The URL can be used to link to this page

Browse Search

Home My WebLink About20192276.tiffCOLORADO Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150 O St PO Box 758 Greeley, CO 80632 June 11, 2019 Dear Sir or Madam: RECEIVED JUN 1 Li "=:J WELD COUNTY COMMISSIONERS On June 13, 2019, the Air Pollution Control Division will begin a 30 -day public notice period for Bonanza Creek Energy Operating Company, LLC - Whitetail F-4 Production Facility . 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 & Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer Pub;c P1eeL (0Ira! lc\ P LCTA) A1 -C. PWCJMIE.tzlGwlw%) Lo/1y/tq 2019-2276 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Bonanza Creek Energy Operating Company, LLC - Whitetail F-4 Production Facility - Weld County Notice Period Begins: June 13, 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: Bonanza Creek Energy Operating Company, LLC Facility: Whitetail F-4 Production Facility Oil and natural gas production facility Lot 3, Secton 4, T6N, R62W Weld County The proposed project or activity is as follows: Applicant proposes to increase permitted limits to account for production from one (1) newly producing well. 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 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 16WE0004 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices, The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Comments may be submitted using the following options: • Use the web form at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices. This page also includes guidance for public participation • Send an email to cdphe.commentsapcd@state.co.us • Send comments to our mailing address: Bradley Eades Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 1 I ADO COLORA � nwnnben�;�m.mr, Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Package It Received Date: Review Start Date: Bradley Eades 393801 2/22/2019 5/16/2019 Section 01 - Facility Information Company Name: County AIRS ID: Bonanza Creek Energy Operating Company, LLC 123 Quadrant Section Township Range Lot 3 4 6N 62 Plant AIRS ID: Facility Name: Physical Address/Location: County: Type of Facility: 9DB2 Whitetail F-4 Production Facility Lot 3 of Section 4, Township 6N, Range 62W Weld County Exploration & Production Well Pad What industry segment? Oil & Natural Gas Production & Processing Is this facility located in a NAAQS non -attainment area? If yes, for what pollutant? Carbon Monoxide (CO) Section 02 - Emissions Units In Permit Application Yes Particulate Matter (PM) ✓ Ozone (NOx & VOC) AIRs Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks 002 Condensate Tank CNDTK 01-04 Yes 16WE0004 2 Permit Modification 003 Produced Water Tank PWT-01 Yes 16WE0004 2 Permit Modification 004 Liquid Loading L-01 Yes 16WE0004 2 Permit Modification 006 Separator Venting FL -02 Yes 16WE0004 2 Permit Modification HLP Sep/Sales Gas Flaring 007 Separator Venting SEP-01, SEP-02 Yes 16WE0004 2 Permit Modification 2 -LP separators Section 03 - Description of Project Modification to existing equipment to reflect additional production from one (1) new well. There is a TEG dehydrator permitted at the site which is yet to be installed. Condition 3 of the permit gives 18 months from the date the permit was issued (January 2019) to install the equipment. With issuance 2, I will retain the same requirement, however, the deadline to construct will be extended to 18 months from this issuance date (issuance 2). This should be considered if applicant applies for future extensions of this deadline. It should be noted that Bonanza is not formally requesting an extension to this deadline but I am affording it in the interest of maintaining consistent permit language. Section 04 - Public Comment Requirements Is Public Comment Required? Yes If yes, why? Greater than 25 tons per year in Non -Attainment Area Section 05 - Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? No If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes, indicate programs and which pollutants: Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) Is this stationary source a major source? If yes, explain what programs and which pollutants herE SO2 Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) No Yes SO2 NOx CO VOC PM2.5 F 1 No NOx PM10 TSP HAPs CO VOC PM2.5 PM10 TSP HAPs Condensate Storage Tank(s) Emissions Inventory 002 Condensate Tank Facility AIRs ID: 123 County 9DB2 Plant 002 Point Section 02 - Equipment Description Details Detailed Emissions Unit Four (4) 500 barrel fixed roof condensate storage vessels connected via liquid manifold. Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Enclosed flare Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Condensate Throughput = 127,750 Barrels (bbl) per year Actual Condensate Throughput While Emissions Controls Operating = 127,750 Barrels (bbl) per year Requested Permit Limit Throughput = 153,300 Barrels (bbl) per year Requested Monthly Throughput = 13020 Barrels (bbl) per month Potential to Emit (PTE) Condensate Throughput 153,300 Barrels (bbl) per year 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 = 2974.93 Btu/scf 104.2551429 scf/bbl Potential to Emit (PTE) heat content of waste gas routed to combustion device = Het content of pilot gas = 2974.93 btu/scf Volume of pilot gas burned = 16.8 scf/hr Requested heat content of pilot gas routed to combustion device = Section 04 - Emissions Factors & Methodologies Will this storage tank emit flash emissions? 39,622 MMBTU per year 47,546 MMBTU per year 47,546 MMBTU per year 438 MMBTU per year Emission Factors Condensate Tank Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) Emission Factor Source (Condensate Throughput) (Condensate Throughput) VOC 13.3437 0.6672 Site Specific E.F. (includes flash) Site Specific E.F. (includes flash) Site Specific E.F. (includes flash) Benzene 0.0638 0.0032 Toluene 0.0585 0.0029 Ethylbenzene 0.0075 0.0004 Site Specific E.F. (includes flash) Site Specific E.F. (includes flash) Site Specific E.F. (includes flash) Site Specific E.F. (includes flash) Xylene 0.0174 0.0009 n -Hexane 0.4926 0.0246 224 TMP 0.0027 0.0001 Control Device Emission Factor Source Uncontrolled Uncontrolled Pollutant (lb/MMBtu) (lb/bbl) (waste heat combusted) (Condensate Throughput) PM10 0.0075 0.0023 AP -42 Table 1.4-2 (PM10/PM.2.5) AP -42 Table 1.4-2 (PM10/PM.2.5) AP -42 Chapter 13.5 Industrial Flares (NOx) AP -42 Chapter 13.5 Industrial Flares (CO) PM2.5 0.0075 0.0023 NOx 0.0680 0.0211 CO 0.3100 0.0961 Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) VOC 1022.8 352.3 42.6 1022.79 51.14 8687 PM10 0.2 0.1 0.1 0.18 0.18 30 PM2.5 0.2 0.1 0.1 0.18 0.18 30 NOx 1.6 1.3 1.3 1.63 1.63 277 CO 7.4 6.1 6.1 7.44 7.44 1263 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 9773 8145 407 9773 489 Toluene 8970 7475 374 8970 449 Ethylbenzene 1150 958 48 1150 57 Xylene 2664 2220 111 2664 133 n -Hexane 75521 62934 3147 75521 3776 224 TMP 414 345 17 414 21 2 of 19 K:\PA\2016\16W E0004.CP2.xlsm Condensate Storage Tank(s) Emissions Inventory Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XII.C, D, E, F Storage tank is subject to Regulation 7, Section XII.C-F Regulation 7, Section XII.G, C Storage Tank is not subject to Regulation 7, Section XII.G Regulation 7, Section XVII.B, C.1, C.3 Storage tank is subject to Regulation 7, Section XVII, B, C.1 & C.3 Regulation 7, Section XVII.C.2 Storage tank is subject to Regulation 7, Section XVII.C.2 Regulation 6, Part A, NSPS Subpart Kb Storage Tank is not subject to NSPS Kb Regulation 6, Part A, NSPS Subpart 0000a Storage tank is subject to NSPS 0000a Regulation 8, Part E, MACT Subpart HH Storage Tank is not subject to MACT HH (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use the state default emissions factors to estimate emissions? If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company use a site specific emissions factor to estimate emissions? Yes: If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company request a control device efficiency greater thar 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 'Applicant is conservatively assuming the HHV of the pilot fuel is equal to that of the tank waste gas. `Applicant modeled a pressurized liquid analysis (sampled 1/10/19) collected from the low pressure side of the HLP separator using ProMax. ProMax was used to model both flash and working and breathing losses. Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point ft 002 Process tt SCC Code 01 4-04-003-11 Fixed Roof Tank, Condensate, working+breathing+flashing losses Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.06 0 lb/1,000 gallons condensate throughput PM2.5 0.06 0 lb/1,000 gallons condensate throughput NOx 0.51 0 lb/1,000 gallons condensate throughput VOC 317.7 95 lb/1,000 gallons condensate throughput CO 2.31 0 Ib/1,000 gallons condensate throughput Benzene 1.52 95 lb/1,000 gallons condensate throughput Toluene 1.39 95 Ib/1,000 gallons condensate throughput Ethylbenzene 0.18 95 Ib/1,000 gallons condensate throughput Xylene 0.41 95 lb/1,000 gallons condensate throughput n -Hexane 11.73 95 lb/1,000 gallons condensate throughput 224 TMP 0.06 95 lb/1,000 gallons condensate throughput 3 of 19 K:\PA\2016\16WE0004.CP2.xlsm Condensate Tank Regulatory Analysis Worksheet Colorado Re ulation 3 Parts A and B - APEN and Permit Re uirements Source is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this Individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? You have indicated that source is in the Non Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.2)? Source requires a permit Yes No Colorado Regulation 7, Section XII.C-F 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at an oil and gas exploration and production operation', natural gas compressor station or natural gas drip station? 3. Is this storage tank located upstream of a natural gas processing plant? Storage tank is subject to Regulation 7, Section XtI.C•F Yes Yes Yes Section XII.C.1 - General Requirements for Air Pollution Control Equipment - Prevention of Leakage Section XII.C.2 - Emission Estimation Procedures Section XII.D - Emissions Control Requirements Section XII.E - Monitoring Section XII.F - Recordkeeping and Reporting Colorado Regulation 7, Section XII.G 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at a natural gas processing plant? 3. Does this storage tank exhibit "Flash" (e.g. storing non -stabilized liquids) emissions and have uncontrolled actual emissions greater than or equal to 2 tons per year VOC? Storage Tank Is not subject to Regulation 7, Section XII.G Yes Yes No Section XII.G.2 - Emissions Control Requirements Section XII.C.1 - General Requirements for Air Pollution Control Equipment - Prevention of Leakage Section XII.C.2 - Emission Estimation Procedures Colorado Regulation 7, Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this condensate storage tank" located at an oil and gas exploration and production operation , well production facility=, natural gas compressor station' or natural gas processing plant? 3. Is this condensate storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions' of this storage tank equal to or greater than 6 tons per year VOC? 5. Storage tank Is subject to Regulation 7. Section XVII, fl, C.1 & C.3 Yes No Yes Yes 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 Does the condensate storage tank contain only "stabilized" liquids? Yes No Storage tank is subject to Regulation 7, Section XVII.C.2 Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels 1. Is the individual storage vessel capacity greater than or equal to 75 cubic meters (m3) [~472 BBLs)? 2. Does the storage vessel meet the following exemption in 60.111b(d)(4)? a. Does the vessel has a design capacity less than or equal to 1,589.874 m' (-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)"s as defined in 60.111b? 6. Does the storage vessel meet any one of the following additional exemptions: a. Is the storage vessel a pressure vessel designed to operate in excess of 204.9 kPa [-29.7 psi) and without emissions to the atmosphere (60.110b(d)(2))?; or b. The design capacity is greater than or equal to 151 m' [""950 BBL] and stores a liquid with a maximum true vapor pressure' less than 3.5 kPa (60.11ob(b))?; or c. The design capacity is greater than or equal to 75 M3 h472 BBL) but less than 151 m3 [-950 BBL) and stores a liquid with a maximum true vapor pressure' less than 15.0 kPa(60.11ob(b))? Source Requires an APEN. Go to the next question Go to next question Source Requires a permit Continue . You have indicated the site attainment status nn the project summary sheet. Continue - You have indicated the facility type on the project summary sheet. Source is subject Yes Yes Continue - You have determined facility attainment status on the Project Summary sheet. Storage Tank is not subject to Regulation 7, Section XII.G • You have indicated facility type on project summary sheet. Source is subject Continue - You have indicated the source category on the Project Summary sheet. Go to the next question - You have indicated facility type on project summary sheet. Go to the next question Source is subject to parts of Regulation 7, Sections XVII.B&C. Go to the next question Source Is subject to all provisions of Regulation 7, Section XVII, Subsections B & C Go to the next question Storage Tank is not subject NSPS Kb. Storage Tank is riot subject to NSPS Kb Subpart A, General Provisions §60.112b - Emissions Control Standards for VOC §60.113b - Testing and Procedures §60.115b - Reporting and Recordkeeping Requirements §60.116b • Monitoring of Operations 40 CFR, Part 60, Subpart 0000, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Is this condensate storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this condensate storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015? 3. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year? 4. Does this condensate storage vessel meet the definition of "storage vessel"' per 60.5430? 5. Is the storage vessel subject to and controlled in accordance with requirements for storage vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Subpart NH? Storage Tank is not subject to NSPS 0000 Yes Yes No Subpart A, General Provisions per §60.5425 Table 3 §60.5395 - Emissions Control Standards for VOC §60.5413 - Testing and Procedures §60.5395(g) - Notification, Reporting and Recordkeeping Requirements §60.5416(c) - Cover and Closed Vent System Monitoring Requirements §60.5417 - Control Device Monitoring Requirements [Note: If a storage vessel is previously determined to be subject to NSPS 0000 due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS 0000 per 60.5365(e)(2) even if potential VOC emissions drop below 6 tons per year) 40 CFR, Part 60, Subpart 0000a, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Is this condensate storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this condensate storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2.) after September 18, 2015? 3. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year? 4. Does this condensate storage vessel meet the definition of "storage vessel"' per 60.5430? 5. Is the storage vessel subject to and controlled in accordance with requirements for storage vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Subpart NH? Storage tank is subject to NSPS 0000a Yes Yes Yes Yes Subpart A, General Provisions per §60.5425 Table 3 §60.5395 - Emissions Control Standards for VOC §60.5413 - Testing and Procedures §60.5395(g) . Notification, Reporting and Recordkeeping Requirements §60.5416(c) - Cover and Closed Vent System Monitoring Requirements §60.5417 - Control Device Monitoring Requirements [Note: If a storage vessel Is previously determined to be subject to NSPS 0000 due to emissions above 6 tons per year VOC on the applicability determination date, It should remain subject to NSPS 0000 per 60.5365(e)(2) even 40 CFR, Part 63, Subpart MACT HH, Oll and Gas Production Facilities 1. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.160(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))' 2. Is the tank located at a facility that is major' for HAPs? 3. Does the tank meet the definition of "storage vessel"° in 63.761? 4. Does the tank meet the definition of "storage vessel with the potential for flash emissions"s per 63.761? 5. Is the tank subject to control requirements under 40 CFR Part 60, Subpart Kb or Subpart 0000? Storage Tank is not subject to MAC f HH Subpart A. General provisions per §63.764 (a) Table 2 §63.766 - Emissions Control Standards §63.773 - Monitoring §63.774 - Recordkeeping §63.775 - Reporting No Yes No Yes Yes RAG Review RACY 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. No Continue - You have indicated the source category on the Project Summary sheet. Go to the next question Storage Tank is not subject NSPS 0000. Continue - You have indicated the source category on the Project Summary sheet. Go to the next question Go to the next question Go to the next question Source is subject to NSPS 0000 Continue - You have indicated the source category on the Project Summary sheet. Storage Tank is not subject MACT HH - There are no MACT HH requirements for tanks at area sources Go to the next question Go to the next question Source is subject Produced Water Storage Tank(s) Emissions Inventory 003 Produced Water Tank Facility AIRs ID: 123 County 9DB2 003 Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: One (1) 500 barrel fixed roof produced water storage vessel Enclosed Flare 95 Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Produced Water Throughput = 109,500 Barrels (bbl) per year Actual Produced Water Throughput While Emissions Controls Operating = Requested Permit Limit Throughput = 131,400 Barrels (bbl) per year Requested Monthly Throughput = 11160 Barrels (bbl) per month Potential to Emit (PTE) Produced Water Throughput = Secondary Emissions - Combustion Device(s) Heat content of waste gas = Volume of waste gas emitted per BBL of liquids produced = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = 131,400 Barrels (bbl) per year 1059 1.4 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? Yes 162 MMBTU per year 195 MMBTU per year 195 MMBTU per year Emission Factors Produced Water Tank Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) Emission Factor Source (Produced Water Throughput) (Produced Water Throughput) VOC 0.0345 0.00 Site Specific E.F. (includes flash) Site Specific E.F. (includes flash) Benzene 0.0013 0.000 Toluene 0.0007 0.000 Site Specific E.F. (includes flash) Site Specific E.F. (includes flash) Site Specific E.F. (includes flash) Site Specific E.F. (includes flash) Site Specific E.F. (includes flash) Ethylbenzene 0.0000 0.000 Xylene 0.0001 0.000 n -Hexane 0.0004 0.000 224 TMP 0.0000 0.000 Control Device Emission Factor Source Uncontrolled Uncontrolled Pollutant (lb/MMBtu) (lb/bbl) (waste heat combusted) (Produced Water Throughput) PM10 0.0075 0.0000 AP -42 Table 1.4-2 (PM1O/PM.2.5) AP -42 Table 1.4-2 (PM10/PM.2.5) AP -42 Chapter 13.5 Industrial Flares (NOx) AP -42 Chapter 13.5 Industrial Flares (CO) PM2.5 0.0075 0.0000 NOx 0.0680 0.0001 CO 0.3100 0.0005 Section 05 - Emissions Inventory Wt % From EGA of Flashed Gas VOC 28.69% Benzene 1.12% Toluene 0.60% Ethylbenzene 0.04% Xylene 0.12% n -Hexane 0.36% 224 TMP 0.00% Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) VOC PM10 PM2.5 NOx 2.3 1.9 0.1 2.26 0.11 19 0.0 0.0 0.0 0.00 0.00 0 0.0 0.0 0.0 0.00 0.00 0 0.0 0.0 0.0 0.01 0.01 1 CO 0.0 0.0 0.0 0.03 0.03 5 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) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene 177 148 7 177 9 0.09 0.00 Toluene 95 79 4 95 5 0.05 0.00 Ethylbenzene 6 5 0 6 0 0.00 0.00 Xylene 18 15 1 18 1 0.01 0.00 n -Hexane 57 47 2 57 3 0.03 0.00 224 TMP 0 0 0 0 0 0.00 0.00 Section 06 - Regulatory Summary Analysis 109,500 Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XVII.B, C.1, C.3 Storage Tank is not subject to Regulation 7, Section XVII Regulation 7, Section XVII.C.2 Storage Tank is not subject to Regulation 7, Section XVII.C.2 Regulation 6, Part A, NSPS Subpart OOOO Storage Tank is not subject to NSPS OOOO (See regulatory applicability worksheet for detailed analysis) 6 of 19 K:\PA\2016\16WE0004.CP2.xlsm Produced Water Storage Tank(s) Emissions Inventory Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid water sample drawn at the facility being permitted and analyzed using flash liberation analysis? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor. See PS Memo 14-03, Questions 5.9 and 5.12 for additional guidance on testing. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes *Applicant calcualted emission factors using flash liberation analysis of a pressurized water sample collected 1/10/2019 from the Whitet ail F-4 facility. The pressurized water sample (42psig, 131F) was allowed to flash at atmospheric conditions (12.4 psi, 60F) and the scf of gas liberated per barrel of liquid was measured. Quality assurance was performed by the laboratory with reported results of 18.5% duplicate GWR RSD. The Division has no published guidane on quality assurance for FLA of produced water however, the laboratory reports an acceptable result of up to 20%. Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 003 Process # SCC Code 01 4-04-003-15 Fixed Roof Tank, Produced Water, working+breathing+flashing losses Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons liquid throughput PM2.5 0.00 0 lb/1,000 gallons liquid throughput NOx 0.00 0 lb/1,000 gallons liquid throughput VOC 0.8 95 lb/1,000 gallons liquid throughput CO 0.01 0 lb/1,000 gallons liquid throughput Benzene 0.03 95 lb/1,000 gallons liquid throughput Toluene 0.02 95 lb/1,000 gallons liquid throughput Ethylbenzene 0.00 95 lb/1,000 gallons liquid throughput Xylene 0.00 95 lb/1,000 gallons liquid throughput n -Hexane 0.01 95 lb/1,000 gallons liquid throughput 224 TMP 0.00 95 lb/1,000 gallons liquid throughput 7 of 19 K:\PA\2016\16WE0004.CP2.xlsm Produced Water Storage Tank Regulatory Analysis Worksheet Please note that NSPS Kb might be might be applicable for certain tanks at water management and injection facilities. If the tanks you are reviewing are at one of these facilities, please review NSPS Kb. Colorado Regulation 3 Parts A and B - APEN and Permit Requirements source is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the operator claiming less than 1% crude oil and is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1.M) 3. Are total facility uncontrolled VOC emissions greater than S TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Pan B, Section II.D.3)? Yes 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 operator claiming less than 1% crude oil and is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1-M) 3- Are total facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than S TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.2)? No Yes Source requires a permit Colorado Regulation 7, Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this produced water storage tank' located at an oil and gas exploration and production operation , well production facility2, natural gas compressor station' or natural gas processing plant? 3. Is this produced water storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions` of this storage tank equal to or greater than 6 tons per year VOC? storage Tank is not subject to Regulation 7, Section XVII Yes Yes Section XVII.B — General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.C.1 - Emissions Control and Monitoring Provisions Section XVII.C.3 - Recordkeeping Requirements 5. Does the produced water storage tank contain only "stabilized" liquids? If no, the following additional provisions apply. Storage Tank is not subject to Regulation 7, Section XVII.C.2 No Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart OOOO, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Is this produced water storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this produced water storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015? 3. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year? 4. Does this produced water storage vessel meet the definition of "storage vessel"' per 60.5430? No Yes No No Storage Tank is not subject to NSPS OOOO Subpart A, General Provisions per §60.5425 Table 3 §60.5395 - Emissions Control Standards for VOC §60.5413 - Testing and Procedures §60.5395(g) - Notification, Reporting and Recordkeeping Requirements §60.5416(c) - Cover and Closed Vent System Monitoring Requirements §60.5417 - Control Device Monitoring Requirements [Note: If a storage vessel is previously determined to be subject to NSPS OOOO due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS OOOO per 60.5365(e)(2) even if potential VOC emissions drop below 6 tons per year) RACT Review RACT review is required if Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets both criteria, then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act. its implementing regulations, and Air Quality Control Commission regulations This document is not a rule or regulation. and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances This document does not change or substitute for any law. regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act,, its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control The use of non -mandatory language such as "recommend," "may," "should," and 'can." is intended to describe APCD interpretations and recommendations Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. Source Requires an APEN. Go to the next question Go to next question Source Requires a permit Continue - You have indicated the source category on the Project Summary sheet. Continue - You have indicated the facility type on the Project Summary sheet. Go to the next question Storage Tank is not subject to Regulation 7, Section XVII Storage Tank is not subject to Regulation 7, Section XVII.C.2 Continue - You have indicated the source category on the Project Summary sheet. Storage Tank is not subject NSPS OOOO - This tank was constructed outside of the applicability date. Storage Tank is not subject NSPS OOOO. Hydrocarbon Loadout Emissions Inventory 004 Liquid Loading 'Facility AIRs ID: 123 County 9DB2 Plant 004 Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Is this loadout controlled? Collection Efficiency: Control Efficiency: Loadout of condensate to tank trucks. Enclosed Flare Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Hydrocarbon Loadout Actual Volume Loaded = Yes 100.0 95 127,750 Barrels (bbl) per year Actual Volume Loaded While Emissions Controls Operating = 127,750 Barrels (bbl) per year Requested Permit Limit Throughput = 153,300 Barrels (bbl) per year Requested Monthly Throughput = 13020 Barrels (bbl) per month Potential to Emit (PTE) Volume Loaded = Secondary Emissions - Combustion Device(s) Heat content of waste gas = Volume of waste gas emitted per year = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = 153,300 Barrels (bbl) per year 2763.21 Btu/scf 274407 scf/year Potential to Emit (PTE) heat content of waste gas routed to combustion device = Section 04 - Emissions Factors & Methodologies Does the company use the state default emissions factors to estimate emissions? Does the hydrocarbon liquid loading operation utilize submerged fill? Yes Yes 632 MMBTU per year 758 MMBTU per year 758 MMBTU per year The state default emissions factors may be used to estimate emissions. Emission Factors Hydrocarbon Loadout Pollutant Uncontrolled Controlled (lb/bbl) (Ib/bbl) Emission Factor Source (Volume Loaded) (Volume Loaded) VOC 2.36E-01 1.18E-02 Condensate Loadout State E.F. Benzene 4.10E-04 2.05E-05 Condensate Loadout State E.F. Condensate Loadout State E.F. Condensate Loadout State E.F. Condensate Loadout State E.F. Condensate Loadout State E.F. Condensate Loadout State E.F. Toluene 0.00E+40 0.00E+00 Ethylbenzene 0.00E+00 0.00E+00 Xylene 0.00E+00 0.00E+00 n -Hexane 3.60E-03 1.80E-04 224 TMP 0.00E+00 0.00E+00 I Control Device Emission Factor Source Uncontrolled Uncontrolled Pollutant (lb/MMBtu) (Ib/bbl) (waste heat combusted) (Volume Loaded) PM10 0.0075 3.69E-05 AP -42 Table 1.4-2 (PM10/PM.2.5) AP -42 Table 1.4-2 (PM10/PM.2.5) AP -42 Table 1.4-2 (SOx) AP -42 Chapter 13.5 Industrial Flares (NOx) AP -42 Chapter 13.5 Industrial Flares (CO) PM2.5 0.0075 3.69E-05 SOx 0.0006 2.91E-06 NOx 0.0680 3.36E-04 CO 0.3100 1.53E-03 f1 K:\PA\2016\16W E0004.CP2.xlsm Hydrocarbon Loadout Emissions Inventory Section OS - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) PM10 PM2.5 SOx NOx 0.00 0.00 0.00 0.00 0.00 0 0.00 0.00 0.00 0.00 0.00 0 0.00 0.00 0.00 0.00 0.00 0 0.03 0.02 0.02 0.03 0.03 4 VOC Co 13.09 15.07 0.75 18.09 0.90 154 0.12 0.10 0.10 0.12 0.12 20 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 63 52 3 63 3 Toluene 0 0 0 0 0 Ethylbenzene 0 0 0 0 0 Xylene 0 0 0 0 0 n -Hexane 552 460 23 552 28 224 TMP 0 0 0 0 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit RACT - Regulation 3, Part B, Section III.D.2.a The loadout must be operated with submerged fill to satisfy RAG. (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 *Applicant calculated combustion emissions using an estimated tank vapor composition from the ProMax simulation used to estimate tank em issions. This results in a more conservative result than what is calculated using State default HHV values and a mass balance on VOC emitted assuming 65 Ib/Ibmol and 379 scf/Ibmol. Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 004 Process # 01 SCC Code 4-06-001-32 Crude Oil: Submerged Loading Normal Service (S=0.6) Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons transferred PM2.5 0.00 0 lb/1,000 gallons transferred SOx 0.00 0 lb/1,000 gallons transferred NOx 0.01 0 lb/1,000 gallons transferred VOC 5.6 95 lb/1,000 gallons transferred CO 0.04 0 lb/1,000 gallons transferred Benzene 0.01 95 Ib/1,000 gallons transferred Toluene 0.00 95 lb/1,000 gallons transferred Ethylbenzene 0.00 95 lb/1,000 gallons transferred Xylene 0.00 95 lb/1,000 gallons transferred n -Hexane 0.09 95 lb/1,000 gallons transferred 224 TMP 0.00 95 lb/1,000 gallons transferred 10 of 19 K:\PA\2016\16WE0004.CP2.xlsm Hydrocarbon Loadout Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements Source is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section II.D.1.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)? You have indicated that source is in the Non -Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section II.D.1.I)? 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? 4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill? 5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 6. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.2)? Source requires a permit Yes No NA No NA Yes 7. RACT - Are uncontrolled VOC emissions from the loadout operation greater than 20 tpy (Regulation 3, Part B, Section III.D.2.a)? No 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 Separator Venting Emissions Inventory 006 Separator Venting Facility AIRs ID: 123 County 9DB2 Plant 006 Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Flaring of high pressure gas from two (2) high/low pressure (HLP) separators during sales line downtime Enclosed flares (two (2) Crimson CE -1000) Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Limited Process Parameter Gas meter natural Gas Vented Yes, meter is currently installed and operational Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Separator Actual Throughput = MMscf per year 95 Requested Permit Limit Throughput = 15.0 MMscf per year Requested Monthly Throughput = 1 MMscf per month Potential to Emit (PTE) Throughput = Process Control (Recycling) Equipped with a VRU: Is VRU process equipment: 15.0 MMscf per year No. Secondary Emissions - Combustion Device(s) for Air Pollution Control Separator Gas Heating Value: Volume of waste gas emitted per BBL of liquids throughput: Section 04 - Emissions Factors & Methodologies 1406 Description Btu/scf scf/bbl Two (2) HLP separators. When high pressure ags cannot be compressed into the sales pipeline, it is routed to a flare. A site -specific sales gas analysis was collected from the sales gas line at 188 psig, 100F on 1/10/19 with composition reflected below: MW 24.6 Weight % Oxygen/Argon 0.02 CO2 4.27 N2 0.68 methane 43.37 ethane 17.88 propane 17.59 isobutane 2.37 n -butane 6.97 isopentane 1.58 n -pentane 2.00 cyclopentane 0.17 n -Hexane 0.57 cyclohexane 0.15 Other hexanes 0.95 heptanes 0.43 methylcyclohexane 0.16 224-TMP 0.00 Benzene 0.07 Toluene 0.08 Ethylbenzene 0.01 Xylenes 0.04 C8+ Heavies 0.64 Total 100.0 VOC Wt % 33. 7E. Ib/Ib-mol Displacement Equation Ex = Q * MW * Xx / C Emission Factors Separator Venting Emission Factor Source Pollutant Uncontrolled Controlled (lb/MMscf) (lb/MMscf) (Gas Throughput) (Gas Throughput) VOC 21915.0426 1095.7521 Extended gas analysis Extended gas analysis Extended gas analysis Benzene 47.8369 2.3918 Toluene 49.8667 2.4933 Ethylbenzene 8.3731 0.4187 Extended gas analysis Extended gas analysis Extended gas analysis Extended gas analysis Xylene 28.8000 1.4400 n -Hexane 367.0667 18.3533 224 TMP 0.1298 0.0065 Pollutant Primary Control Device Emission Factor Source Uncontrolled Uncontrolled (lb/MMBtu) Ib/MMscf (Waste Heat Combusted) (Gas Throughput) PM10 0.0075 10.475 AP -42 Table 1.4-2 (PM10/PM.2.5) AP -42 Table 1.4-2 (PM10/PM.2.5) AP -42 Table 1.4-2 (SOx) AP -42 Chapter 13.5 Industrial Flares (NOx) AP -42 Chapter 133 Industrial flares (CO) PM2.5 0.0075 10.475 SOx 0.0006 0.827 NOx 0.0680 95.600 CO 0.3100 _ 435.823 12 of 19 K:\PA\2016\16W E0004. CP2.xlsm Separator Venting Emissions Inventory Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) PM10 PM2.S 0.03 0.00 0.00 0.08 0.08 13 0.08 0.00 0.00 0.08 0.08 13 SOx 0.01 0.00 0.00 0.01 0.01 1 NOx 0.72 0.00 0.00 0.72 0.72 122 VOC 164.36 0.00 0.00 164.36 8.22 1396 CO 3.27 0.00 0.00 3.27 3.27 555 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 718 0 0 718 36 Toluene 748 0 0 748 37 Ethylbenzene 126 0 0 126 6 Xylene 432 0 0 432 22 n -Hexane 5506 0 0 5506 275 224 TMP 2 0 0 2 0 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 not 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. Are facility -wide permitted emissions of VOC greater than or equal to 90 tons per year? No If yes, the permit will contain: -An "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. -A "Periodic Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application on an annual basis. Will the operator have a meter installed and operational upon startup of this point? Yes If no, the permit will contain a condition that requires the operator to calculate gas throughput using the liquid throughput until the meter is installed and operational (not to exceed 180 days). This condition will use the "Volume of waste gas emitted per BBL of liquids throughput" (scf/bbl) value in section 03. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes This point is to permit flaring of high-pressure gas from the HIP separator when the sales pipeline is unavailable. Point 007 represents the low pressure stream that is routed to the combustor when the LP compression is unavailable. Applicant indicates that each stream is measured separately with dedicated meters. Section 09 - Inventory 5CC Coding and Emissions Factors AIRS Point # 006 Process # SCC Code 01 3-10-001-60 Flares Uncontrolled Emissions Pollutant Factor Control % Units PM10 10.48 0 Ib/MMSCF PM2.5 10.48 0 Ib/MMSCF SOx 0.83 0 Ib/MMSCF NOx 95.60 0 Ib/MMSCF VOC 21915.04 95 Ib/MMSCF CO 435.82 0 Ib/MMSCF Benzene 47.84 95 lb/MMSCF Toluene 49.87 95 Ib/MMSCF Ethylbenzene 8.37 95 lb/MMSCF Xylene 28.80 95 Ib/MNISCF n -Hexane 367.07 95 Ib/MMSCF 224 TMP 0.13 95 Ib/MMSCF 13 of 19 K:\PA\2016\16WE0004.CP2.xlsm Separator Venting Regulatory Analysis Worksheet Colorado Re ulation 3 Parts A and B - APEN and Permit Re uirements SOW( Is ut the Non Attuinineut Al ea 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.La)? 2. Are total facility uncontrolled VOC emissions greater than S TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? Not enough information 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 S TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.2)? 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, CS Yes Section XVII.B.2 - General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.G - Emissions Control Alternative Emissions Control (Optional Section) Is this separator controlled by a back-up or alternate combustion device (i.e., not the primary control device) that is not enclosed? The control device for this separator is not subject to Regulation 7, Section XVII.B.2.e Section XVII.B.2.e - Alternative emissions control equipment Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend.- "may," "should. " and "can, "is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself Yes :Na Separator Venting Emissions Inventory 007 Separator Venting Facility AIRs ID: 123 County 9DB2 Plant 007 Point Section 02 - Equipment Description Details Flaring of low pressure gas from two (2) high/low pressure (HLP) separators during sales line downime. Detailed Emissions Unit Description: Enclosed flares (two (2) Crimson CE -1000) Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Limited Process Parameter Gas meter Natural Gas Vented Yes, meter is currently installed and operational Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Separator Actual Throughput = MMscf per year 95 Requested Permit Limit Throughput = 11.85 MMscf per year Requested Monthly Throughput = 1 MMscf per month Potential to Emit (PTE) Throughput = Process Control (Recycling) Equipped with a VRU: Yes Is VRU process equipment: Yes 11.85 MMscf per year Uncontrolled and controlled emissions used to establish requested permit limits are based only on when the VRU is bypassed (i.e. waste gas volume that is routed to the flare) Secondary Emissions - Combustion Device(s) for Air Pollution Control Separator Gas Heating Value: Volume of waste gas emitted per BBL of liquids throughput: Section 04 - Emissions Factors & Methodologies Description 2195 Btu/scf scf/bbl Two (2) LP separators. When low pressure ags cannot be compressed into the sales pipeline, it is routed to the enclosed flares. A site -specific sales gas analysis was collected from the low pressure separators "LP Gas" at 38 psig, 105 F on 1/10/19 with composition reflected below: MW 39.1 Weight % Trace components (indicated as O2/Argo, 0.22 2.69 CO2 N2 0.87 methane 11.12 ethane 15.52 propane 27.60 isobutane 4.76 n -butane 15.61 isopentane 4.60 n -pentane 6.33 cyclopentane 0.60 n -Hexane 2.16 cyclohexane 0.56 Other hexanes 3.57 heptanes 1.61 methylcyclohexane 0.57 224-TMP 0.00 Benzene 0.27 Toluene 0.25 Ethylbenzene 0.03 Xylenes 0.08 C8+ Heavies 1.21 Total 100.22 VOC Wt % 69.81 Ib/Ib-mol Displacement Equation Ex = Q * MW * Xx / C Emission Factors Separator Venting Emission Factor Source Pollutant Uncontrolled Controlled (lb/MMscf) (lb/MMscf) (Gas Throughput) (Gas Throughput) VOC 72015.2912 3600.7646 Extended gas analysis Extended gas analysis Extended gas analysis Extended gas analysis Extended gas analysis Extended gas analysis Extended gas analysis Benzene 283.1900 14.1595 Toluene 262.2485 13.1124 Ethylbenzene 27.8481 1.3924 Xylene 77.6371 3.8819 n -Hexane 2223.9662 111.1983 224 TMP 1.1314 0.0591 Pollutant Primary Control Device Emission Factor Source Uncontrolled Uncontrolled (Ib/MMBtu) lb/MMscf (Waste Heat Combusted) (Gas Throughput) PM10 0.0075 16.353 AP -42 Table 1.4-2 (PM10/PM.2.5) AP -42 Table 1.4-2 (PM10/PM.2.5) AP -42 Table 1,4-2 (5Ox) AP -42 Chapter 13,5 Industrial flares (NOx) AP -42 Chapter 13.5 Industrial Flares (CO) PM2.5 0.0075 16.353 SOx 0.0006 1.291 NOx 0.0680 149.239 CO 0.3100 680.354 I `, of K:\PA\2016\16WE0004.CP2.xlsm Separator Venting Emissions Inventory Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) PM10 PM2.5 SOx 0.10 0.00 0.00 0.10 0.10 16 0.10 0.00 0.00 0.10 0.10 16 0.01 0.00 0.00 0.01 0.01 1 NOx 0.88 0.00 0.00 0.88 0.88 150 VOC 426.69 0.00 0.00 426.69 21.33 3624 CO 4.03 0.00 0.00 4.03 4.03 685 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 3356 0 0 3356 168 Toluene 3108 0 0 3108 155 Ethylbenzene 330 0 0 330 17 Xylene 920 0 0 920 46 n -Hexane 26354 0 0 26354 1318 224 TMP 14 0 0 14 1 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 not 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. Are facility -wide permitted emissions of VOC greater than or equal to 90 tons per year? Nv If yes, the permit will contain: -An "Initial Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. -A "Periodic Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application on an annual basis. Will the operator have a meter installed and operational upon startup of this point? 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. Yes Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes This point is to permit flaring of low pressure gas during VRU compressor downtime. Point 006 represents the total sales gas stream that is routed to the combustor when the sales line is unavailable. Applicant indicates that each stream is measured separately with dedicated meters. Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 007 Process # SCC Code 01 3-10-001-60 Flares Uncontrolled Emissions Pollutant Factor Control % Units PM10 16.35 0 Ib/MMSCF PM2.5 16.35 0 Ib/MMSCF SOx 1.29 0 Ib/MMSCF NOx 149.24 0 lb/MMSCF VOC 72015.29 95 Ib/MMSCF CO 680.35 0 Ib/MMSCF Benzene 283.19 95 lb/MMSCF Toluene 262.25 95 Ib/MMSCF Ethylbenzene 27.85 95 Ib/MMSCF Xylene 77.64 95 Ib/MMSCF n -Hexane 2223.97 95 lb/MMSCF 224 TMP 1.18 95 Ib/MMSCF 16 of 19 K:\PA\2016\16WE0004.CP2.xlsm Separator Venting Regulatory Analysis Worksheet Colorado Re ulation 3 Parts A and B - APEN and Permit Requirements _ Source is in the Non -Attainment Are., 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 S TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.3)? Not enough information 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 10 TPY (Regulation 3, Part B, Section II.D.2)? Source requires a permit 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, Ci Section XVII.B.2 — General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.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? The control device for this separator is not subject to Regulation 7, Section XVII.B.2.e Section XVII.B.2.e — Alternative emissions control equipment Disclaimer This document assists operators oath 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," "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 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION FACILITY EMISSION SUMMARY Company Name Bonanza Creek Energy Operating C County AIRS ID 123 Plant AIRS ID 9DB2 Facility Name Whitetail F-4 Facility ompany, LLC History File Edit Date 5/16/2019 Ozone Status Non -Attainment EMISSIONS - Uncontrolled (tons per year EMISSIONS With Controls (tons qer year POINT AIRS ID PERMIT Description PM10 PM2.5 H2S SO2 NOx VOC Fug VOC CO Total HAPs PM10 PM2.5 H2S SO2 NOx VOC Fug VOC CO Total HAPs REMARKS Previous FACILITY TOTAL 0.1 0.1 0.0 0.0 21.2 52.6 0.0 34.3 2.5 From August 2018 Tab Previous Permitted Facility total 0.1 0.1 0.0 0.0 21.2 52.6 0.0 34.3 2.5 001 GP02.CN Caterpillar G3306B 185hp 0.0 0.0 002 16WE0004 Condensate Tank 1.6 1,022.8 7.4 49.3 1.6 51.1 7.4 2.5 Mod to add 1 well 003 16WE0004 Produced Water Tank 2.3 0.2 0.1 0.0 Mod to add 1 well 004 16WE0004 Truck Loading 18.1 0.3 0.9 0.0 Mod to add 1 well 005 16WE0004 Temporary Gas Flare 0.0 0.0 006 16WE0004 Emergency Flare 164.1 3.8 8.3 0.2 Mod to add 1 well 007 16WE0004 HLP Separator 426.7 17.0 21.4 0.9 Mod to add 1 well 008 GP02 Arrow A-62 80 HP engine 0.1 0.1 11.4 0.3 4.5 0.1 0.1 0.1 11.4 0.3 4.5 0.1 009 17WE0691.XP.CN Compressco GJ230 engine 0.0 0.0 010 GP02 PSI GM 4.3L Vortec 55hp 2.4 0.0 4.0 0.0 1.5 0.0 2.6 0.0 011 16WE0004 TEG Dehydrator 0.1 30.7 0.3 4.9 0.1 0.7 0.3 0.2 012 GP02 Caterpillar G3306TA 203hp 32.5 1.40 34.5 0.2 2.0 1.40 3.9 0.2 No change 013 GP02 Caterpillar G3306TA 203hp 32.5 1.40 34.5 0.2 2.0 1.40 3.9 0.2 No change FACILITY TOTAL 0.1 0.1 0.0 0.0 80.5 1,667.8 0.0 85.2 76.0 0.1 0.1 0.0 0.0 18.6 85.7 0.0 22.6 4.3 VOC: Syn Minor (NANSR and OP) NOx: Minor (NANSR and OP) CO: Minor (PSD and OP) HAPS: Syn Minor Total + n -Hexane HH: Syn Minor + affected Area 7777: Syn Minor Permitted Facility Total 0.1 0.1 0.0 0.0 13.0 1.634 3 0.0 11.9 70.7 0.1 0.1 0.0 0.0 13.0 82.1 0.0 11.9 3.6 Excludes units exempt from permits/APENs (A) Change in Permitted Emissions 0.0 0.0 0.0 0.0 -8.2 29.5 0.0 -22.4 PubCom is required based on increase of 25 tpy in NAA Note 1 Total VOC Facility Emissions (point and fugitive) (A) Change in Total Permitted VOC emissions (point and fugitive) 85.7 Facility is eligible for GP02 because < 90 tpy emissions less than 25/50 tpy 29.5 _ _Project Note 2 Page 18 of 19 Printed 6/3/2019 COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION DIVISION FACILITY EMISSION SUMMARY - HAPs Company Name County AIRS ID Plant AIRS ID Facility Name Bonanza Creek Energy Operating Company, LLC 123 9DB2 Whitetail F-4 Facility Emissions - uncontrolled (lbs per year) POINT PERMIT Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n -Hexane McOH 224 TMP H2S TOTAL (tpy) !Previous FACILITY TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 GP02.CN Caterpillar G3306B 185hp 0.0 002 16WE0004 Condensate Tank 9782 8984 1150 2668 75532 430 49.3 003 16WE0004 Produced Water Tank 1 0.2 004 16WE0004 Truck Loading 554 0.3 005 16WE0004 Temporary Gas Flare 0.0 006 16WE0004 Emergency Flare 718 748 432 5506 3.8 007 16WE0004 HLP Separator 3356 3108 330 920 26354 17.0 008 GP02 Arrow A-62 80 HP engine 139 1 0.1 009 17WE0691.XP.CI'Compressco GJ230 engine 0.0 010 GP02 PSI GM 4.3L Vortec 55hp 0.0 011 16WE0004 TEG Dehydrator 2459 2894 877 2151 1212 1:', 4.9 012 GP02 Caterpillar G3306TA 203hp 327 ' -, 42 25 0.2 013 GP02 Caterpillar G3306TA 203hp 327 42 25 0.2 TOTAL (tpy) 0.4 0.1 0.0 8.3 7.9 1.2 3.1 54.6 0.0 0.3 0.0 0.0 76.0 *Total Reportable = all HAPs where uncontrolled emissions > de minimus values Red Text: uncontrolled emissions < de minimus Emissions with controls (lbs per year) POINT PERMIT Description Formaldehyde Acetaldehyde Acrolein Benzene Toluene Ethylbenzene Xylenes n -Hexane McOH 224 TMP H2S TOTAL (tpy) IPreviousFAc1LlTh'TOTAt 0 0 0 0 0 0 0 0 0 0 0 0 0.0 001 GP02.CN Caterpillar G3306B 185hp 0.0 002 16WE0004 Condensate Tank 489 449 58 133 3777 22 2.5 003 16WE0004 Produced Water Tank 0.0 004 16WE0004 Truck Loading 28 0.0 005 16WE0004 Temporary Gas Flare 0.0 006 16WE0004 Emergency Flare 36 1 37 22 275 0.2 007 16WE0004 HLP Separator 168 155 17 46 1318 0.9 008 GP02 Arrow A-62 80 HP engine 0.1 009 17WE0691.XP.C Compressco GJ230 engine Q.0 010 GP02 PSI GM 4.3L Vortec 55hp 0.0 011 16WE0004 TEG Dehydrator 116 139 43 106 28 0.2 012 GP02 Caterpillar G3306TA 203hp 327 0.2 013 GP02 Caterpillar G3306TA 203hp 327 0.2 TOTAL (tpy) 0.4 0.1 0.0 0.4 0.4 0.1 0.2 2.7 0.0 0.0 0.0 0.0 4.3 19 16WE0004.CP2.xlsm 6/3/2019 Permit number: COLORADO Air Pollution Control Division Department of Public Health & Environment CONSTRUCTION PERMIT 1 6WE0004 Date issued: DRAFT Issued to: Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 2 Bonanza Creek Energy Operating Company, LLC Whitetail F-4 Production Facility 123/9DB2 Lot 3 SEC 4 T6N R62W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description CNDTK 01-04 002 Four (4) 500 -barrel fixed roof condensate storage vessels connected via liquid manifold. Enclosed Flare PWT-1 003 One (1) 500 -barrel produced water tank Enclosed Flare L 01 004 Truck loadout of condensate by submerged fill. Enclosed Flare FL -02 006 Flaring of gas from two (2) high-pressure separators when gas cannot be compressed into sales pipeline. Enclosed Flare SEP-01, SEP- 02 007 of gas from two (2) low-pressure separators when gas cannot be compressed into sates pipeline. Enclosed Flare COLORADO Air Pollution Control Division Department of Public Haan & Environment Page 1 of 16 Facility Equipment ID AIRS Point Equipment Description Emissions Control Description DEHY-1 011 One (1) Triethylene glycol (TEG) natural gas dehydration unit (make, model, serial number: TBD) with a design capacity of 2.0 MMscf per day. This unit is equipped with two (2) Kimray PV45015 glycol pumps with a design capacity of 7.5 gallons per minute each. Only one pump will be operating at a time, with the second pump as a backup. This unit is equippe dl With a flash tank, reboiler and still vent lalnp�ping gas is injected into the still vent Still vent: air-cooled condenser and enclosed flare. Flash tank: closed loop system. This permit is granted subject to all rules and regulations of the Colorado.Air Quality Control Commission and the Colorado Air Pollution Prevention and ContrQQet(C.R.S. 25 7-101'ekeq), to the specific general terms and conditions included in this document a, e following specific tOrn and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the i sion) no later tha►i fifteen days of the latter of commencement of operation or issuance is permit, by submitting a Notice of Startup form to the Division foruipment covered. by this permit. The Notice of Startup form may be downloaded online a ` .colorado. acific/cdphe/other-air-permittin-- notices. Failure to notify the Division o pup of the itted source is a violation of Air Quality Control Comm' sion (AQCC)'Regulation libber 3, �B, Section III.G.1. and can result in the revocation ot it. 2. Within one hundred and ei of this permit, compliance the Division. It is the owne conditi•. Failure t •� P,!7 ertific ermi may, be o ification. (Regulation Ni ays (180latter ofcommencement of operation or issuance the conditions contained in this permit shall be demonstrated to r operatorLesponsibility to self -certify compliance with the mpliance within 180 days may result in revocation of the nce onkhow to self -certify compliance as required by ed online a .colorado.gov/pacific/cdphe/air-permit-self- r 3, Part B,`Section III.G.2.) 3. This�permit shall expire if the o 6r,or operator of the source for which this permit was issued: (i) does of commence" struction odification or operation of this source within 18 months after e, the dateissuance 4f this construction permit or the date on which such construct io r.or activity scheduled to commence as set forth in the permit application associated Wit:It this perm(ii) discontinues construction for a period of eighteen months or more; (iii) does'noficomplete construction within a reasonable time of the estimated completion date. The Division a grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. Point 011: The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • The dehydrator manufacturer name, model number and serial number • The glycol circulation pump manufacturer name and model number COLORADO Air Pollution Control Division Departs , int of Ribirc Neaitrt , Environment Page 2 of 16 This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation Number 3, Part B, III.E.) 6. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility Equipment ID AIRS Point Tons per _ Year Emission Type PM2.5 NO,,>, VOC CO CNDTK 01-04 002 -- 1 7 X1.2 7.5 Point PWT-1 003 0.2 -- Point L-01 004 l -- 0.9 -- Point FL -02 006 -- 8.3 3.3 ' _ Point SEP-01, SEP-02 007 --- 21.4 4.0 Point DEHY-1 011 ilr Ip 7 -- Point Note: See "Notes limits. tssion factors and methods used to calculate Facility -wide emissions of ea individuaizardous air ptlftitant shall not exceed 8.0 tons per year. ... Facil a emissihazardous air pollutants shall not exceed 20.0 tons per year. �emissi mitatiom�hazardous air pollutants shall apply to all permitted fission units at thtsr=facilii fiance with the annual mi , for both criteria and hazardous air pollutants, shall be dete ed on a rollintwelve (12 onth total. By the end of each month a new twelve month total 1 m ulated basecF4 the pr- Us twelve months' data. The permit holder shall calculate actual erns t ns each montha,and keep a compliance record on site or at a local field office with site responsibility for Division review. 8. Point 011: Complianice the emission limits in this permit shall be demonstrated by running the GRI GlyCalc m� on 4.0 or higher on a monthly basis using the most recent extended wet gas analysis and orded operational values, including: dry gas throughput, lean glycol recirculation rate, flash tank closed loop system downtime, flash tank temperature and pressure, wet gas inlet temperature, and wet gas inlet pressure. Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into the model and be provided to the Division upon request. 9. Point 011: On a monthly basis, the owner or operator shalt monitor and record operational values including: flash tank closed loop system downtime, flash tank temperature and pressure, wet gas inlet temperature and pressure. These records shall be maintained for a period of five years. 10. 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.) COPHE COLORADO Air Pollution Control Division Department of Public Hea;tr b Dwtrortme t Page 3 of 16 Facility Equipment ID AIRS Point Control Device Pollutants Controlled CNDTK 01-04 002 Enclosed Flare VOC and HAP PWT-1 003 Enclosed Flare VOC and HAP L-01 004 Enclosed Flare VOC and HAP FL -02 006 Enclosed Fla, VOC and HAP SEP-01, SEP- 02.E 007 Enclos � �4 VOC and HAP DEHY-1 011 Still gent Enclosed flare` VOC and HAP 11. The owner or operator shall operate and IT closed loop system and shall vrecycle 100% (Regulation Number 3, Part B, Section III. E.) in the mission points a table below as a rmissas described �athe table below. Facility Equipment ID AIRS Point , Er 15 Dons Recyc D escription r , Pollutants Recovered DEHY-1 Flash Tank: Recycled to facility inlet or fuel gas system VOC and HAP PROCESS LIMITATIONS 12. Th be li o t`h'e` lLo g maximum processing rates as listed below. Monthly �Ods of t actual processing rates s be maintained by the owner or operator and made ailable to the Division fo itipection upon uest. (Regulation Number 3, Part B, II.A.4. ) racks Limits ,ty Equip On, ID AIR Point Process Parameter Annual Limit CNDTK 01 04 002 ` Condensate throughput 153,300 barrels TANK -1 s rr Produced Water throughput 131,400 barrels L-01 004 Condensate loaded 153,300 barrels FL -02 006 Sales gas routed to flare 15.00 MMscf SEP 01, SEP- 02 007 from low pressure separators routed to the enclosed flares 11.85 MMscf DEHY-1 011 Dry gas throughput 730.00 MMscf The owner or operator shall monitor monthly process rates based on the calendar month. CDPH COLORADO Air Pollution Control Division Department o€ Pubh[ Heath b Esevonment Page 4 of 16 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. 13. Point 006, 007: The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from the separator(s) using a 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. 14. Point 011: This unit shall be limited to the maximum lean glycol circulation rate of 0.406 gallons per minute. The lean glycol recirculation rate shall be recorded weekly in a log maintained on site and made available to the Division for inspection upon request. Glycol recirculation rate shall be monitored by one of the following methods u —1-glycol flow meter(s), or recording strokes per minute and converting to circulation rate. aximum glycol circulation rate does not preclude compliance with the optimal glycol clrct i tit n rate (Loft) provisions under MACT HH. (Reference: Regulation Number 3, Part B, II AZ STATE AND FEDERAL REGULATORY REQUIREMENTS: 15. The permit number and ten digit AIRS ID= er assigned by the U1 ion (e.g. 123/4567/001) shall be marked on the subject equipmen r. ease of identification. lation Number 3, Part B, Section III.E.) I. E.) (State only enforceable) 16. This source is subject to the odorjequirements o 17. Point 002: This source is subject{tom elation Num with all applicable requirements� CII and, sp • Comply with the recordkee for condeisatestorage tanks • Ensure=. enclo of visual' means apprc er 7, S 7, a 11 Sects is used Number 2. (Stat+ fly enforceable) Section XII. The operator shall comply ally, shall: nd emission control requirements ustion d ce co tti oilingemissions from this storage tank be bte emissi and be design " so that an observer can, by means m the ouaeof the enclosed combustion device, or by other ision, det ne whether it is operating properly. (Regulation only en orceable) 18. Point "0O2, 00`6, 00 : The Combustion" device covered by this permit is subject to elation Number XVII.B.2. Gen ral Provisions (State only enforceable). If a flare or otbe combustion to control emissions of volatile organic compounds to comply wit ction XVII, it s be enclosed; have no visible emissions during normal operations, as define der Regulate umber n7j XVII.A.16; and be designed so that an observer can, by means o ual observati 1;1rfrom the outside of the enclosed flare or combustion device, or by other convenient means a roved by the Division, determine whether it is operating properly. e -e This flare must bquippedwith an operational auto -igniter according to the following schedule: • All combusts ces installed on or after May 1, 2014, must be equipped with an operational 1 j igniter upon installation of the combustion device; • All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 19. Point 002: 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 COLORADO Air Pollution Control Division Departrn fit of Public Hearin 6 Elvronment Page 5 of 16 available to the Division upon request. This control requirement must be met within 90 days of the date that the storage tank commences operation. 20. Point 002: 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. 21. Point 004: This source is located in an ozone non -attainment or attainment -maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill, (Reference: Regulation 3, Part B, III.D.2) 22. Point 004: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. 23. Point 004: The owner or operator shall follow toadinedures that minimize the leakage of VOCs to the atmosphere including, but not limited t(i( ence: Regulation 3, Part B, III.D.2): a. The owner or operator shall inspect on couplings, and valves are maintains vapor loss during loading and unloading. Each inspection shall be documetin a b. All compartment hatches at the fad latched at all times wen loading open maintenance, gauging„ ety of person c. Inspect thief hatch seals covers shall be weighted an d. Inspectpressure necess RDs s> and brew Ling losses e. _Document an' tion of lief devicest e set to re not vents „o oens of thie MS-,,fo e"loadinipment to ensure that hoses, revent drip , leaking, or other liquid or The inspectionsayoccur at least monthly. log available to the 'ision on request. inclu 4thief hatched shall be closed and not active, except for periods of l n equipment. integritI replace as necessary. Thief hatch eaied..,,. aar ua for proper operation and replace as at a pr that will ensure flashing, working tugh the PR under normal operating conditions. ch seals and PRD with an indication of status, a it resolution. 24. nt 004: For i contro itAoading operation, the owner or operator shall follow loading cedures that mini e the age of VOCs to the atmosphere including, but not limited to (Reference: Regulation art B, I[I.D.2): f. all and opera he vaporcollection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks. g. Include= vent the release of vapor from vapor recovery hoses not in use. h. Use operating°cedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. i. Operate all recovery and disposal equipment at a back -pressure less than the pressure relief valve setting of transport vehicles. 25. Point 006, 007: 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%. COLORADO Air Pollution Control Division Department o Public Heaah F Egvironment Page 6 of 16 If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. 26. Point 011: This source is subject to Regulation Number 7, Section XII.H. The operator shall comply with all applicable requirements of Section XII and, specifically, shall: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for glycol natural gas dehydrators; and • Ensure uncontrolled actual emissions of volatile organic compounds from the still vent and vent from any gas -condensate -glycol (GCG) separator (flash separator or flash tank), if present, shall be reduced by at least 90 percent on a rolling twelve-month basis through the use of a condenser or air pollution control equipment. (Regulation Number 7, Section XII.H.1.) 27. Point 011: The glycol dehydration unit covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII[? inning May 1, 2015, still vents and vents from any flash separator or flash tank on a glycol natural -has dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas -processing plant subject to control requirements pursuant to Section XVIL6° , shall reduce uncontrolled actual emissions of hydrocarbons by at least 95% on a rolling twelve-month basis through the use of a condenser or air pollution control equip„rment. CDPHE C COLORADO Air Pollution Control Division Department of PubItc Realm & Environment Page 7 of 16 MACT HH Applicable Requirements Area Source Natural Gas throughput exemption §63.764 - General Standards §63.764 Fe)(1) - The owner or operator is exempt from the requirements of paragraph (d) of this section if the criteria listed in paragraph (e)(1)(i) or (ii) of this section are met, except that the records of the determination of these criteria must be maintained as required in §63.774(d)(1). §63.764 (e)(1)(1) - The actual annual average flowrate of natural gas to the glycol dehydration unit is less than 85 thousand standard cubic meters per day (3.0 MMSCF/day), as determined by the procedures specified in §63.772(b)(1) of this subpart §63.772 - Test Methods, Compliance Procedures and Compliance Demonstration §63.772(b) - Determination of glycol dtehydration unit flowrate or benzene emissions. The procedu a - __ his paragraph shall be used by an owner or operator to determine',_g dehydration unit natural gas flowrate or benzene emissions to meet thecriteria for an exemption from control requirements,mun, der §63.764(e)` , . §63.772(b)(1) - The determination of actual flowrate of natural gas to a glycol dehydration unit all be made using the procedures of either paragraph (b)(1)(i) or (b)(1)(ii) of this section. ,(,, ,, §63.772(b) 1)(i) - The owneor o or shall install and operate a monitori yment that (fi€-easures natural gas" overate to the glycol deliion unit with an accuracy of plus or minus 2 percent or better. The owner -operator sha vert annual natural gas flowrate to a daily average by cdi ng the arm flowrate by the number of days per year the glycol dehy a ion unit pr ce d natural gas. �(b)(1)(ii) a owe ors o for shall document, to the Admi tor's satis ction at th virtual annual average natural gas _flowrate_ o the glycoLdehydration unit is less than 85 thousand standard =c bic meters per day. ;d_.,An owner operator of a glycol dehydration unit that mee the exemption cr feria n §63.764(e)(1 i or §63.764(e)(1 iishall maintai n 1 hh e records specified in paragraph (d)(1)(i) or paragraph (d (1)(ii)i 'this section, as appropriate, for that glycol dehydration unit. v §6 4 (d)(1 The actual annual average natural gas throughput (in ter_ natural gas flowrate to the glycol dehydration unit per day) as deters ed in accordance with §63.772(b)(1) §63 Recor[ceeping Requirements "I tip OPERATING Et MAINTENAEREQUIIEMENTS 28. Points 002, 003, 004,' 6, 007, and 011: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OEM) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to the OEM plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 29. Points 002, 004, 006, 007, and 011: The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke COLORADO Air Pollution Control Division Department of Ratak Health F Environment Page 8 of 16 for any period or periods of duration greater than or equal to one minute in any fifteen -minute period during normal operation. (Regulation Number 7, Sections XII.C, XVII.B.2. and XVII.A.16) 30. Point 011: The owner or operator shall complete the initial extended wet gas analysis within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify initial compliance with the emission limits. The owner or operator shall submit the analysis and the emission calculation results to the Division as part of the self -certification process. (Reference: Regulation Number 3, Part B, Section III.E.) Periodic Testing Requirements 31. Points 002, 003, 004, 006, and 007: This source is norequired to conduct periodic testing, unless otherwise directed by the Division or other stet federal requirement. 32. Point 011: The owner or operator shall complete an of the dehydration unit on a■ annual basis Results of thelwet gas analysis shall be used to calculate emissions of criteria pollutants and l ar`dous air tants per this permit and be provided to the Division upon request. ADDITIONAL REQUIREMENTS d wet gas analysis prior to the inlet 33. All previous versions of this permit are cancih elled upon issuance of this pew 34. A revised Air Pollutant Emission Notice (APEN) sha(t'befil (Regulation Number= 3, Part A, II.C.) • Annually by April 30th whenevera significant in case in emissions occurs as follows: • • • • For any criteria pollutan For sources emitting less than 100 tons=peryear, a change in actual emissions of five (5) tons e year _ orrrri®re, above the level repo d on the last APEN; or For voTa iLe organicµ ompounds OC) and nitrogen oxides sources (NOr) in ozone nonattain fi at areas e fitting less than 100 tons of VOC or NO,t per year, a change in nual act emiss,� o ne (1) ton per year or more or five percent, whichever is er,, above t �( tep rtedon the ast APEN; or or sour ,emitting 100 tons per -year or more, a change in actual emissions of five percent 0�tons prear or more,',whichever is less, above the level reported on the last APEN submitted; o _r r any non-cri na reportable pollutant: If the ,emissions increase by 50% or five (5) tons per year, whichever is less, above the levelrted on fie Last APEN submitted to the Division. Whenever here' 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. 35. 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 COLORADO Air Pollution Control Division Department of Pubho Health Et E uonment Page 9 of 16 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 36. 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. 37. 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 conk c s and has been verified by the APCD as conforming in all respects with the conditions rmit. Once self -certification of all points has been reviewed and approved by the Division, it willrovide written documentation of such final authorization. Details for obtaining f' al authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 38. This permit is issued in reliance upon the accuracy and completeness o formation supplied by the owner or operator and is conditioned'upon conduct of the a t yam, or construction, installation and operation of the source, in accordance' with this information and with representations made by the o, eror operator or ►wnFe or operator's agents. is valid only for the equipment and operations ct vity specifically i ntified on the permit. 39. Unless specifically stated otherwisethe general and spec 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. this per s ai erial t 40. Each and evehereof and is not severable. Any�. dfitiort�d��,�� challenge to peal of a co edition he e s constitute a4 -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;s° certifica ion and fir aL uthorization by the Air Pollution Control Division (APCD) on�sgrounds s t ,in Colorado Air Quality Control Act and regulations of the Air Commis QCC), including failure to meet any express term or condition of permitIf t ' Division d ., es a permit, conditions imposed upon a permit are contested by ,owner or open tor,mor the Division revokesla permit, the owner or operator of a source may request a hearing before the Af CC;for review of the Division's action. 41. Sectio►5-7-114.7(2)(a), G .R5 requires that all sources required to file an Air Pollution Emission Notice AN) must pay arrannual 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 cancellatioor he per Upon notification, annual fee billing will terminate. 42. Violation of the terr'ms a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or th gulations 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: Bradley Eades Permit Engineer COLORADO Air Pollution Control Division Department of Public Health Er Environment. Page 10 of 16 Permit History Issuance Date Description Issuance 1 January 9, 2019 Issued to Bonanza Creek Energy Operating Company, LLC Issuance 2 This Issuance Issued to Bonanza Creek Energy Operating Company, LLC Modification in response to addition of one (1) new well. Add point 003 to facility -wide permit (previously 18WE0814). CDPHE L COLORADO Air Pollution Control Division Department of Pubt;o Health & Etc: onment Page 11 of 16 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 Regulatio II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The o operator shall notify the Division of any malfunction condition which causes a violation of an limit or limits stated in this permit as soon as possible, but no later than noon of the nex,`rkiM ayr, followed by written notice to the Division addressing all of the criteria set forth: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 o or of the Division's analysis of the specific compounds emitted if the°rource(s) operate at the permitted limitations. AIRS Point Pollutant CAS.# Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 002 P Benzene c71432 X73 489 Toluene� 108883 8,970 449 Ethylbenzene r . 100414-` x,150 57 411O Xylenes 133020 i i,ilipoTu 2,664 133 o AHexane 0543 � ,, 75,521 3776 TrimethylpentaneKK. 540841; 414 21 Benzene ,IIi 71432 177 9 003 Toluene '' ' j ,, 98883 95 5 t(kylbenzene 100414 6 <1 -Xytenest 1330207 18 1 n -Hex x x,N 110543 57 3 004 Benzenes 71432 63 3 n -Hexane 110543 552 28 006 Benzene 71432 718 36 Toluene 108883 748 37 Ethylbenzene 100414 126 6 Xytenes 1330207 432 22 n -Hexane 110543 5506 275 COLORADO Air Pollution Control Division Department of Public Health 6 Environment. Page 12 of 16 2,2,4- Trimethylpentane 540841 2 <1 007 Benzene 71432 3,356 168 Toluene 108883 3,108 155 Ethylbenzene 100414 330 17 Xylenes 1330207 920 46 n -Hexane 110543 26,354 1,318 2,2,4- Trimethylpentane 540841 14 1 011 Benzene 71432 2459 116 Toluene 108883 v'�i 2894 139 Ethylbenzene 100414 '�" 877, 43 Xylenes 1330207 � 2151' "' � 106 n -Hexane 1105'4 ll 1212 u, 28 Trimethylpentane 540841 139 3 Note: All non -criteria reportable pollutants in the table aboy per year (lb/yr) are reportable and pity resuLt in annual emission ees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this petit are a ed on the Point 002: ncontrolled emissiorrtafes above 250 pounds wing emission factors: CAS # Pollutant P r! Uncontrolled Emission Factors lb/bbi Controlled Emission Factors lb/bbl Source 0.096X,,, 0.0961 CDPHE V0C —13 3437r'�'r 0.6672 ProMax simulation based on site - specific pressurized liquid sample 71`432Benzene" '��D.0638 0.0032 198883 `TaCUene ,, 0.05$5; 0.0029 1 Qg:41, 4 Ethylbenzene 0.0075 0.0004 1330207 Xyler-_ 0.0174 0.0009 11054�� n -Hexane 0.4926 0.0246 540841 2,2,4- Ft 'Trimethylpentane 0.0027 0.0001 Note: The controlleaemissiowfactors for this point are based on the flare control efficiency of 95%. Point 003: CAS # , Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source V0C 0.0345 0.0017 Flash liberation analysis Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. COLORADO Air Pollution Control Division Department of fttbkkc Health & [°rvironment Page 13 of 16 Point 004: Pollutant CAS # Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 0.236 7.91 E-02 CDPHE State Emission Factor n -Hexane 110543 3.60E-03 1.21E-03 Note: The controlled emission factors are based on the flare control efficiency of 95% Point 006: CAS CAS # Pollutant Uncontrolled Emission Factors (lb/MMSCF) trolled Emission Factors , a MISCF) Source NOx 95.60 = 'T95.60 AP -42 Chapter 13.5 CO 435.82 435,.$2:_ VOC 21,91a 04; 1,095.7 __ S 100414 Ethylbenzene 8.37Alit0.42 1330207 Xylene 28.80 =.x1.44 110543 n -Hexane _- 367.07 18.35 Note: The controlled emissions factor Point 007: int are base the flare control efficiency of 95%. CAS # 10 Polluta Uncontrolled , Emission Factors! (lb(lll).- ' qiControlled Emission Factors (iSCF) Source V0C 72,01'5;9 3,600.76 Site -specific LP gas sample collected 1/10/19 71432 Berne 283.19 ' 14.16 1088$ Tolu ',,262.25F q 13.11 10041Ethylbenzene Y 8 5 b '� 1.39 Fi207 "" �fylene 77:64 �: 3.88 ` 1O543 n Hex pe - 2,223.97 111.20 540 2'2' Trimethylp , e 1.18 0.06 Note: The rolled emission factors for this point are based on the flare control efficiency of 95%. Point 011: The emission levels eotai n this permit are based on information provided in the application and the GRI GlyCalc 4 0 r . Controlled emissions are based on a flare control efficiency of 95% and a flash tank closed loop'system control efficiency of 100%. Total actual still vent combustion emissions are based on the sum of the emissions for the still vent primary control. Total combustion emissions are based on the following emission factors: Still Vent Primary Control: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Waste Gas Combusted Source NOx 67.1901 AP -42 Chapter 13.5 Industrial Flares CO 306.3079 COLORADO Air Pollution Control Division Department of Ftinitc Health E Environment Page 14 of 16 Note: The combustion emission factors are based on a heating value of 988 Btu/scf. Actual emissions are calculated by multiplying the emissiom factors in the table above by the waste gas flow from the regenerator overheads stream in the monthly GlyCalc report and by the hours per month the waste gas was routed to this control device. 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 refl ctt -g 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 Syntheti Minors ounce of: �; !, li VOC, tots Ps, i-Hexane `k�r �tiflIllp NANSR Synthetic M Source of: a, iii Area Source Re �eents: Applicable MACT HH 9) Full text of the Title 4i found ..t ht cfr.gpoac e liste nvironment Electronic Code of Federal Regulations can be Par ��60: Standards of Performance for New Stationary Sources NSPS i0..1 -End Subpart A - Subpart KKKK NSPS Par 60, Appendixes Appendix A - Appendix I Part 63: National E hiss o r' Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.5 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 Enveonment Page 15 of 16 C COLORADO Air Pollution Control Division Department of Public Ffea3 ^t & Eniior mane Page 16 of 16 Condensate Storage Tank(s) APES; Form APCD-205 Cal V Air Pollutant Emission Notice (APEN) and 6107 7 pi Application for Construction Permit Gamajad All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store condensate associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/pacific/cdphe/air-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 6WE0004 AIRS ID Number: 123 / 9DB2 / 002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Bonanza Creek Energy Operating Company, LLC Site Name: Whitetail F-4 Production Facility (COGCC #440714) Site Location: Lot 3, T6N, R62W, S4 40.52225, -104.33035 Mailing Address: (Include Zip Code) 410 17th Street, Suite 1400 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Contact Person: Alisson Soehner Phone Number: (303) 803-1752 E -Mail Address2: asoehner@bonanzacrk.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. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 393795 COLORADO 1 I A • HH b EnNMPmM.I Permit Number: 16WE0004 AIRS ID Number: 123 / 9DB2/ 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 ❑ Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP01 O GP08 If General Permit coverage is requested, the General Permit registration fee of $312.50 must be submitted along with the APEN filing fee. -OR- ❑� MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment ❑ Change company name3 O Change permit limit O Transfer of ownership' O Other (describe below) -OR - ❑ APEN submittal for update only (Mote blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit exempt/grandfathered source O Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info it Notes: Updating throughput due to addition of new well. 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: Company equipment Identification No. (optional): For existing sources, operation began on: Condensate tank battery used to store condensate. CNDTK 01-04 03/11/2015 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 Storage tank(s) located at: hours/day 7 ❑✓ Exploration Et Production (E&P) site days/week 52 weeks/year O Midstream or Downstream (non E&P) site Will this equipment be operated in any NAAQS nonattainment area? O Yes • No Are Flash Emissions anticipated from these storage tanks? • Yes • No Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? ■ Yes NI No If "yes", identify the stock tank gas -to -oil ratio: m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No III D Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actualSI emissions ≥ 6 ton/yr (per storage tank)? Yes No • Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 /� COLORADO 2 I AV' nc vlct wwc H N"1OkfnrPRmun, Permit Number: 16WE0004 AIRS ID Number: 123 / 9DB2 / 002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information Condensate Throughput: Actual Annual Amount (bbl/year) 127,750 From what year is the actual annual amount? N/A Average API gravity of sales oil: 40.1 degrees ❑ Internal floating roof Tank design: ❑ Fixed roof Requested Annual Permit Limits (bbl/year) 153,300 RVP of sales oil: 9.8 ❑ External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) - Date of First Production (month/year);, CNDTK01-04 Four (4) 500 bbl 2,000 bbls 10/2018 03/2015 Wells Serviced by this Storage Tank or Tank Battery6 (E8P Sites Ony) API Number Name of Well I Newly Reported Well 05 - 123 - 41166 Whitetail 21-4-9XRLNB ■ 05 - 123 - 46836 Whitetail A-4-9XRLNB O _ ■ ■ ■ s Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 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 orUTM) 40.52225, -104.33035 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) ECD 01-02 —25 500 TBD TBD Indicate the direction of the stack outlet: (check one) 0 Upward El Horizontal ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): 48 ❑ Square/rectangle ❑ Other (describe): Interior stack width (inches): Interior stack depth (inches): Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 '.COLORADO 3 , . nt Pu�c �Fn.Ibm$ Permit Number: 16WE0004 AIRS ID Number: 123 / 9DB2 / 002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Make/Model: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): % ❑ Combustion Device: Pollutants Cortrolled: VOC, HAPs Rating: 5.48 Type: Enclosed Flare MMBtu/hr Make/Model: Two (2) Leed L30-0011 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: N/A Waste Gas Heat Content: 2,975 Btu/scf Constant Pilot Light: ✓❑ Yes ❑ No Pilot Burner Rating: 0.05 MMBtu/hr O Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: % Section 7 - Gas/Liquids Separation Technology Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? -35 psig Describe the separation process between the well and the storage tanks: Gas and oil produced from the well is processed through a high pressure separator where liquids are separated from the natural gas. The liquids from the high pressure separator are sent to the low pressure separators where the oil and water are separated and piped to their respective tanks. All liquids are trucked from the facility. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 ®,COLORADO 4 N0.ia�iV� b En�tronmm� Permit Number: 16WE0004 AIRS ID Number: 123 / 9DB2 /002 [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 form. If multiple emission control methods were identified in Section 6, the following table can be used to state the fficiency (% reduction): Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) VOC ECD 95% NOx CO HAPs ECD 95% Other: From what year is the following reported actual annual emissions data? N/A 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/ ear ) Controlled Emissions (Tons! year) Uncontrolled Emissions (Tons/year) lT Y ) Controlled Emissions (Tons/year) (Tons/Y ) VOC 13.34 lb/bbl ProMax 852.30 42.62 1,022.77 51.14 NOx 0.068 lb/MMBtu AP -42 N/A 1.37 N/A 1.64 CO 0.310 lb/MMBtu AP -42 N/A 6.21 N/A 7.44 Non Crit is 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 8 (Pounds/year) Benzene 71432 0.064 lb/bbl ProMax 8,144.60 408.00 Toluene 108883 0.059 lb/bbl ProMax 7,475.20 374.00 Ethylbenzene 100414 0.008 lb/bbl ProMax 958.06 48.00 Xylene 1330207 0.017 lb/bbl ProMax 2,220.20 112.00 n -Hexane 110543 0.493 lb/bbl ProMax 62,934.00 3,148.00 2,2,4- Trimethylpentane 540841 0.003 lb/bbl ProMax 345.06 18.00 5 Requested values will become permit limitations. Requested limit(s) should consider future growth. 7 Attach condensate liquid laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-205 - Condensate Storage Tanks) APEN - Revision 7/2018 5I AVCOLORADO ' -RZ RwttT P €nnronman� Permit Number: 16WE0004 AIRS ID Number: 123 / 9DB2 / 002 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP01 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. Signature of Legally Authorized Person (not a vendor or consultant) Alisson Soehner Name (print) Date Environmental Engineer, Air Quality 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-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 COLORADO ,�Pu anmro»ni 6 Produced Water Storage Tank(s) APEN - Form APCD-207 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store produced water associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, condensate storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.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. RECEIVED FED 2 1 21019 APCD Stationary S, -,Hr( es � `lJ Permit Number: AIRS ID / 9DB2 h i W �0�� f Number: 123 003 0� [Leave blank unless APCD has already assigned a permit # and AIRS ID] 6/3/I°` Section 1 - Administrative Information Company Name: Bonanza Creek Energy Operating Company, LLC Site Name: Whitetail F-4 Production Facility (COGCC #440714) Site Location: Lot 3, T6N, R62W, S4 40.52225,-104.33035 Mailing Address: (Include Zip Code) 410 17th Street, Suite 1400 Site Location County: Weld NAICS or SIC Code: 1311 Denver, CO 80202 Contact Person: Alisson Soehner Phone Number: (303) 803-1752 E -Mail Address2: asoehner@bonanzacrk.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-207 - Produced Water Storage Tank(s) APEN - Revision 7/2018 393796 COLORADO tEnm or Permit Number: 18WE0814 AIRS ID Number: 123 / 9DB2 / 003 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source ❑ Request coverage under traditional construction permit ❑ Request coverage under a General Permit O GP05 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $312.50 must be submitted along with the APEN filing fee. -OR- ❑✓ MODIFICATION to existing permit (check each box below that applies) O Change in equipment ❑ Change company name3 ❑✓ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info a Notes: Updating throughput due to addition of new well. 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: Company equipment Identification No. (optional): For existing sources, operation began on: Produced water tank battery used to store produced water. PWT-01 03/11/2015 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 Storage tank(s) located at: hours/day 7 days/week 52 ❑✓ Exploration Et Production (EEtP) site weeks/year O Midstream or Downstream (non EEtP) site Will this equipment be operated in any NAAQS nonattainment area? / Yes ❑ No Are Flash Emissions anticipated from these storage tanks? ✓ Yes ❑ No Are these storage tanks located at a commercial facility that accepts oil production wastewater for processing? ❑ Yes No ✓ Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? ❑ Yes ✓ No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. ❑ Yes No ✓ Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? ❑ Yes No ✓ Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 7/2018 AvggricoLoRADo HiNAh6 Ervin, nm, Permit Number: 18WE0814 AIRS ID Number: 123 / 9DB2 / 003 [Leave blank unless APCD has already assigned a permit # and AIRS ID) Section 4 - Storage Tank(s) Information Produced Water. Throughput: Actual Annual Amount (bbllyear) 109,500 Requested Annual Permit Limits (bbl/year) 131,400 From what year is the actual annual amount? Tank design: Fixed roof N/A ❑ Internal floating roof O External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) PWT-01 One (1) 500 bbl 500 bbl 03/2015 03/2015 Wells Serviced by this Storage Tank or Tank Batten/6 (EItP Sites On y) API Number Name of Well Newly Reported Well 05 -123 -41166 Whitetail 21-4-9XRLNB ❑ 05 -123 -46836 Whitetail A-4-9XRLNB 5 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 The EaP 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) -- - 40.52225, -104.33035 Operator Stack ID No. ` Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) ECD 01-02 -25 500 TBD TBD Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ['Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): 48 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 7/2018 3 I ARIIICOLORADO V NvAth°a� M, Permit Number: 18WE0814 AIRS ID Number: 123 I 9DB2 / 003 [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: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: % ❑ Combustion Device: Pollutants Controlled: VOC, HAPs Rating: 0.02 Type: Enclosed Flare MMBtu/hr Make/Model: Two (2) Leed L30-0011 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: N/A Constant Pilot Light: ✓❑ Yes ❑ No Pilot Burner Rating: Waste Gas Heat Content: 1,059 0.02 Btu/scf MMBtu/hr O Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: % Section 7 - Gas/Liquids Separation Technology Information (EBtP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? —35 psig Describe the separation process between the well and the storage tanks: Gas and oil produced from the well is processed through a high pressure separator where liquids are separated from the natural gas. The liquids from the high pressure separator are sent to the low pressure separators where the oil and water are separated and piped to their respective tanks. All liquids are trucked from the facility. Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 7/2018 4 I ArCOLORADO Hw RE 71... n , Permit Number: 18WE0814 AIRS ID Number: 123 / 9DB2 / 003 [Leave blank unless APCD has already assigned a permit II and AIRS ID] Section 8 - 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 iciency (% reduction): Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) VOC ECD 95% NOx CO HAPs ECD 95% Other: From what year is the following reported actual annual emissions data? N/A Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions Requested Annual Permit t(s) Emission Limit(s) Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (tons/year) (tons/ ear Controlled Emissions (tons/year) Uncontrolled Emissions tons/ ear ( Y ) Controlled Emissions (tons/ ear (tons/year) VOC 0.0344 lb/bbl SSEF 1.88 0.10 2.26 0.11 NOx 0.0001 lb/bbl SSEF N/A 0.01 N/A 0.01 CO 0.0005 lb/bbl SSEF N/A 0.03 N/A 0.03 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.) g Uncontrolled Emissions (pounds/year) Y I Controlled Emissions a (pounds/year) Benzene 71432 0.0013 lb/bbl SSEF 148.00 8.00 Toluene 108883 0.0007 lb/bbl SSEF 80.00 4.00 Ethylbenzene 100414 <0.0001 lb/bbl SSEF 6.00 2.00 Xylene 1330207 0.0001 lb/bbl SSEF 16.00 2.00 n -Hexane 110543 0.0004 lb/bbl SSEF 48.00 4.00 2,2,4- Trimethylpentane 540841 N/A N/A N/A N/A N/A 5 Requested values will become permit limitations. Requested limit(s) should consider future growth. 7 Attach produced water laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. COLORADO Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 7/2018 Permit Number: 18WE0814 AIRS ID Number: 123 / 9DB2 / 003 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP05 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. 7,/t1 Signature of Legally Authorized Person (not a vendor or consultant) Date Alisson Soehner Environmental Engineer, Air Quality Name (print) Title Check the appropriate box to request a copy of the: ✓0 Draft permit prior to issuance ✓J 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-207 - Produced Water Storage Tank(s) APEN - Revision 7/2018 6 AVCOLORADO RECErrpD FEB2f 2019 Hydrocarbon Liquid Loading APENc orn, 44 rFr_,r, Form APCD-208 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for hydrocarbon liquid loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, glycol dehydration unit, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 16WE0004 AIRS ID Number: 123 / 9DB2 / 004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Bonanza Creek Energy Operating Company, LLC Site Name: Whitetail F-4 Production Facility (COGCC #440714) Site Location: Lot 3, T6N, R62W, S4 40.52225, -104.33035 Mailing Address: (include zip code) 410 17th Street, Suite 1400 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Contact Person: Alisson Soehner Phone Number: (303) 803-1752 E -Mail Address2: asoehner@bonanzacrk.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 393797 COLORADO x..im a cnairon+++ant Permit Number: 16WE0004 AIRS ID Number: 123 / 9DB2 / 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 construction permit ❑ 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- ❑✓ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment ❑ Change company name3 ✓❑ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Ft Notes: Updating throughput due to addition of new well. 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: Truck loadout used to load condensate into trucks as necessary. Company equipment Identification No. (optional): L-01 For existing sources, operation began on: 05/28/2015 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? MI 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 12 No Is this source located at an oil and gas exploration and production site? Yes No p ■ If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Yes No Fi ■ Does this source splash fill less than 6750 bbl of condensate per year? Yes No NI • Does this source submerge fill less than 16308 bbl of condensate per year? Yes No ■ a Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 AVCOLORADO 2 I ,1�V'N,Fr ii„r „, Permit Number: 16WE0004 AIRS ID Number: 123 / 9DB2 / 004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: ❑✓ Condensate 0 Crude Oil 0 Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded5: 153,300 bbl/year Actual Volume Loaded: This product is loaded from tanks at this facility into: tank trucks (e.g. "rail tank cars" or "tank trucks") 127,750 bbl/year If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: N/A Average temperature of bulk liquid loading: N/A °F True Vapor Pressure: N/A Psia ® 60 °F Molecular weight of displaced vapors: N/A lb/lb-mot 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/ft' Load Line Volume: ft3/truckload Vapor Recovery Line Volume: ft3/truckload 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 jiCOLORADO ty Dcputment we Permit Number: 16WE0004 AIRS ID Number: 123 I 90E32 / 004 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.52225, -104.33035 Operator Stack ID No' Discharge Height Above Ground Level (feet) Tem . p ( F) Flow Rate (ACFM) Velocat X (fir/sec) ECD 01-02 -24 500 TBD TBD Indicate the direction of the stack outlet: (check one) ✓❑ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): O Upward with obstructing raincap Indicate the stack opening and size: (check one) ✓❑ Circular Interior stack diameter (inches): 48 O Other (describe): 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, HAPs Rating: 0.09 MMBtu/hr Type: Enclosed Flare Make/Model: Two (2) Leed L30-0011 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 % Minimum Temperature: N/A °F Waste Gas Heat Content: 2,763 Btu/scf Constant Pilot Light: ❑✓ Yes O No Pilot Burner Rating: N/A MMBtu/hr O Other: Pollutants Controlled: Description: Requested Control Efficiency: Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 COLORADO AV 4 I AiAV wt€ roa°am Permit Number: 16WE0004 AIRS ID Number: 123 / 9DB2 / 004 [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 reduction►: Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) PM SOX NO. CO VOC ECD 95% HAPs ECD 95% Other: 0 Using State Emission Factors (Required for GP07) VOC Benzene n -Hexane ❑✓ Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL O Crude 0.104 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? N/A Pollutant Criteria Pollutant Emissions Inventory Emission Factor Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Controlled Emissions6 (tons/year) Uncontrolled Emissions (tons/year) Requested Annual Permit Emission Limit(s)5 Uncontrolled Emissions (tons/year) Controlled - Emissions` (tons/year) PM 40.0 ug/L AP -42 N/A N/A N/A 0.004 SOX 0.00021 Ib/MMBtu AP -42 N/A N/A N/A <0.0001 NO. 0.068 lb/MMBtu AP -42 N/A N/A N/A 0.026 CO 0.310 lb/MMBtu AP -42 N/A N/A N/A 0.12 VOC. 0.236 lb/bbl State Factor N/A N/A 18.13 0.91 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract - Service (CAS) Number Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, . etc.) Mfg., Uncontrolled Emissions (pounds/year) (P y ) Controlled Emissions6 (pounds/year) Benzene 71432 0.0004 lb/bbl State Factor 64.00 4.00 Toluene 108883 N/A N/A N/A N/A N/A Ethylbenzene 100414 N/A N/A N/A N/A N/A Xylene 1330207 N/A N/A N/A N/A N/A n -Hexane 110543 0.0036 lb/bbl State Factor 554.00 28.00 2,2,4- Trimethylpentane 540841 N/A N/A N/A N/A N/A Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 p ,COLORADO QaV5 I ,�RI�Tfn".„ Hfa�Nk EnW, Permit Number: 16WE0004 AIRS ID Number: 123 /90K/004 [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. - '(zi167 Signature of Legally Authorized Person (not a vendor or consultant) Date Alisson Soehner Environmental Engineer, Air Quality 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 $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-B 1 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 7/2018 V=7"1RADO 3a3sttv� nSL'�Q `�t"15 Gas Venting APEN - Form APCD-2111 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for gas venting only. Gas venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 16WE0004 AIRS ID Number: 123 /9DB2 /006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Bonanza Creek Energy Operating Company, LLC Site Name: Whitetail F-4 Production Facility (COGCC #440714) Site Location: Lot 3, T6N, R62W, S4 Mailing Address: 40.52225, -104.33035 (Include Zip Code) 410 17th Street, Suite 1400 Site Location County: Weld NAICS or SIC Code: 1311 Denver, CO 80202 Contact Person: Alisson Soehner Phone Number: (303) 803-1752 E -Mail Address2: asoehner@bonanzacrk.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-211 - Gas Venting APEN - Revision 7/2018 393799 VI,COLORADO Permit Number: 16WE0004 AIRS ID Number: 123 /9DB2/OO6 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit ❑✓ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) - OR APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: Requesting new throughput due to the addition of a new well. 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: HLP Separator venting when gas cannot be compressed into sales pipeline Company equipment Identification No. (optional): For existing sources, operation began on: FL -02 03/11/2015 For new, modified, or reconstructed sources, the projected start-up date is: ❑✓ 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? Is this equipment subject to Colorado Regulation No. 7, Section XVII.G? Form APCD-211 - Gas Venting APEN - Revision 7/2018 days/week weeks/year Yes Yes Yes No No No COLORADO 2 I RMt AV' /EnP1:PN+MI Permit Number: 16WE0004 AIRS ID Number: 123 I 9DB2 / 006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information ❑✓ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ❑ Blowdown Events # of Events/year: ❑ 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 Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? Gas Venting Process Parameters5: Liquid Throughput Process Parameters5: Vented Gas Properties: ❑ Yes ❑✓ No Vent Gas Heating Value: 1,406 BTU/SCF Requested: 15.0 MMSCF/year Actual: N/A MMSCF/year -OR- Requested: bbl/year Actual: bbl/year Molecular Weight: 24.6 VOC (Weight %) 33.7262 Benzene (Weight %) 0.0738 Toluene (Weight %) 0.0768 Ethylbenzene (Weight %) 0.0129 Xylene (Weight %) 0.0444 n -Hexane (Weight %) 0.5659 2,2,4-Trimethylpentane (Weight %) 0.0001 Additional Required Information: ❑✓ Attach a representative gas analysis (including BTEX Et n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Q COLORADO 3 �� ° dam FiN11716 F.IIhTiM1l111 Form APCD-211 - Gas Venting APEN - Revision 7/2018 Permit Number: 16WE0004 AIRS ID Number: 123 /9DB2/006 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.52225,-104.33035 Operator Stack ID No. Discharge Height - Above Ground Level - (Feet) Temp *F Flow Rate (ACFM) (ACFM) Velocity (ft/sec) FL -02 -35 500 TBD TBD Indicate the direction of the stack outlet: (check one) 0✓ Upward O Horizontal 0 Downward Other (describe): Indicate the stack opening and size: (check one) p✓ Circular ❑ Other (describe): Interior stack diameter (inches): ❑ Upward with obstructing raincap 96 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. VRU: Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed: Make/Model: % % Combustion Device: Pollutants Controlled: Sales Gas, VOC, HAPs Rating: 2.41 Type: Enclosed Flare Make/Model: Two (2) Crimson CE -1000 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: NA Waste Gas Heat Content: 1,406 Btu/scf MMBtu/hr hr Constant Pilot Light: p✓ Yes O No Pilot burner Rating: 0.02 MMBtu/hr Other: Pollutants Controlled: Description: Requested Control Efficiency: Form APCD-211 - Gas Venting APEN - Revision 7/2018 ',COLORADO 41 ificr «br M1ea Ih b ERq�PRTrm Permit Number: 16WE0004 AIRS ID Number: 123 /9DB2/006 [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 r combined) control efficiency (% reduction): Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) PM SOX NO. CO VOC ECD 95% HAPs ECD 95% Other: From what year is the following reported actual annual emissions data? _ N/A Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5. _;, Uncontrolled Basis -(tons/year) Units Source ( AP -42, Mfg., etc.) Uncontrolled Emissions Controlled Emissions 6 (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) PM 40.0 ug/L AP -42 N/A N/A N/A 0.20 SOx 0.00304 ug/L AP -42 N/A N/A N/A 0.03 NO. 0.068 Ib/MMBtu AP -42 N/A N/A N/A 0.72 CO 0.310 Ib/MMBtu AP -42 N/A N/A N/A 3.28 VOC 21,873.1 lb/MMscf SSEF N/A N/A 164.05 8.21 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 6r (pounds/year) Benzene 71432 47.9 lb/MMscf SSEF 718.0 36.0 Toluene 108883 49.8 Ib/MMscf SSEF 748.0 38.0 Ethylbenzene 100414 8.4 lb/MMscf SSEF 126.0 8.0 Xylene 1330207 28.8 Ib/MMscf SSEF 432.0 22.0 n -Hexane 110543 367.0 lb/MMscf SSEF 5,506.0 276.0 2,2,4- Trimethylpentane 540841 0.10 lb/MMscf SSEF 2.0 2.0 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. 5 COLORADO Form APCD-211 - Gas Venting APEN - Revision 7/2018 Permit Number: 16WE0004 AIRS ID Number: 123 / 9DB2 f 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) Date Alisson Soehner Environmental Engineer, Air Quality Name (please print) Title Check the appropriate box to request a copy of the: �✓ 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) 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 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-211 - Gas Venting APEN - Revision 7/2018 OLORADO 6I4467{n:::mtn `ECEry E) FEP 222019 Gas Venting APEN - Form APCD-21icD Air Pollutant Emission Notice (APEN) and rc,ec Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for gas venting only. Gas venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 16WE0004 AIRS ID Number: 123 /9DB2 /007 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Bonanza Creek Energy Operating Company, LLC Site Name: Whitetail F-4 Production Facility (COGCC #440714) Site Location: Lot 3, T6N, R62W, S4 Mailing Address: 40.52225, -104.33035 (Include Zip Code) 410 17th Street, Suite 1400 Site Location Weld County: NAICS or SIC Code: 1311 Denver, CO 80202 Contact Person: Alisson Soehner Phone Number: (303) 803-1752 E -Mail Address2: asoehner@bonanzacrk.com I Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-211 - Gas Venting APEN - Revision 7/2018 3b3798 �W LORADO V 51NttT 6 EnelroMnT� Permit Number: 16WE0004 AIRS ID Number: 123 /9DB2/007 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source -OR- ❑✓ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit O Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) OR - • APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info £t Notes: Requesting new throughput due to the addition of a new well. 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: two (2) enclosed flares. Two (2) high/low pressure separators controlled by Company equipment Identification No. (optional): For existing sources, operation began on: Sep -01, Sep -02 3/11/2015 For new, modified, or reconstructed sources, the projected start-up date is: 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: Will this equipment be operated in any NAAQS nonattainment area? hours/day Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions? Is this equipment subject to Colorado Regulation No. 7, Section XVII.G? Form APCD-211 - Gas Venting APEN - Revision 7/2018 days/week weeks/year O Yes ❑ No 0 Yes 0 No O Yes ❑ No COLORADO 2 I AV H... b Eget!mmi Permit Number: 16WE0004 AIRS ID Number: 123 / 9DB2 / 007 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information ❑✓ Gas/Liquid Separator D Welt Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ❑ Blowdown Events # of Events/year: ❑ 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 Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑✓ Yes Gas Venting Process Parameters5: Liquid Throughput Process Parameters5: Vented Gas Properties: ❑ No Vent Gas Heating Value: 2 195 BTU/SCF Requested: 11.85 MMSCF/year Actual: N/A MMSCF/year -OR- Requested: bbl/year Actual: bbl/year Molecular Weight: 39.1 VOC (Weight %) 69.8048 Benzene (Weight %) 0.2745 Toluene (Weight %) 0.2541 Ethylbenzene (Weight %) 0.0269 Xylene (Weight %) 0.0751 n -Hexane (Weight %) 2.1556 2,2,4-Trimethylpentane (Weight %) 0.0011 Additional Required Information: ▪ Attach a representative gas analysis (including BTEX Et n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-211 - Gas Venting APEN - Revision 7/2018 p e COLORADO Nfilln b EnW l P' ❑✓ Upward ❑ Horizontal Permit Number: 16WE0004 AIRS ID Number: 123 /9DB2/007 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.52225,-104.33035 Operator Stack ID No Discharge Height Above GrouLevel (Feet)nd Temp. ('F) Flow Rate (ACFM) Velocity ift/sec) LPGF ECD -35 500 TBD TBD Indicate the direction of the stack outlet: (check one) ❑ Downward O Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Other (describe): Interior stack diameter (inches): ❑ Upward with obstructing raincap 96 Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. ❑ VRU: Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed: Make/Model: ❑ Combustion Device: Pollutants Controlled: VOC, HAPs Rating: 2.97 MMBtu/hr Type: Enclosed Flare Make/Model: Two (2) Crimson CE -1000 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: NA Waste Gas Heat Content: 2,195 Btu/scf Constant Pilot Light: ❑✓ Yes O No Pilot burner Rating: 0.04 MMBtu/hr Other: Pollutants Controlled: Description: Requested Control Efficiency: Form APCD-211 - Gas Venting APEN - Revision 7/2018 �® COLORADO 4 �a� Permit Number: 16WE0004 AIRS ID Number: 123 /9DB2/007 [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 or combined) control efficiency (% reduction): Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) PM SOx NOx CO VOC ECD 95% HAPs ECD 95% Other: From what year is the following reported actual annual emissions data? N/A Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (x''-42, Mfg., etc-) Uncontrolled Emissions (tons/ ear(tons/year) Y ) Controlled Emissions6 (tons/year) ` Uncontrolled Emissions (tons/year) Controlled Emissions PM 40.0 ug/L AP -42 N/A N/A N/A 0.16 SOx 0.00353 Ib/MMBtu AP -42 N/A N/A N/A 0.05 NOx 0.068 Ib/MMBtu AP -42 N/A N/A N/A 0.89 CO 0.310 Ib/MMBtu AP -42 N/A N/A N/A 4.04 VOC 72,014.98 lb/MMscf SSEF N/A N/A 426.69 21.34 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) Y ) Controlled Emissions6 (pounds/year) Benzene 71432 283.19 Ib/MMscf SSEF 3,356.0 168.0 Toluene 108883 262.15 Ib/MMscf SSEF 3,108.0 156.0 Ethytbenzene 100414 27.75 lb/MMscf SSEF 330.0 18.0 Xylene 1330207 77.48 Ib/MMscf SSEF 920.0 46.0 n -Hexane 110543 2,223.85 Ib/MMscf SSEF 26,354.0 1,318.0 2,2,4- Trimethylpentane 540841 1.13 lb/MMscf SSEF 14.0 2.0 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 - Gas Venting APEN Revision 7/2018 ,COLORADO 5 cnt u"m Permit Number: 16WE0004 AIRS ID Number: 123 / 9D B2 / 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. '2,2J- Signature of Legally Authorized Person (not a vendor or consultant) Date Alisson Soehner Environmental Engineer, Air Quality Name (please 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 $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment 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.Rov/cdphe/apcd Form APCD-211 - Gas Venting APEN - Revision 7/2018 • COLORADO HpNU F [�vl@M1mM, Hello