.54E-1 lb/bbl E&P Tanks 13316 666 2,2,4 Trimethylpentane 540841 5.45E-3 lb/bbl E&P Tanks 537 27 4 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 Attach crude oil 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-210 - Crude Oil Storage Tank(s) APEN - Revision 07/2017 5 I. A. COLORADO IteaftherrAtifirMIN Permit Number: 17WE1204 AIRS ID Number: 123 / 9F50 / 004 [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 GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. NA/') LI /pi 110.1 Signature of Legally Authorized Person (not a vendor or consultant) Date Kristin Van Hees Environmental Coordinator Name (print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $152.90 and the General Permit For more information or assistance call: registration fee of $250, if applicable, to: Colorado Department of Public Health and Small Business Assistance Program / Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 (303) 692-3175 or (303) 692-3148 - COLORADO Form APCD-210 -Crude Oil Storage Tank(s) APEN - Revision 07/2017 6 Inssn°oam RED APR 3.0 2019 Hydrocarbon Liquid Loading APEN s b 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. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. This APEN is to be used for hydrocarbon liquid loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, glycol dehydration unit, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www:colorado.uov/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: 17WE1205 AIRS ID Number: 123 / 9F50 / 005 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Enerplus Resources (USA) Corporation Site Name: Canadian Slang Well Pad Site Location: SESW Sec 36, T8N, R67W Mailing Address: (Include Zip Code) 950 17th Street, Suite 2200 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 211111 Contact Person: Phone Number: E -Mail Address2: Kristin Van Nees 720-279-5515 KVanHees@enerplus.com ' Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. • 397745 Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019 COLORADO 1I if- .=, HO61T6GvIvnmOM Permit Number: 17WE1205 AIRS ID Number: 123 / 9F50/005 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ' ❑ NEW permit OR newly -reported emission source O Request coverage under construction permit O Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $312.50 must be submitted along with the APEN filing fee. -OR- p MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O Change company name3 Change permit limit O Transfer of ownership4 O Other (describe below) OR ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Crude Oil truck loading Company equipment Identification No. (optional): LOAD For existing sources, operation began on: 8/18/2017 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? a Yes ■ No Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Yes No • P Does this source load gasoline into transport vehicles? ■ Yes 0 No Is this source located at an oil and gas exploration and production site? I51 Yes ■ No If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Yes No • 4 Does this source splash fill less than 6750 bbl of condensate per year? ■ Yes NI No Does this source submerge fill less than 16308 bbl of condensate per year? • Yes I No Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019 21 COLORADO DepaamemDI Palle NaatatbUfalronxlerd Permit Number: 17WE1205 AIRS ID Number: 123 /9F50/005 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: O Condensate p Crude Oil ❑ Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded5: 135,000 bbl/year This product is loaded from tanks at this facility into: (e.g. "rail tank cars" or "tank trucks") Actual Volume Loaded: Tank trucks bbl/year If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: 0.6 Average temperature of bulk liquid loading: 70 °F True Vapor Pressure: 3.4 @ 70F Psia 60 °F Molecular weight of displaced vapors: 50 lb/lb mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: bbl/year Actual Volume Loaded: bbl /year Product Density: lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume: ft3/truckload 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-208 Hydrocarbon Liquid Loading APEN - Revision 3/2019 1COLONADO 3 I �� I""`"�11h6Gvlm�; NmmMett Permit Number: 17WE1205 AIRS ID Number: 123 I 9F50 / 005 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 46.611048/-104.843942 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. (® Flow Rate (ACFM) Velocity (ft/sec) ECD1/ECD2 32.8 1000 variable variable Indicate the direction of the stack outlet: (check one) 0 Upward O Horizontal O Downward O Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular O Other (describe): O Upward with obstructing raincap Interior stack diameter (inches): 91 and 144 Section 6 - Control Device Information O Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. O Loading occurs using a vapor balance system: Requested Control Efficiency: ❑ Combustion Device: Used for control of: VOC and HAPs Rating: MMBtu/hr Type: 2-ECDs Make/Model: GOO Beast 3200 and Questor Q5000 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: NA °F Waste Gas Heat Content: 2623 Btu/scf Constant Pilot Light: ✓❑ Yes O No Pilot Burner Rating: 0.015 MMBtu/hr ❑ Other: Pollutants Controlled: Description: Requested Control Efficiency: Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019 4 l ctILoRADO n c carr,:t, H�tufer;,vuxc�:tw�. Permit Number: 17WE1205 AIRS ID Number: 123 /9F50/005 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the • Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) PM SOX NO. CO VOC Enclosed Combustor 95 HAPs Enclosed Combustor 95 Other: o Using State Emission Factors (Required for GP07) VOC Benzene n -Hexane ❑ Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL ❑ Crude 0.104 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? 2019 Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5_. Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled Emissions 6 (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) PM SOX NOX included w oil tanks CO included w oil tanks VOC 2.4 lb/1000 gal AP -42 6.80 0.34 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (pounds/year) Controlled Emissions6 (pounds/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 0.09 lb/1000 gal Mass balance 531 27 2,2,4- Trimethyipentane 540841 _ Other: 5 Requested values wilt become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019 RADO 5 I AYICOLOX. T`�97 pey�nm,TtwA +� M a51fib FnHmvnn.f Permit Number: 17WE1205 AIRS ID Number: 123 /9F501005 [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 General Permit GP07. vv‘ Signature of Legally Authorized Person (not a vendor or consultant) Kristin Van Flees ,Zq't °1 1 Date Environmental Coordinator 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 $191.13 and the General Permit registration fee of $312.50, 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 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 3/2019 6I ICOLORAbO ➢gisttm . WN.k H. nos EfNrmmient Natural Gas Venting APEN - Form APCD-211 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for Natural Gas Venting only. Natural Gas Venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. if your emission unit does not fall into this category, there may be a more specific APEN for your source. In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdohe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 17WE1206 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Company equipment Identification: SEPARATOR AIRS ID Number: 123 / 9F50/ 006 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 1 - Administrative Information Company Name': Site Name: Site Location: Enerplus Resources (USA) Corporation Canadian Slang Well Pad Site Location SESW Sec 36, T8N, R67W County: Weld Mailing Address: (Include Zip Code) 950 17th Street, Suite 2200 Denver, CO 80202 E -Mail Address': KVanHees@enerplus.com NAICS or SIC Code: 211111 Permit Contact: Kristin Van Hees Phone Number: 720-279-5515 'Please use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-211 - Natural Gas Venting APEN - Rev 03/2017 COLORADO Dapv 7: of PoL'Jc 397744 Permit Number: 17WE 1206 AIRS ID Number: 123 /9F50/ 006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2- Requested Action ❑ NEW permit OR newly -reported emission source -OR - El MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment ❑ Change company name 0 Add point to existing permit ✓❑ Change permit limit ❑ Transfer of ownership' 0 Other (describe below) OR - • APEN submittal for update only (Please note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info a Notes: Increase Throughput 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: Flaring of produced gas until pipeline is tied -in (two separators, one for each well) For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 9 / 12 / 2017 / / 0 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 days/week weeks/year O Yes O Yes ❑ No 0 No (COLORADO 2 I N4,partroant a AS, Permit Number: 17WE1206 AIRS ID Number: 123 /9F50/ 006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information 0 Gas/Liquid Separator O Well Head Casing ❑ Pneumatic Pump Make: Model: O Compressor Rod Packing Make: Model: ❑ Blowdown Events # of Events/year: O Other Description: Serial #: Capacity: Gal/min # of Pistons: Leak Rate: Scf/hr/pist Volume per event: MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a Gas/Liquid Separator you must use Natural Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑✓ Yes Natural Gas Venting Process Parameters4: Liquid Throughput Process Parameters4: ❑ No Maximum Vent Rate: 12333 SCF/hr Vent Gas Heating Value: 1394.2 BTU/SCF Requested: 127.9 MMSCF/year Actual: 93.31 MMSCF/year -OR- Requested: Bbl/yr Actual: Bbl/yr 4 Requested values will become permit limitations. Requested limit(s) should consider future process growth Process Properties: Molecular Weight: VOC (mole %) VOC (Weight %) 36.98 Benzene (mole %) Benzene (Weight %) 0.0410 Toluene (mole %) Toluene (Weight %) 0.0630 Ethylbenzene (mole %) Ethylbenzene (Weight %) 0.0864 Xylene (mole %) Xytene (Weight %) 0.1145 n -Hexane (mole %) n -Hexane (Weight %) 0.4759 2,2,4-Trimethylpentane (mole %) 2,2,4-Trimethylpentane (Weight %) 0.0122 Additional Required Information: ❑✓ Attach a representative gas analysis (including BTEX Et n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 COLORADO 3 I..®V! tr. Permit Number: 17WE 1206 AIRS ID Number: 123 /9F50/ 006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.611048/-104.843942 era or, Stack ��o,. a Discharge Height Above Ground Level (Feet) em (. J FiOW date ACF ) _ Yelociiy t/sec ), ECD1/ECD2 328 1000 variable variable Indicate the direction of the stack outlet: (check one) ❑ Downward ❑Other (describe): 0 Upward ❑ Horizontal Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): ❑ Upward with obstructing raincap 91 and 144 0 Other (describe): If flare used, 15' height and 6 inch diameter Section 6 - Control Device Information ❑ VRU: Pollutants Controlled: Sipe: Requested Control Efficiency VRU Downtime or Bypassed Make/Model: ya ❑ Combustion E Device: Pollutants Controlled: VOC, HAPs Rating: Type: 2-ECDs MMBtu/hr Make/Model: GCO Beast 3200 and Questor Q5000 Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency 98 Minimum Temperature: NA Waste Gas Heat Content 1 394.2 Btu/scf Constant Pilot Light: ❑✓ Yes 0 No Pilot burner Rating 0.015 MMBtu/hr Other: Pollutants Controlled: VOC, HAPs Description: Seffes open flare as backup during startup/upset ccj Control Efficiency 95 0/0 Requested Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 41 C0L0k AbD Depanm=n[a(?u . H�itm6c�i�'m�nx Permit Number: 17WE1206 AIRS ID Number: 123 /9F50/ 006 [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 El No erall control efficiency (% reduction): Pollutant Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) PM SO, NOX VOC 2-ECDs and back up flare 95 CO - HAPs 2-ECDs and back up flare 95 Other: 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) Controlled6 (Tons/year) Uncontrolled (Tons/year) Controlled (Tons/year) Uncontrolled (Tons/year) PM SO, NOX 0.068 II'MMBtu AP -42 4.43 4.43 6.06 6.06 VOC 17.69 Il lMMBtu Mass Balance 1219.60 60.98 1578.00 78.90 CO 0.31 II/MMBtu AP -42 20.19 20.19 27.65 27.65 Benzene 27.37 Ib/MMscf Mass Balance 1.28 0.06 1.75 0.09 Toluene 42.00 Ib/MMscf Mass Balance 1.96 0.10 2.69 0.13 Ethylbenzene 57.62 Ib/MMscf Mass Balance 2.69 0.13 3.69 0.18 Xylenes 76.37 Ib/MMscf Mass Balance 3.57 0.18 4.88 0.24 n -Hexane 317.44 Ib/MMscf Mass Balance 14.83 0.74 20.31 1.02 2,2,4- Trimethylpentane Other: 8.13 II 'MMscf Mass Balance 0.38 0.02 0.52 0.03 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6Annual emission fees will be based on actualcontrolled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 COLORADO 5I AN", Nea511.6Fnriwraat Permit Number: 17WE 1206 AIRS ID Number: 123 /9F50/ 006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. Signature of Legally Authorized Person (not a vendor or consultant) Kristin Van Hees �l2 Ijci Date Environmental Coordinator Name (please print) Title Check the appropriate box to request a copy of the: E Draft permit prior to issuance E✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) Send this form along with $152.90 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Telephone: (303) 692-3150 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-211 -Natural Gas Venting APEN - Rev 03/2017 :....•a . (COLORADO 6 It HSvirtattm u Reciprocating Internal Combustion Engine APEN - Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit RECEIVED APR 3 0 1019 APCD onary �+iv�aq All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for reciprocating internal combustion engines (RICE). If your engine is a diesel compression ignition engine or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. diesel compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200(1 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: 19►A/EOS37 AIRS ID Number: 123 /9F50 /007 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 Administrative Information Company Name': Enerplus Resources (USA) Corporation Site Name: Canadian Slang Pad Site Location: SESW Sec. 36, T8N, R67W Mailing Address: (Include Zip Code) 950 17th Street, Suite 2200 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Permit Contact: Kristin Van Hees Phone Number: 720-279-5515 E -Mail Address2: KVanHees@enerplus.com Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by APCD via e-mail to the address provided. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 COLORADO 1I V 11>W lLUIII1b F. nl 397744 Permit Number: AIRS ID Number: 123 /9F50 / 007 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action O NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source O PORTABLE source O Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,500.00 must be submitted along with the APEN Filing fee. -OR - ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name O Add point to existing permit O Change permit limit ❑ Transfer of ownership"' ❑✓ Other (describe below) - OR • APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacements Additional Info £t Notes: Convert GP02 to 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. GEN01 General description of equipment and purpose: Engine to drive generator For existing sources, operation began on: 2/23/2018 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.gov/cdphe/attainment) Normal Hours of Source Operation: 24 Seasonal use percentage: Dec -Feb: 25 DYes ON 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 COLORADO 2 I D,P cn,oIP Uo watmaaiviloninmt Permit Number: AIRS ID Number: 123 /9F50 / 007 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑✓ Primary and/or Peaking 0 Pump ❑ Water Pump ❑ Emergency Back-up ❑ Other: ❑ Compression What is the maximum number of hours this engine will be used for emergency back-up power? 0 Engine Make: Doosan hours/year Engine Model: 8.1 L CAC Serial Number6: EEPOG-402082 What is the maximum designed horsepower rating? 199 hp What is the engine displacement? 0.74 l/cyl What is the maximum manufacturer's site -rating? 199 hp kW What is the engine Brake Specific Fuel Consumption at 100% Load? 10782 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke 1214 -Stroke Combustion: 0 Lean Burn ❑✓ Rich Burn Ignition Source: 0 Spark 0 Compression Aspiration: 0 Natural ❑✓ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑✓ Yes 0 No If yes, what type of AFRC is in use? ❑✓ O2 Sensor (mV) ❑NOx Sensor (ppm) 0 Other: Is this engine equipped with a Low-NOx design? 0 Yes ❑✓ No Engine Dates: What is the manufactured date of this engine? 3/11/2014 What date was this engine ordered? NA What is the date this engine was first located to Colorado? NA What is the date this engine was first placed in service/operation? NA What is the date this engine commenoed construction? NA What is the date this engine was last Feconstructed or modified? NA Is this APEN reporting an AOS replacement engine? 0 Yes ❑✓ No If yes, provide the make, model, arrd 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. nmm co�oae oa Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 3 Permit Number: AIRS ID Number: 123 /9F50 / 007 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.611048/-104.843942 Jo- My`R' yF, rater�� st� E, Mischa a He g1it � �.��,�� Above roun Le el �� '� p � � � �� Fls► to fr�C . � � y elocs�t;x�� ft/ _ GEN01 TBD 1350 -1129 —24.0 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): 6 ❑ Upward with obstructing raincap Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fue Use=Rate L� 00% Load . , 5�F hour f.. ��r.. Actual Annual Fuel Us.e Ln . ... SCF/yearl x Requeste Annual erm°it L1m!t' r " x,4`44", F 11 V1 CF/year 1539 13.48 From what year is the actual annual amount? 2018 Indicate the type of fuel used$: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) 0 Field Natural Gas Heating value: 1394 BTU/scf 0 Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): ' Requested values will become permit limitations. Requested limit(s) should consider future process growth. 8 If fuel heating value is different than the listed assumed value, provide this information in the "other" field. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 4 'COLORADO .DopartmcntolFuLllc Wald, PrXM/frottment Permit Number: AIRS ID Number: 123 /9F50 / 007 [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) 4 /Zot Jtc'1 Date Kristin Van Hees Environmental Coordinator Name (please print) Title Check the appropriate box to request a copy of the: El 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 $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 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 Or visit the APCD website at: Make check payable to: https://www.colorado.gov/cdphe/apcd Colorado Department of Public Health and Environment Telephone: (303) 692-3150 Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 A 4C0400ADO 6 I'T a loepvmt imentet nbllc. AAi�� l asnnrenmwn Permit Number: AIRS ID Number: 123 /9F50 /007 [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 O 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) PM1a PM2.5 SOX NOx NSCR 90.75% VOC NSCR 21.43% CO NSCR 89.01% Other: HAPs - NSCR 50% Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? 2018 Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions 9 Requested Annual Permit Emission Limit(s)7 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tons/year) TSP (PM) 1.94E-2 Ib/MMBtu AP -42 0.18 0.18 PM10 1.94E-2 Ib/MMBtu AP -42 0.18 0.18 PMyg 1.94E-2 Ib/MMBtu AP -42 0.18 0.18 SOX 5.88E-4 Ib/MMBtu AP -42 0.006 0.006 NOX• 2.21 Ib/MMBtu AP -42 20.77 1.92 VOC 0.70 g/hp-hr Manufacturer 1.35 1.06 CO 3.72 Ib/MMBtu AP -42 34.96 3.84 Does the emissions source have any uncontrolled actual emissions of non -criteria yes pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? . If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: ❑ No Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions' Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions (Pounds/year) Formaldehyde 50000 0.0205 Ib/MMBtu AP -42 385.3 39.4 Acetaldehyde 75070 Acrolein 107028 Benzene, 71432 Other: 7 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Reciprocating Internal Combustion Engine APEN - Revision 1/2017 [; cO4ORADO amm a uw.onmm+ Spark Ignition 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. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. This APEN is to be used for spark ignition (e.g. gas -fired) reciprocating internal combustion engines (RICE). If your engine is a compression ignition engine (e.g. diesel -fired) or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. 3UL 3 9" Permit Number: chivem [Leave blank unless APCD has already assigned a permit # and AIRS ID] AIRS ID Number: 123 /9F50/o05' Section 1 - Administrative Information Company Namei: Enerplus Resources (USA) Corporation Site Name: Canadian Slang Pad Site Location: SESW Sec. 36, T8N, R67W Mailing AdpCode) 950 17th Street, Suite 2200 (Include Zip Code) Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Contact Person: Phone Number: E -Mail Address2: Kristin Van Flees 720-279-5515 kvanhees@enerplus.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-201 - Spark Ignition Engine APEN - Revision 3/2019 4Q3491 COLORADO 1 I ��!mambmQ�� l Hea[H�b Emlloeumnl Permit Number: AIRS ID Number: 123 /9F50/ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑✓ NEW permit OR newly -reported emission source (check one below) ❑✓ STATIONARY source O PORTABLE source ❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,875 must be submitted along with the APEN filing fee. - OR O MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment ❑ Change company name4 ❑ O Change permit limit O Transfer of ownerships ❑ -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ID APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacement6 Additional Info Et Notes: Add point to existing permit Other (describe below) 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. s For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 6 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? If yes, provide the Company Equipment Identification No. GLENG02 Yes General description of equipment and purpose: Engine to drive gas lift For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.gov/cdphe/attainment) TBD ✓❑ Yes ❑ No Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Spark Ignition Engine APEN - Revision 3/2019 COLORADO 2 I MY°c,,.'n" �� Hea[IribEmLonment Permit Number: AIRS ID Number: 123 /9F50/ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: O Primary and/or Peaking Power 0 Emergency (max. 500 hrs/year) ✓❑ Compression ❑ Pump Jack ❑. Water Pump 0 Other: What is the maximum number of hours this engine will be used for emergency back-up power? 0 hours/year Engine Make: Caterpillar Engine Model: 3306TH Serial Number7: G6X00250 What is the maximum designed horsepower rating? 203 hp What is the maximum manufacturer's site -rating? 203 hp kW What is the engine Brake Specific Fuel Corsumption at 100% Load? 8379 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ❑✓ 4 -Stroke Combustion: ❑ Lean Burn ❑✓ Rich Burn Aspiration: ❑ Natural ❑✓ Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes 0 No If yes, what type of AFRC is in use? El Oz Sensor (mV) ❑NOx Sensor (ppm) O Other: Is this engine equipped with a Low-NOx design? ❑ Yes 0 No Engine Dates: What is the manufactured date of this engine? 12/2/2002 What date was this engine ordered? NA What is the date this engine was first located to Colorado? NA What is the date this engine was first placed in service/operation? NA What is the date this engine commenced construction? NA What is the date this engine was last reconstructed or modified? Is this APEN reporting an AOS replacement engine? ❑ Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Spark Ignition Engine APEN - Revision 3/2019 A,WICOLORADO 3 I I H.a[°ep Nb EllItn iwnt Permit Number: AIRS ID Number: 123 /9F50/ [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.611048/-104.843942 0`perator Stack ID No Discharge Height und Grround Level Gro Temp: Flow Rate ,: CFM)`�] : Velocity (ftT3ec). GLENG02 TBD -1064 -970 -46.3 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward 0 Horizontal 0 Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): Interior stack diameter (inches): 8 ❑ Upward with obstructing raincap Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel:` Use Rate;@'100%;Load (SCF/hour) ActualrAnnual Fuel Use (MMSCF/year) y Requested AnnualPermit Limit$ 5q1*.ear 1220 10.69 From what year is the actual annual amount? 2019 Indicate the type of fuel used9: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑✓ Field Natural Gas Heating value: 1394 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf El Other (describe): Heating Value (give units): s Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Spark Ignition Engine APEN - Revision 3/2019 4 I COLORADO gcy:�t=ntnEPuL,m HeuEllt bflivl[nnm[usl Permit Number: AIRS ID Number: 123 /9F50/ [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? ID 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 93.07% VOC CO NSCR 86.14% 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? 2019 Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions" Requested Annual Permit Emission Limit(s)e ; Uncontrolled Bemis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) Uncontrolled Emissions ` (tons/year) Controlled Emissions (tons/year) TSP (PM) 1.94E-2 Ib/MMBtu AP -42 0.14 0.14 PM10 1.94E-2 Ib/MMBtu AP -42 0.14 0.14 PM2.5 1.94E-2 lb/MMBtu AP -42 0.14 0.14 SOx 5.88E-4 Ib/MMBtu AP -42 0.004 0.004 NOx 14.43 g/hp-hr Mfg. 28.29 1.96 VOC 0.70 g/hhp-hr Mfg. + cushion 1.37 1.37 CO 14.43 g/hp-hr Mfg. 28.29 3.92 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 J❑ Yes ❑ No lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract (CAS) ( ) Number Emission Factor Actual Annual Emissions1Q Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (pounds/year) 980 Controlled Emissions (pounds/year) 980 Formaldehyde 50000 0.25 g/hp-hr Mfg. Acetaldehyde 75070 Acrolein 107028 Benzene 71432 Other: 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported.If source has not yet started operating, leave blank. Form APCD-201 - Spark Ignition Engine APEN - Revision 3/2019 ot.ORADO 5I 21 NY t= Permit Number: AIRS ID Number: 123 /9F50/ [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. -7 13o /tot Signature of Legally Authorized Person (not a vendor or consultant) Date Kristin Van Hees Sr. Environmental Specialist Name (please print) Title Check the appropriate box to request a copy of the: ✓0 Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $1,875, 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 For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-201 - Spark Ignition Engine APEN - Revision 3/2019 COLORADO aai� Permit Number: AIRS ID Number: 123 /9F50 /007 [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. 4/, \.A/N 'i'2oi 1l01 Signature of Legally Authorized Person (not a vendor or consultant) Date Kristin Van Hees Environmental Coordinator Name (please print) Title Check the appropriate box to request a copy of the: ✓0 Draft permit prior to issuance ✓� Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $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 (COLORADO Dcpmimen,o,peblk 6 [,;&YNnim, d#nhronman, Hello