The URL can be used to link to this page

Browse Search

Home My WebLink About20182741.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 E?�St PO Box 758 Greeley, CO 80632 August 21, 2018 Dear Sir or Madam: RECEIVED AUG 2 7 2018 WELD COUNTY COMMISSIONERS On August 23, 2018, the Air Pollution Control Division will begin a 30 -day public notice period for Bonanza Creek Energy Operating Company - Coyote E-36 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 a Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer PQblic Ri,view qty/tg ""Pl-CeArn/TP). ML(Z'T), Pw ( eR t c H i umf c ts) 08 28-18 2018-2741 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Bonanza Creek Energy Operating Company - Coyote E-36 Production Facility - Weld County Notice Period Begins: August 23, 2018 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Bonanza Creek Energy Operating Company Facility: Coyote E-36 Production Facility Well Production Facility SWSW SEC 36 T8N R63W Weld County The proposed project or activity is as follows: Well Pad equipment The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 17WE0122 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Timothy Sharp Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us keljr COLORADO 1 I PowMa frt'. d�aon+iuse6 Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Timothy Package #: 330108 Received Date: 4/30/2015 Review Start Date: 2/12/2017 Section 01 - Facility Information Company Name: Bousiton Creek Energy Operating company County AIRS ID: 123 '... Plant AIRS ID: 5040 Facility Name: Coyote -E-35 Production Faritity- Physical Address/Locatio SWSW quadrant of Section SEC 36, Township T8N, Range-R63WW, in Weld County, Colorado Type of Facility: Exploration & Production Well Pad What industry segment? oil & NaturolGas Production & Processing Is this facility located in a NAAQS non -attainment area? Yes If yes, for what pollutant? ) arbon Monoxide (co) L articulate Matter (PM) Djazone (NOx a CCC) Weld Quadrant Section Township Range `R63W SWSW SEC 36 TSPI ' Section 02 - Emissions Units In Permit Application AIRS Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks 003 CondensateTank CNDTK-1 Yes 17WE0122 CPS No Permit Issuance 004 Produced Water Tank PW Yes 17WE0122: CP1 . --:No Permit Initial issuance .. •.005 - HydrocarbonL.iquidloading 'TLO -'.. Yes- 17WEO122, CP1 - No Permit Initial - issuance 06 Separator Venting -€ -- SEP 1 -- Yes 17WE0122 _ - CP1. No-:' - Permit Initial Issuance 007 Process Flare FL -1 I yes 17WE0122 CP1 No Permit initial Issuance Section 03 - Description of Project Section 04 - Public Comment Requirements Is Public Comment Required? If yes, why? Requesting Synthetic Min Section 05 - Ambient Air Impact Analysis Requirement: Was a quantitative modeling analysis required? Pto If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Yes 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? SO2 NOx CO VOC PM2.5 PM10 TSP HAPs Cl ® Cj fg 0 0 CI CI 0 Q Ll d Colorado Air Permitting Project If yes, explain what programs and which pollutants here SO2 NOx CO VOC PM2.5 PM10 TSP HAPs Prevention of Significant Deterioration (PSD) ❑ ❑ El ❑ ❑ 0 Title V Operating Permits (OP) 0 0 ❑ 0 El 0 D 0 Non -Attainment New Source Review (NANSR) ❑ ❑ Condensate Storage Tank(s) Emissions Inventory Section 01- Administrative Information Facility AIRs ID: County Plant Point Section 02- Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Section 03- Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Condensate Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Condensate Throughput Barrels (bbl) per year Barrels (bbl) per year Secondary Emissions - Combustion Device(s) Heat content of waste gas= 2639+; Btu/scf Volume of waste gas emitted per BBL of liquids produced = ' 12,33; scf/bbl Actual heat content of waste gm routed to combustion device = Requested heat content of waste gas routed to combustion device = Actual Condensate Throughput While Emissions Controls Operating = '29;206; Barrels (bbl( per year 950 MMBTU per year 1,140 MMBTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device= 1,140 MMBTU per year Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Pollutant Pollutant Uncontrolled Controlled (lb/bbl) Pb/bbl) (Condensate Throughput) 59 .010.. --.0.002.. 0.062 --....:0.007 (Condensate Throughput) 0.08 0.001 0.000 0.000 0.000 0.003 0.000 Control Device Uncontrolled Uncontrolled (Ib/MMBtu) (waste heat comhusted) (lb/bbl) 0-:0680. 0.3700.... (Condensate Throughput) 0.0000 0.0000 0.0022 0.0120 Emission Factor Sauce Emission Factor Source Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled {tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) VOC PM10 PM2.5 NOx CO 27.9 23.2 1.2 27.9 1.4 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.2 0.2 0.2 0.2 0.2 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 350 292 15 350 18 280 234 12 280 14 35 29 1 35 2 70 58 3 70 4 2172 1810 91 2172 109 245 204 10 245 12 Section 06- Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Section XII.C, D, E, F Regulation 7, Section 011.0, C Regulation 7, Section XVII.B, C.1, C.3 Regulation 7, Section XVII.C.2 Regulation 6, Part A, NSPS Subpart Kb Regulation 6, Part A, NSPS Subpart 0000 Regulation 8, Part E, MACT Subpart HH (See regulatory applicability worksheet for detailed analysis) Source requires a permit Storage Tank is not subject to Regulation 7, Section XII.C-F Storage Tank is not subject to Regulation 7, Section %II.G Storage tank is subject to Regulation 7, Section XVII, 5, C.1 & C.3 Storage tank is subject to Regulation 7, Section XVII.C.2 Storage Tank is not subject to NSPS Kb Storage tank is subject to NSPS 0000 Storage Tank is not subject to MAR NH 3of 20 K:\PA\2017\17WE0122.CP1.xlsm Condensate Storage Tank(s) Emissions Inventory Section 07- Initial and Periodic Sampling and Testing Requirements Does the company use the state default emissions factors to estimate emissions? If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? -` If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 -Technical Analysis Notes Section 09 - Inventory 5CC Coding and Emissions Factors AIRS Point # 003. Process SCC Code 01 '�ti,7a2fcs€ Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons condensate throughput PM2.5 0.00 0 lb/1,000 gallons condensate throughput NOx 0.05 0 lb/1,000 gallons condensate throughput VOC 37.9 95 lb/1,000 gallons condensate throughput CO 0.29 0 lb/1,000 gallons condensate throughput Benzene 0.24 95 lb/1,000 gallons condensate throughput Toluene 0.19 95 lb/1,000 gallons condensate throughput Ethylbenzene 0.02 95 lb/1,000 gallons condensate throughput Xylene 0.05 95 lb/1,000 gallons condensate throughput n -Hexane 1.48 95 lb/1,000 gallons condensate throughput 224 TMP 0.17 95 lb/1,000 gallons condensate throughput 4 of 20 K:\PA\2017\17WE0122.CP1.xlsm Condensate Tank Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and I - APEN and Permit Reeuirements [Source o in the Non.Attninment Aron 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 05-03 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 11.0.3)? 0 You hove indicated that nourtn in in the Non•Atteinment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section ll.U.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 end1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than SIPS or CO emissions greater than 5 TPY (Regulation 3, Part e, Section 11.0.2)7 'Source requires a permit Colorado Regulation 7, Section XII.C-F 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at an oil and gas exploration and production operation', natural gas compressor station or natural gas drip station? 3. Is this storage tank located upstream of a natural gas processing plant? IStorage Tank is not sohlent to Regulation 7, Section Xn.f F Section XII.C.1 — General Requirements for Air Pollution Control Equipment— Prevention of Leakage Section XII.C.2—Emission Estimation Procedures Section XII.D —Emissions Control Requirements Section XII.E — Monitoring Section XII.F—Recordkeeping and Reporting Colorado Regulation 7, Section XII.G 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at a natural gas processing plant? 3. Does this storage tank exhibit "Flash" (e.g. storing non-stakilleed liquids) emissions and have uncontrolled actual emissions greater than or equal to 2 tons per year VOC? ISto3age Tank is not subject to Regulation 7, Section 011.0 Section 011.0.2 - 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 er year VOC? Storage tank in subject to Reguint ion 7, Section XVit, R, C..1. C C.? Section XVII.B — General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.C.1- Emissions Control and Monitoring Provisions Section XVII.C.3 - Recordkeeping Requirements 5. Does the condensate storage tank contain only "stabilized" liquids? 'Storage tank is subject to Regulation 7, Section XVII.C.2 Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart Kb. Standards of Performance for Volatile Organic Liquid Storage Vessels 1. Is the Individual storage vessel capacity greater than or equal to 75 cubic meters (ma) [`472 BBLs]? 2. Does the storage vessel meet the following exemption in 60.1116(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 60.111k? 3. Was this condensate storage tank constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) afterJuiy 23, 1984? 4. Does the tank meet the definition of "storage vessel"a in 60.1116? 5. Does the storage vessel store a "volatile organic liquid (VOL)" as defined In 60.1116? 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 kPe (60.1106(h))?; or c. The design capacity is greater than or equal to 75 Ma (^472 BBL] but less than 151 m'(-950 BBL] and stores a liquid with a maximum true vapor pressure' less than 15.0 kPa(60.110b(6))? 'Storage Tank is not subject to NSPS Kb Subpart A, General Provisions §60.1126 - Emissions Control Standards for VOC 160.1136 - Testing and Procedures §60.1156 - Reporting and Recordkeeping Requirements §60.1166 - Monitoring of Operations Yos Yes Yes trio: Yes Nn ti yes YA5 Yrs Source Req Go to next Source Req Continue -' Continue-' Storage Tar Continue-' Storage Tai Source is st Continue -' Go to then Go to then Source is st Go to the n Storage Tar 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 10, 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 HH7 (Storage tank is subiact to 55P5 0000 Subpart A, General Provisions per §60.5425 Table 3 §60.5395 - Emissions Control Standards far VOC §60.5413 - Testing and Procedures §60.5395(g) - Notification, Reporting and Recordkeeping Requirements 460.5916(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 60.53651e)(2) even If potential VOC emissions drop below 6 tons per year] 40 CFR, Part 63, Subpart MACT HH, Oil and Gas Production Facilities 1. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(x)(2)); OR b. A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end users 163.760(x)(3))7 2. Is the tank located at a facility that Is major' for HAPs7 3. Does the tank meet the definition of "storage vessel" " in 63.7617 4. Does the tank meet the definition of "storage vessel with the potential for flash emission's per 63.7617 5. Is the tank subject to control requirements under 40 CFR Part 60, Subpart Kb or Sub art 00007 [Storage Tankis nos subject ko MACT HH Subpart A, General provisions per §63.764 (a) Table 2 §63.766 - Emissions Control Standards §63.773 - Monitoring §63.774 - Recordkeeping. §63.775 - Reporting RACT Review RACT review is required if Regulation 7 does not apply AND If the tank is in the non -attainment area. If the tank meets both criteria, then review RACT 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 end 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 Yes V Continue-' Go to then Go to the n Go to then Source is st Continue -' Storage Tat Produced Water Storage Tank(s) Emissions Inventory Section 01- Administrative Information Facility AIRs ID: Plant 004........;.: Section 02- Equipment Description Details Detailed Emissions Unit 500bbl Produced Water Storage Tank Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Produced Water Throughput= Requested Permit Limit Throughput = Potential to Emit (PTE) Produoed Water Throughput = •,740'. Barrels (bbl) per year ,7401 Barrels (bbl) per year 120 Barrels (bbl) per year Secondary Emissions • Combustion Device(s) Heat content of waste gas= a x;2650 Btu/scf Volume of waste gas emitted per BBL of liquids produced = 36 scf/bbl Actual heat content of waste gas routed to combustion device - Requested heat content of waste gas routed to combustion device = Actual Produced Water Throughput While Emissions Controls Operating = - 300,740 9,571 MMBTU per year 9,571 MMBTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 11,485 MMBTU per year Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Emission Factors Produced Water Tank Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) (Produced Water Throughput) (Produced Water Throughput) Emission Factor Source VOC 0.2W 0.007 0.01 0.000 0.000 0.000 0.000 0.001 0.000 Control Device Benzene Toluene Ethylbenxene Xylene n -Hexane 224 TMP Pollutant Emission Factor Source Uncontrolled Uncontrolled (Ib/MMBtu) (ib/bbl) (waste heat combusted) (Produced Water Throughput) PM10 PM2.5 0.0000 0.0000 0.0065 0.0295 NOx CO 0.0680 :3100 Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) VOC 15.8 13.2 0.7 13.2 0.7 PM10 0.0 0,0 0.0 0.0 0.0 PM2.5 0.0 0.0 0.0 0.0 0.0 NOx 0.4 0.3 0.3 0.3 0.3 CO 1.8 1.5 1.5 1.5 1.5 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (lbs/year) (lbs/year) (lbs/year) (lbs/year) (lbs/year) Benzene 846 705 35 705 35 Toluene 0 0 0 0 0 Ethylbenxene 0 0 0 0 0 Xylene 0 0 - 0 0 0 n -Hexane 2660 2216 111 2216 111 224 IMP 0 0 0 0 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XVII.B, Cl, C.3 Storage tank is subject to Regulation 7, Section XVII, B, Cl & 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 0000 Storage tank is subject to NSPS 0000 (See regulatory applicability worksheet for detailed analysis) 7 of 20 K:\PA\2017\17WE0122.CP1.xlsm Produced Water Storage Tank(s) Emissions Inventory Section 07- Initial and Periodic Sampling and Testing Requirements Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid water sample drawn at the facility being permitted and analyzed using flash liberation analysis? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. 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 adcitional 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 0R -Technical Analysis Notes Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # Process 6 SCC Code 004 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 0.15 0 lb/1,000 gallons liquid throughput VOC 6.2 95 lb/1,000 gallons liquid throughput CO 0.70 0 lb/1,000 gallons liquid throughput Benzene 0.17 95 lb/1,000 gallons liquid throughput Toluene 0.00 95 lb/1,000 gallons liquid throughput Ethylbenzene 0.00 95 16/1,000 gallons liquid throughput Xylene 0.00 95 lb/1,000 gallons liquid throughput n -Hexane 0.52 95 1b/1,000 gallons liquid throughput 224 TMP 0.00 95 lb/1,000 gallons liquid throughput S of 20 K:\PA\2017\17WE0122.CP1.xlsm Produced Water Storage Tank Regulatory Analysis Worksheet Please note that NSPS Kb might be might be applicable for certain tanks at water management and injection facilities. If the tanks you are 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 5 TPY, IV -Ox greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? You have indicated that source iv 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 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section II,D.2)? Source requires a permit Colorado Regulation 7. Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this produced water storage tank' located at an oil and gas exploration and production operation , well production facility', natural gas compressor 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 subjed to €Regu€ation 7, Section XVII, B, C.I. & C.3 Section XVII.B —General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.C.1 - Emissions Control and Monitoring Provisions Section XVII.C.3 - Recordkeeping Requirements 5. Does the produced water storage tank contain only "stabilized" liquids? If no, the following additional provisions apply. (Storage tank is subject to Regulation 7, Section XV€I,C,2 Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart 0000, 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? 'Storage tank is subject to NSPS 0000 Subpart A, General Provisions per §60.5425 Table 3 §60.5395 - Emissions Control Standards for VOC §60.5413 - Testing and Procedures §60.5395(g) - Notification, Reporting and Recordkeeping Requirements §60.5416(c) - Cover and Closed Vent System Monitoring Requirements §60.5417 - Control Device Monitoring Requirements (Note: If a storage vessel Is previously determined to be subject to NSPS 0000 due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS 0000 per 60.5365(e)(2) even if potential VOC emissions drop below 6 tons per year) RACI' Review RACI' 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 Yes Yes Source Req Go to next ' Source Req Continue -' Continue -' Go to then Source is sr Continue -' Go to then Storage Tar Go to the n Hydrocarbon Loadout Emissions Inventory Section 01- Administrative Information Facility AIRS ID: County Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Is this loadout controlled? Collection Efficiency: Control Efficiency: 95.00 Requested Overall VOC & HAP Control Efficiency %: Section 03- Processing Rate Information for Emissions Estimates Primary Emissions - Hydrocarbon Loadout Actual Volume Loaded = Requested Permit Limit Throughput = Potential to Emit (PTE) Volume Loaded = Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per year = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = Barrels (bbl) per year Barrels (bbl) per year Barrels (bbl) per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = Section 04- Emissions Factors & Methodologies Does the company use the state default emissions factors to estimate emissions Are the emissions factors based on a stabilized hydrocarbon liquid sample drawn at the facility being permitted? Loading Loss Equation L = 12.46'S'P"M/T Actual Volume Loaded While Emissions Controls Operating = 51858.79781 114 MMBTU per year 137 MMBTU per year 137 MMBTU per year The stabilized hydrocarbon liquid sample is valid for developing site specific emissions factors. Factor Meaning Value Units Source S Saturation Factor 1 m_.. 'ir'Op�.Vt:' �;� ... ii'�f•, .... � ...... ,,. ^"�. y �;.. ; ... , �Ba�iSs89z3WCu=jS�3} .,: P True Vapor Pressure ' " 4.59 r. psia__- M Molecular Weight of Vapors "45.75 -= lb/lb-mol T Liquid Temperature ;505.42 Rankine -- - --' L Loading Losses 4.256 lb/1000 gallons 0.178752 lb/bbl Component Mass Fraction Emission Factor Units 5onrce Benzene ' 0.0060053 0.001180711 lb/bbl - - - Toluene -- 0 lb/bbl Ethylbenzene 0 lb/bbl Xylene "" ,.. 0 lb/bbl n -Hexane 0.0398235 -' 0.00711853 lb/bbl 224TMP - 0 lb/bbl Emission Factors Hydrocarbon Loadout Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) (Volume Loaded) (Volume Loaded) 8.94E-03 5.90E-05 0.00E+00 0.00E+00 0.00E+00 3.56E-04 0.00E+00 VOC Benzene Toluene -03 Ethylbenzene Xylene n -Hexane 224 TMP Emission Factor Source Emission Factor Source Pollutant. Control Device Uncontrolled Uncontrolled (Ib/MMBtu) (lb/bbl) (waste heat combusted) (Volume Loaded) 0.00E+00 0.00E+00 0.00E+00 2.66E-04 1.21E-03 PM10 PM2.5 5Ox NOx CO 0.3100 _. 10 of 20 K:\PA\2017\17 W E0122.CPl.xl sm Hydrocarbon Loadout Emissions Inventory Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/yearl (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) PM10 0.00 0.00 0.00 0.00 0.00 PM2.5 0.00 0.00 0.00 0.00 0.00 500 0.00 0.00 0.00 0.00 0.00 NOx 0.00 0.00 0.00 0.00 0.00 VOC 3.13 2.61 0.13 3.13 0.16 CO 0.02 0.02 0.02 - 0.02 0.02 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (Ibs/year) (Ibs/year) (Ibs/year) (Ibs/year) llbs/yearl Benzene 41 34 2 41 2 Toluene 0 0 0 0 0 Ethylbenzene 0 0 0 0 0 %ylene 0 0 0 0 0 n -Hexane 249 208 10 249 12 224 TMP 0 0 0 0 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit PACT- Regulation 3, Part B, Section III.D.2.a (See regulatory applicability worksheet for detailed analysis) The loadout must be operated with submerged fill to satisfy RACT. Section 07- Initial and Periodic Sampling and Testing Requirements Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point# 005 Process 01 SCC Code 4-06-001-42 Crude Oil: Submerged Loading Balanced Service (0=1) 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 16/1,000 gallons transferred VOC 4.3 95 (5/1,000 gallons transferred CO 0.03 0 Ib/1,000 gallons transferred Benzene 0.03 95 lb/1,000 gallons transferred Toluene 0,00 95 lb/1,000 gallons transferred Ethylbenzene 0.00 95 lb/1,000 gallons transferred Xylene 0.00 95 lb/1,000 gallons transferred n -Hexane 0.17 95 lb/1,000 gallons transferred 224 TMP 0.00 95 lb/1,000 gallons transferred 11 of 20 K:\PA\2017\17 W E0122.CP1.xlsm Hydrocarbon Loadout Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements Source is in the Nan -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.1.1)? 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 11.0.1.1)? 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 5 TPY (Regulation 3, Part B, Section II.D.2)? 'Source requires a permit Yes: fey Nq. No! No • 7. RACT - Are uncontrolled VOC emissions from the loadout operation greater than 20 tpy (Regulation 3, Part B, Section III.D.2.a)? 'The loadout must Inc operated with submerged fill to satisfy RACT. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," "may," "should," and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must' and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. Go to next ' Go to the n Go to next , Go to next , Go to next, The loadou Nff.._"____' The loadou Separator Venting Emissions Inventory Section 01 - Administrative Information Facility AIRS ID: County 9ddd'i Plant Section 02 - Equipment Description Details Detailed Emissions Unit Description: enclosed combustor Requested Overall VOC & HAP Control Efficiency %: Limited Process Parameter Gas meter Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Separator Actual Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput = Process Control (Recycling) Equipped with a VRU Is VRU process equipment: MMscf per year MMscf per year 2 MMscf per year 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 Displacement Equation Ex=Q•MW'Xx/C Weight Helium CO2 N2 methane ethane propane isobutane n -butane isopentane n -pentane cyclopentane n -Hexane cyclohexane Other hexanes heptanes methylcyclohexane 224-TMP Benzene Toluene Ethylbenzene Xylenes C8+ Heavies 0.12 0.11- 0-,11: 0:04 AB: Total VOC Wt 99.94 50.29 Btu/scf scf/bbl Ib/Ib-mol 13 of 20 K:\PA\2017\ 17WE0122.CP1.xlsm Separator Venting Emissions Inventory Emission Factors Separator Venting Pollutant Uncontrolled Controlled (Ib/MMscf) (Ib/MMscf) (Gas Throughput) (Gas Throughput) Emission Factor Source VOC 40866,1551 2043.3078 Benzene Toluene 89.7182 86.4675 29.2559 48.4348 647.2063 96.3821 4.4859 4.3234 1.4628 2.4217 32.3603 4.8191 Ethylbenzene Xylene n -Hexane 224 TMP Emission Factor Source Pollutant Primary Control Device Uncontrolled Uncontrolled (lb/MMBtu) lb/MMscf (Waste Heat Combusted) (Gas Throughput) PM10 PM2.5 0.000 0.000 0.000 500 Nog CO 115.940 528.550 Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) PM10 0.00 0.00 0.00 0.00 0,00 PM2.5 0.00 0.00 0.00 -- 0.00 0.00 500 0.00 0.00 0.00 0.00 0.00 NOx 0.13 0.00 0.00 0.13 0.13 VOC 44.95 0.00 0.00 44.95 2.25 CO 0.58 0.00 0.00 0.58 0.58 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled - Uncontrolled Controlled (lbs/year) (lbs/year) (lbs/year) (lbs/year) (lbs/year) Benzene 197 0 0 197 10 Toluene 190 0 0 190 10 Ethylbenzene 64 0 0 64 3 Xylene 107 0 0 107 5 n -Hexane 1424 0 0 1424 71 224 TMP 212 0 0 212 11 Section 06 - Regulatory Summary Ana>is Regulation 3, Parts A, B Regulation 7, Section XVII.B, G Regulation 7, Section X)/II.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 Source requires a permit Source is subject to Regulation 7, section XVll.6.2, G The control device for this separator is not subject to Regulation 7, Section XVII.B.2.e 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? 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? No If no, the permit will contain a condition that requires the operator to calculate gas throughput using the liquid throughput until the meter is installed and operational (not to exceed 180 days). This condition will use the "Volume of waste gas emitted per BBL of liquids throughput" (scf/bbl) value in section 03. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling You have indicated above that the monitored process parameter is natural gas vented. The following questions do 14 of 20 K:\PA\2017\17 W E0122.CP1.xl sm Separator Venting Emissions Inventory Section 08 - Technical Analysis Notes Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point N Process 8 SCC Code 006 01 3-10-001-60 Flares Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 Ib/MMSCF PM2.5 0.00 0 Ib/MMSCF SOx 0.00 0 Ib/MMSCF NOx 115.94 0 Ib/MMSCF VOC 40866.16 95 Ib/MMSCF CO 528.55 0 Ib/MMSCF Benzene 89.72 95 Ib/MMSCF Toluene 86.47 95 Ib/MMSCF Ethylbenzene 29.26 95 Ib/MMSCF Xylene 48.43 95 Ib/MMSCF n -Hexane 647.21 95 Ib/MMSCF 224 IMP 96.38 95 Ib/MMSCF 15 of 20 K:\PA\2017\17WE0122.CP1.xlsm Separator Venting Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements Source is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? You haveindicated that source is in the Non -Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section II.D.2)? MOM ;! '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.S..2, C 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 XYII.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 Source Req Source Req 'f@u !source IS SL The control Separator Venting Emissions Inventory Section 01- Administrative Information 'Facility AIRs ID: 1. 3 County 9d4d Plant 007 Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Two 2) enclosed combustorn Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Limited Process Parameter Gas meter atwatfoo ranted_, Yes meterSm H irssta Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Separator Actual Throughput = Requested Permit Limit Throughput = Potential to Emit (PTE) Throughput = Process Control (Recycling) Equipped with a VRU: Is VRU process equipment. - MMscf per year MMscf per year 71 MMscf per year 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 Displacement Equation Ex=Q*MW *Xx/C €$49_Btu/scf scf/hhl MW 23 Weight % Helium CO2 N2 methane ethane 5.28 4:57 5.:52 propane isobutane n -butane isopentane n -pentane cyclopentane n -Hexane cyclohexane Other hexanes heptanes methylcyclohexane 224-TMP Benzene Toluene Ethylbenzone Xylenes C8+ Heavies 140 4.32 0.79 0.51 0.17 0.41 0.13 0'.04 0,66 O.05 0.01 15 Total VOC Wt % 99.69 27.69 Ib/Ib-mol 17 of 20 K:\PA\2017\17 W E0122.CP 1.xls m Separator Venting Emissions Inventory Pollutant Separator Venting Uncontrolled - (lb/MMscf) Controlled (Ib/MMsgf) 16803.9578 37.6740 840,1979 1.4946 Millin :311 INEIRE 249.7120 4.2620 0.4028 Pollutant Section 05 - Emissions Inventory Primary Control Device Uncontrolled (lb/MMBtu) (Waste Heat Combusted) Uncontrolled lb/MMscf (Gas Throughput) Emission Factor Source Emission Factor Source Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) PM10 PM2.5 SOx NOx VOC CO 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.14 0.00 0.00 3.14 3.14 598.22 0.00 0.00 598.22 29.91 17,11 0.00 0.00 17.11 17.11 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP 2682 0 0 2682 134 2128 0 0 2128 106 303 0 0 303 15 574 0 0 574 29 17779 0 0 17779 889 1771 0 0 1771 09 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XVII.e, G Source is subject to Regulation 7, Section XVII.8.2, 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-specificl,ss 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? 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? No If no, the permit will contain a condition that requires the operator to calculate gas throughput using the liquid throughput until the meter is installed and operational (not to exceed 180 days). This condition will use the "Volume of waste gas emitted per BBL of liquids throughput" (scf/bbl) value in section 03. Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling you have indicated above that the monitored process parameter is n Ural gas vented. The following questions do not require an answer. 18 of 20 K:\PA\2017\17W E0122.CP1.xlsm Separator Venting Emissions Inventory Section 08 - Technical Analysis Notes Applicant has accounted for a 30% buffer in the emissions estimate. The throughput limit has been increased by 30% Section 09 - Inventory 5CC Cockle and Emissions Factors AIRS Point # 007 Process # 5CC Code 01 3-10-001-60 Flares Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 Ili/MMSCF PM2.5 0.00 0 Ib/MMSCF SOx 0.00 0 Ili/MMSCF NOS 88.33 0 Ib/MMSCF VOC 16803.96 95 1b/MMSCF CO 480.63 0 Ili/MMSCF Benzene 37.67 95 Ib/MMSCF Toluene 29.89 95 Ili/MMSCF Ethylbenzene 4.26 95 Ib/MMSCF Xylene 8.06 95 Ib/MMSCF n -Hexane 249.71 95 Ib/MMSCF 224 IMP 24.87 95 lb/MMSCF 19 of 20 K:\PA\2017\ 17WE0122.CP1.xlsm Separator Venting Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements Source is in tire Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? IYou have indicated that source is in the Non -Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 5 TPY (Regulation 3, Part B, Section 11.O.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 XVil.B.2, G 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 with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as "recommend," "may," "should," and "can," is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself Source Req Source Req The control Permit number: Date issued: Issued to: COLORADO Air Pollution Control Division Department of Public Health & Environment CONSTRUCTION PERMIT 17WE0122 DRAFT Bonanza Creek Energy Operating Company Facility Name: Plant AIRS ID: Physical Location: County: General Description: Issuance: 1 Coyote E-36 Production Facility 123/9D4D SWSW SEC 36 T8N R63W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description CNDTK-1 003 Three (3) 500 barrel fixed roof storage vessels used to store condensate Enclosed Combustor PW 004 One (1) 500 barrel fixed roof storage vessel used to store produced water Enclosed Combustor TLO 005 Truck loadout of condensate by submerged fill Enclosed Combustor SEP-1 006 Low Pressure Separator Enclosed Combustor FL -1 007 High Pressure Separator Enclosed Combustor This permit is granted subject to all rules and regulations of the Colorado Air Quality Control Commission and the Colorado Air Pollution Prevention and Control Act (C. R.S. 25-7-101 et seq), to the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air COLORADO Air Pollution Control Division JzpslWit•#_'! t ct 1''t.ih4tr F?eiht^'v itnxvnnme;t Page 1 of 11 Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self- certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable -time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. Point(s): 006, 007 Within one hundred and eighty days (180) after issuance of this permit, the operator shall install a flow meter to monitor and record volumetric flow rate of natural gas vented from each separator covered by this permit. 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-1 003 --- --- 1.4 --- Point PW 004 --- --- 0.7 --- Point TLO 005 --- --- 1.1 --- Point SEP-1 006 --- --- 2.3 --- Point FL -1 007 --- 3.2 29.9 17.1 Point Note: See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall not exceed 8.0 tons per year. The facility -wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. COLORADO Air Pollution Control Division Puy₹it 1 tec;en s E^,vnanrnent. Page 2 of 11 Compliance with the annual limits, for both criteria and hazardous air pollutants, shalt be determined on a rolling twelve (12) month total. By the end of each month a new twelve month total is calculated based on the previous twelve months' data. The permit holder shall calculate actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 8. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled CNDTK-1 003 Enclosed Combustor VOC and HAP PW 004 Enclosed Combustor VOC and HAP TLO 005 Enclosed Combustor VOC and HAP SEP-1 006 Enclosed Combustor VOC and HAP FL -1 007 Enclosed Combustor VOC and HAP PROCESS LIMITATIONS AND RECORD'S 9. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for iispection upon request. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit CNDTK-1 003 Condensate throughput 35,040 barrels PW 004 Water throughput 100,740 barrels TLO 005 Condensate throughput 35,040 barrels SEP-1 006 Natural Gas Venting 2.2 MMscf FL -1 007 Natural Gas Venting 71.2 MMscf The owner or operator shall monitor monthly process rates based on the calendar month. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 10. Point(s): 006, 007 Upon installation of the flow meter, the owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from the separator(s) using the flow meter. The owner or operator shall use monthly throughput records to demonstrate COLORADO Air Pollution Control Division i,,fxvv at%of O'ito JOrlitlent Page 3 of 11 compliance with the process limits contained in this permit and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 11. Point(s): 003, 004, 006, 007 The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/4567/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 12. Point(s): 003, 004, 005 No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Regulation Number 1, Section II.A.5:) 13. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 14. Point(s): 003, 004 The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.B.2. General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. This flare must be equipped with an operational auto -igniter according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; • All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 15. Point(s): 003, 004 The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall install and operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons except where the combustion device has been authorized by permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation Number 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two years, made available to the Division upon request. This control requirement must be met within 90 days of the date that the storage tank commences operation. 16. Point(s): 003, 004 The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Section XVII.C.2. 17. Point(s): 005 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) 18. Point(s): 005 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. 19. Point(s): 005 The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.D.2): • The owner or operator shall inspect onsite loading equipment to ensure that hoses, couplings, and valves are maintained to prevent dripping, leaking, or other liquid or COLORADO .Air Pollution Control Division thtc Yieci h E _ rr6nment Page 4 of 11 vapor loss during loading and unloading. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. • All compartment hatches at the facility (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. • Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. • Inspect pressure relief devices (PRD) annually for proper operation and replace as necessary. PRDs shall be set to release at a pressure that will ensure flashing, working and breathing losses are not vented through the PRD under normal operating conditions. Document annual inspections of thief hatch seats and PRD with an indication of status, a description of any problems found, and their resolution. 20. Point(s): 005 For this controlled loading operation, the owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.D.2): • Install and operate the vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks. • Include devices to prevent the release of vapor from vapor recovery hoses not in use. • Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. • Operate all recovery and disposal equipment at a back -pressure less than the pressure relief valve setting of transport vehicles. 21. Point(s): 006, 007 The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.B.2. General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, XVII.A.16; and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. This flare must be equipped with an operational auto -igniter according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device; • All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 22. Point(s): 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%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. OPERATING Et MAINTENANCE REQUIREMENTS 23. Point(s): 003, 004, 005, 006, 007 Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the • COLORADO Air Pollution Control Division t:;mbrrtent Page 5 of 11 requirements of this permit. Revisions to the OaM 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 24. Point(s): 003, 004, 006, 007 The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen -minute period during normal operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.16) Periodic Testing Requirements 25. Point(s): 003, 004, 006, 007This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 26. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOX) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. GENERAL TERMS AND CONDITIONS 27. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation 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. COLORADO Air Pollution Control Division v.,.i Esrirsnsvte£:t Page 6 of 11 28. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7- 114.5(12)(a) C.R.S. and AQCC Regulation Number 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 29. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 30. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 31. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shalt be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 32. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 33. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Bonanza Creek Energy Operating Company LLC [COLORADO 3 ! Air Pollution Control Division eptot - sC -7t Ptttvii^ t evath$ Envrronr>, rtC Page 7 of 11 Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (Ib/yr) Controlled Emissions (lb/yr) 003 Benzene 71432 350 18 Toluene 108883 280 14 Ethylbenzene 100414 35 2 Xylenes 1330207 70 4 n -Hexane 110543 2172 109 2,2,4- Trimethylpentane 540841 245 12 004 Benzene 71432 705 35 n -Hexane 110543 2216 111 005 Benzene 71432 41 2 n -Hexane 110543 249 12 006 Benzene 71432 197 10 Toluene 108883 190 10 Ethylbenzene 100414 64 3 Xylenes 1330207 107 5 n -Hexane 110543 1424 71 2,2,4- Trimethylpentane 540841 212 11 007 Benzene 71432 2682 134 Toluene 108883 2128 106 OLORADO Air Pollution Control Division hub c Hea th i ti sxrcnnmerc Page 8 of 11 Ethylbenzene 100414 303 15 Xylenes 1330207 574 29 n -Hexane 110543 17779 889 2,2,4- Trimethylpentane 540841 1771 89 Note: All non -criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 004: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 0.068 lb/MMBtu CDPHE CO 0.371b/MMBtu CDPHE VOC 1.59 Source 71432 Benzene 0.010 Source 108883 Toluene 0.008 Source 110543 n -Hexane 0.062 Source Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. Point 005: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 0.0681b/MMBtu CDPHE CO 0.371b/MMBtu CDPHE VOC 0.262 CDPHE 71432 Benzene 0.007 CDPHE 110543 n -Hexane 0.022 CDPHE Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. Point 006: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Controlled Emission Factors lb/MMscf Source NOx 0.0681b/MMBtu CDPHE CO 0.37 lb/MMBtu CDPHE VOC 40,920.7 CDPHE 110543 n -Hexane 647.9 CDPHE Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. Point 007: CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Controlled Emission Factors lb/MMscf Source NOx 0.068 lb/MMBtu CDPHE CO 0.37 lb/MMBtu CDPHE COLORADO Air Pollution Control Division or Fab li₹ Hec;th u E-:rir-err 2nt Page 9 of 11 CAS # Pollutant Uncontrolled Emission Factors lb/MMscf Controlled Emission Factors lb/MMscf Source VOC 16,773.2 Source 71432 Benzene 38.2 Source 108883 Toluene 39.3 Source 100414 Ethylbenzene 14.2 Source 1330207 Xylene 23.1 Source 110543 n -Hexane 279.6 Source Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) This source is subject to 40 CFR, Part 60, Subpart OOOOa - Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification, or Reconstruction Commenced after September 18, 2015 (See June 3, 2016 Federal Register posting - effective August 2, 2016.) This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available at the Office of the Federal Register website at: https://www.federalregister.gov/documents/2016/06/03/2016-11971 /oil -and -natural -gas - sector -emission -standards -for -new- reconstructed -and -modified-sources 9) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC PSD or NANSR Synthetic Minor/Major Source of: VOC MACT HH Area Source Requirements: Applicable 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories !COLORADO Air Pollution Control Division ',`arpartfnEnt Pubti,7, kfehhil. J EtTwir nent Page 10 of 11 MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ- Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX COLORADO Air Pollution Control Division ➢ " r.^.t P b 63ct xn CnvIr-nniet,,t Page 11 of 11 Permit Number: Facility Equipment ID: CNDTK-1 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 01— Administrative Information Section 02 — Requested Action (Check applicableequ i Bonanza LLC NAICS, or nza Creek Energy Operating Company 1311 ® Company Name: Request for NEW INDIVIDUAL permit ; O Request for coverage under GENERAL PERMIt •" Source Name: Coyote E-36 Production Facility (COGCC # SIC Code: ❑ GP01 O GP08 439377) Source Location: SW/SW Sec. 36, T8N, R63W County: Weld O Request MODIFICATION to existing INDIVIDUAL permit (check boxes be(,ow)4 Elevation: 4,836 Feet O Change process or equipment O Change company name Mailing Address: 410 17th Street, Suite 1400 ZIP Code: 80202 O Change permit limit O Transfer of ownership O Other Denver, CO O APEN Submittal for Permit Exempt/Grandfathered source Person To Contact: Jerry Dismukes Phone Number: 303-803-1724 O APEN Submittal for update only (Please note blank APEN's will not be accepted) E-mail Address: jdismukes@bonanzacrk.com Fax Number: 720-279-2331 Section 03 — General Information For existing sources, operation began on: This Storage Tank is • Exploration & Production Midstream or Downstream Located at: (E&P) Site ❑ (Non-E&P) Site Will this equipment be operated in any NAAQS nonattainment area? ® Yes ❑ No Is actual annual average hydrocarbon liquid throughput > 500 bbl/day? O Yes ► Are these condensate tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. ► Are you requesting > 6 ton/yr VOC emissions, or are uncontrolled actual emissions > 6 ton/yr? General description of equipment purpose: Storage of Condensate until transferred and hauled away by tanker truck. Section 04 — Storage Tank(s) Information Requested Permit Limit: 35,040 bbl/year Actual: 29,200 bbl/year Average API Gravity of Sales Oil: 36.90 degrees Tank Design: Fixed Roof: Addl. Info. The oil produced on site fluctuates above and below an API gravity of 40. The tanks & Notes: are therefore permitted as condensate tanks to be conservative / / For new or reconstructed sources, the projected startup date is: Condensate Throughput: AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Storage Tank(s)1 i' WE U 12.2 [Leave blank unless APCD has already assigned a permit # & AIRS ID] Emission Source AIRS ID: 123 9D4D / 005 Internal Floating Roof: hours/ Normal Hours of Source Operation: 24 day Are Flash Emissions anticipated at these tanks No If "yes", identify the stock tank gas -to -oil ratio: Actual While Controls Operational: 29,200 bbl/year RVP of Sales Oil 9.4 ❑ External Floating Roof: O 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) CNDTK-1 3 - 500bb1 1,500 12/2014 2/2015 Wells Serviced by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 -123 - 40394 State Coyote 14-11-3611NB CI - - ■ - - ■ - - II FORM APC1)-2O5 33010 Page 1 of 3 2 / 8 / 2014 7 days/ 52 weeks/ week year ® Yes ❑ No 1233 Scf/bbl Yes ® No Yes ❑ No Colorado Department of Public Health and Environment Air Pollution Control Division (APCD)This notice is valid for five (5) years. Submit a revised APEN prior to expiration of five-year term, or when a significant change is made (increase production, new equipment, change in fuel type, etc). Mail this form along with a check for $152.90 per APEN for non- E&P, midstream and downstream sources or $152.90 for up to five (5) APENs for E&P sources and $250 for each general permit registration to: Colorado Department of Public Health & Environment APCD-SS-B1 4300 Cherry Creek Drive South =' Denver, CO 80246-1530 For guidance on how to complete this APEN form: f Air Pollution Control Division: (303)'92-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 APEN forms: http://www.colorado.gov/cdphe/oilgasAPENS Application status: http://www.colorado.gov/cdphe/permitstatus 3.a Form APCD-205-Condensate-Tanks-APEN Permit Number: AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Storage Tank(s)1 Emission Source AIRS ID: 123 / 9D4 Section 05 - Stack Information (For Midstream sites onl 'Operator`' Stack ,•' ' ;. TD No. , Stack Baser ~Elevation ' (feet) : Stack bischarge Height Above , Ground Level ' (feet) Temp. ` ` (°F{) . Flow Rate` .. (ACFM) Velocity (ft/sec) Moisture,! C(%) ECD-1 I 4,836 Section 06 —Stack (Source if no combustion) Location (Datum & either Lat/Long or UTM orizontal Datum:., (I�lAD27;'NAD83, ' WGS84).. .ff . n UTIvI . Zone . , (12 of 13) UTM Eastin or = g Longitude (meters or= degrees) ` 4orthiu or UTM g LatitudeLocation ; ..(meters or degrees) ; Methdd•of Collection for Data (e g. map :. GPS, doogleEarth) , -104.391514 40.611086 COGCC Direction of stack outlet (check one): O Vertical ❑ Vertical with obstructing raincap Exhaust Opening Shape & Size (check one): O Circular: Inner Diameter (inches) = Section 07 — Control Device Information _ ❑ Horizontal ❑ Down O Other: Length (inches) = ❑ Other (Describe): Width (inches) = ❑ Vapor Recovery Unit (VRU) used for control of the Storage Tank(s) Size: Make/Model: Requesteit VOC & HAP Control Efficiency: Annual time that VRU is bypassed (emissions vented): D Closed loop system used for control of the storage tank(s) Description: ® Combustion Device used for control of the Storage Tank(s) Type: Enclosed Flare Rating: Make/Model Leed L30-0011, 36" ECD VOC & HAP Control Efficiency: Requested: 95 % Manufacturer Guaranteed: 99 Minimum temp. to achieve requested control: °F Waste gas heat content: 2,639 Btu/scf Constant pilot light? ® Yes ❑ No Pilot burner rating: MMBtu/hr MMBtu/hr O Describe Any Other: Section 08 — 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)? 25-50 psig Please describe the separation process between the well and the storage tanks: See Attached Process Flow Diagram. Section 09 — Emissions Inventory Information & Emission Control Information ® Emission Factor Documentation attached Data year for actual calendar yr. emissions below & throughput in Sec. 04 (e.g. 2007): II 2015 Pollutant Emission Factor Actual Calendar Year Emission . Requested Permitted Emissions , Emission Factor Data Source Uncontrolled Basis , - Units Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) ' Controlled (Tons/Year) NOx 0.068 lb/MMBtu 0.05 0.05 AP42 Tbl 13.5-1 VOC 1.59 lb/bbl 23.26 1.16 27.91 1.40 Promax Model CO 0.37 lb/MMBtu 0.25 0.28 AP42 Tbl 13.5-1 Benzene 0.010 lb/bbl 0.139 0.007 0.167 0.008 Promax Model Toluene 0.008 lb/bbl 0.118 0.006 0.142 0.007 Promax Model Ethylbenzene 0.001 lb/bbl 0.018 0.001 0.021 0.001 Promax Model Xylenes 0.002 lb/bbl 0.034 0.002 0.041 0.002 Promax Model n -Hexane 0.062 lb/bbl 0.898 0.045 1.078 0.054 Promax Model 2,2,4-Trimethylpentane 0.007 lb/bbl 0.105 0.005 0.126 0.006 Promax Model Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Section 10 -Applicant Certification - I hereby certify that all ormat'on contained herein and information submitted with this application is complete, true and correct. � O/.3 Peg Young ��4>a Regulatory Manager "iifoZ / Environmental Re ulator Sig tore f erson Leg ' y Authoriz to ° Supply Data ate Name of Legally Authorized Person (Please print) O, '" Title You 11 be charged additional APEN fee if the APEN is filled out incorrectly or is missing information and needs to be resubmitted. is 2 Annual emissions fees will be based on actual emissions reported here. If left blank, annual emissions fees will be based on requested emissions` Additional Information Required: Attach a pressurized pre -flash condensate extended liquids analysis, RVP & API analysis of the post -flash oil Attach E&P Tanks input & emission estimate documentation (or equivalent simulation report/test results) ® I Check box to request copy of draft permit prior to issuance. FORM APC1)-2(15 Page 2 of 3 3.a Form APCD-205-Condensate-Tanks-APEN AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Produced Water Storage Tank(s)1 Permit Number: W E CJ 22 - Facility Equipment ID: PW Section 01— Administrative Information Bonanza Creek Energy Operating Company LLC Company Name: Source Name: Source Location: Mailing Address: Person To Contact: Coyote E-36 Production Facility (COGCC # 439377) [Leave blank unless APCD has already assigned a permit it & AIRS ID] Emission Source AIRS ID: 123 / 9D4D / 0V [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 02 — Requested Action (Check applicable retjlest boxes) ® Request for NEW INDIVIDUAL permit ��,�" O Request for coverage under GENERAL PERMIT NAICS, or 1311 SIC Code: SW/SW, Sec. 36, T8N, R63W County: Weld 410 17th Street, Suite 1400 Denver, CO Elevation: 4,836 Feet ZIP Code: 80202 Jerry Dismukes Phone Number: 303-803-1724 E-mail Address: jdismukes@bonanzacrk.com Fax Number: 720-279-2331 ❑ GP05 ❑ :GPO O Request MODIFICATION to existing INDIVIDl permit (check boxes below)" ❑ Change process or equipment ❑ Change permit limit Change company name Transfer of ownershipo,,, ❑ Otlty er ❑ APEN Submittal for Permit Exempt/Grandfathered source ❑ APEN Submittal for update only (Please note blank APEN's will not be accepted) Addl. Info. & Notes: Section 03 — General Information For existing sources, operation began on: / / For new or reconstructed sources, the projected startup date is: This Storage Tank is Exploration & Production ❑ Midstream or Downstream Located at: (E&P) Site (Non-E&P) Site Will this equipment be operated in any NAAQS nonattainment area? ® Yes ❑ No ► Are these produced water tanks located at a commercial facility that accepts oil production wastewater for processing? ► Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? ► Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. ► Are you requesting ≥ 6 ton/yr VOC emissions, or are uncontrolled actual emissions ? 6 ton/yr? General description of equipment purpose: Storage of Produced Water untill transferred and hauled away by tanker truck. Section 04 — Storage Tank(s) Information Requested Permit Limit: 100,740 bbl/year Actual: 100,740 bbl/year Actual While Controls Operational: 100,740 bbl/year Produced Water Throughput: Tank Design: Normal Hours of Source Operation: 24 hours/ day Are Flash Emissions anticipated at these tanks Fixed Roof: Internal Floating Roof: ❑ External Floating Roof: Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of most recent storage vessel in storage tank (Month/Year) Date Of First Production (Month/Year) PW-1 1-500bbl 500 12/2014 2/2015 Wells Serviced by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 -123 - 40394 State Coyoted 14-11-361INB i - - ■ - - ■ • 2 / 8 / 2015 7 days/ 52 weeks/ week year Yes ❑ No Yes ® No Yes ® No Yes ® No Yes ❑ No Colorado Department of Public Health and Environment Air Pollution Control Division (APCD)This notice is valid for five (5) years. Submit a revised APEN prior to expiration of five-year term, or when a significant change is made (increase production, new equipment, change in fuel type, etc). Mail this form along with a check for $152.90 per APEN for non- E&P, midstream and downstream sources or $152.90 for up to five (5) APENs for E&P sources and $250 for each general permit registration to: Colorado Department of Public HeaJfl & E+ pyironment APCD-SS-B1 4300 Cherry Creek Drive South 'Q �' Denver, CO 80246-1530 t'704..\ For guidance on how to complete this APEN form: Air Pollution Control Division: (303) 692-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 APEN forms: http://www.colorado.gov/cdphe/oilgasAPENS Application status: http://www.colorado.gov/cdphe/permitstatus FORM APCD-207 330103 Page 1 of 3 3.bForm APCD-207-ProducedWaterTank-APEN AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Produced Water Storage Tank(s)' Emission Source AIRS ID: 123 / D 4 Permit Number: Section 05 — Stack Information (For Midstream sites onl OperatorStack Stack IDNk. ' Base Elevation (feet) Stack: Discharge Height Above ; Ground Level (feet)" Temp. (°F) Flow Rate (ACFM)? ` Velocity ; (ft/sec) Moisture' (%) ECD-1 4,836 Direction of stack outlet (check one): O Vertical ❑ Vertical with obstructing raincap Exhaust Opening Shape & Size (check one): ❑ Circular: Inner Diameter (inches) _ Section 07 — Control Device Information Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Horizontal Datum`,' ry' : 1.1TM • UTM Fasting or (NAD27, NAD83, Zone Longitude WGS84) (12 or, 13) (meters or degrees) M Northing or Latitude (meters or degrees Method of Collection for Location Data (e.g. map, GPS, GoogleEarth) -104.391514 40.611086 COGCC ❑ Horizontal O Down O Other: Length (inches) = ❑ Other (Describe): Width (inches) = ❑ Vapor Recovery Unit (VRU) used for control of the Storage Tank(s) Size: Make/Model: Requested VOC & HAP Control Efficiency: Annual time that VRU is bypassed (emissions vented): ❑ Closed loop system used for control of the storage tank(s) Description: ® Combustion Device used for control of the Storage Tank(s) Type: Enclosed Flare VOC & HAP Control Efficiency: Requested: Minimum temp. to achieve requested control: Constant pilot light? Z Yes O No ❑ Describe Any Other: Rating: 1 MMBtu/hr Make/Model Leed L30-0011, 36" ECD 95 % Manufacturer Guaranteed: 99 °F Waste gas heat content: Pilot burner rating: 2,639 Btu/scf MMBtu/hr Section 08 — 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)? 25-50 psig Please describe the separation process between the well and the storage tanks: See Atached process description. Section 09 — Emissions Inventory Information & Emission Control Information ❑ Emission Factor Documentation attached Data year for actual calendar yr. emissions below & throughput in Sec. 04 (e.g. 2007): Pollutant Emission Factor Actual Calendar Year Emission Requested Permitted Emissions Estimation Method or Emission Factor. Source, Uncontrolled Basis Units Uncontrolled (Tons/Year.) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled . (Tons/Year) NOx VOC 0.262 lb/bbl 13.20 0.66 CDPHE Factor CO Benzene 0.007 lb/bbl 035 0.02 CDPHE Factor Toluene Ethylbenzene Xylenes n -Hexane 0.022 lb/bbl 1.11 0.06 CDPHE Factor 2,2,4-Trimethylpentane Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Section 10 —Applicant Certification - I hereby certify that allll dip rmation contained herein and information submitted with this application is complete, true and correct. -2 S Peg Young Sign ture Person Legal utho ' to Supply Data ; Date Name of Legally Authorized Person (Phase print).; You will be charged an a ' final AP fee if the APEN is filled out incorrectly or is missing information and needs re -submittal. T' o 2 Annual emissions fees will be based on actual emissions reported here. If left blank, annual emissions fees will be based on requested emissions. 4-/- 2\ Additional Information I ❑ I Attach produced water laboratory analysis, stack test results and associated emissions calculations if you are 'El I Che boi( to request copy of draft permit prior to issuance. Environmental Regulatory Manager Title FORM APCn-207 Page 2 of 3 3.bForm APCD-207-ProducedWaterTank-APEN AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Hydrocarbon Liquid Loading' Permit Number: 11 N f E Q 12 `L Facility Equipment ID: TLO Section 01— Administrative Information Company Name: Source Name: Source Location: Please use the Fuel Dispensing Station APEN to report emissions from service stations and fleet refueling stations. [Leave blank unless APCD has already assigned a permit # & AIRS ID] Emission Source AIRS ID: 123 / 904D [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Bonanza Creek Energy Operating Company, LLC Coyote E-36 Production Facility (COGCC # 439377) SW/SW, Sec. 36, T8N, R63W Mailing Address: 410 17th Street, Suite 1400 Denver, CO Person To Contact: Jerry Dismukes E-mail Address: jdismukes@bonanzacrk.com NAICS, or SIC Code: Section 02 — Requested Action (Check applicable request boxes) l 005 IAction Applies To: ❑✓ Individual Permit ❑✓ Request NEW permit or newly reported emission sour O Request REGISTRATION for coverage under GP07 ncurrent request for CANCELLATION of individual permit. number: ' _.. General Permit GP07 E EA - 1311 ❑ Request MODIFICATION to existing permit (check each box below that applies) County: Weld ❑ Change process or equipment ❑ Change company name Elevation: 4,836 Feet ❑ Change permit limit ❑ Transfer of ownership ❑ Other ZIP Code: 80202 ❑ Request to limit HAPs with a Federally enforceable limit on PTE ❑ Request APEN update only. Note — Emissions data must be completed. Blank APENs will not be accepted Phone Number: 303-803-1724 Fax Number: 720-279-2331 Section 03 — General Information Date operation began or projected startup date: 2 / 8 / 2015 Normal Hours of Source Operation: 24 Addl. Info. & Notes: General description of equipment and purpose: Loading of condensate into tanker trucks hours/day 7 days/week 52 weeks/year ► Is this source located at an oil and gas exploration and production site? If yes, does this source load less than 10,000 gallons of crude oil per day on an annual average, splash fill less than 6750 BBL of condensate per year or submerge fill less than 16,308 BBL of condensate per year? ► Is this source located at a facility that is considered a Major Source of Hazardous Air Pollutant (HAP) emissions? ► Will this equipment be operated in any NAAQS nonattainment area? (www.colorado.gov/cdphe/ozone) ► Does this source load gasoline into transport vehicles? A If "Yes", provide an applicability determination of state and federal rules. Section 04 — Loadine Information Product Loaded: Q Condensate O Crude Oil Other: ► If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Annual Volume Loaded: Requested2: 35,040 bbl/year Actual calendar year: 29,200 bbl/year This product is loaded from tanks at this facility into: tank trucks (e.g, "rail tank cars," or "tank trucks") • If site -specific emission factor is used to calculate emissions (Not available for GP07), complete the following: Saturation Factor3: 1.0 Average Temperature of Bulk Liquid Loaded: 64 °F True Vapor Pressure: 4.59 psia @ 60 °F Molecular Weight of Displaced Vapors: 45.75 I. If this APEN is being filed for vapor losses from pressurized loading lines, complete the following: Loads per year: Requested2: #/yr. Actual Calendar Year: #/yr. Product Density: Ft3/truckload Load Line Volume4: Fe/truckload Vapor Recovery Line Volume4: t You may be charged an additional APEN fee for APEN re -submittal due to incorrectly filled -out APEN or mining information. 2 Requested values will become permit limitations for individual construction permits. 3 Please refer to AP -42, Table 5.2-1 for information on saturation factors (found online at: http://www.epa.eov/ttn/chief/ap42/ch05/index.html).`. List the total volume for all lines in each category and attach your calculations of these volumes. Lb/lb-mol FORM APCD-208 Page 1 of 2 Lb/&Y3 I] Yes Yes YesA YesA YesA ❑ No 0 Don't know ❑ No 0 Don't know El No ❑ Don't know ❑ No 0 Don't know I] No 0 Don't know Colorado Department of Public Health and Environment Air Pollution Control Division (APCD) This notice is valid for five (5) years. Submit a revised APEN prior to expiration of five-year term, or when a significant change is made (increase production, new equipment, change in fuel type, etc). Mail this form along with a check for $152.90 per APEN & $250.00 for each general permit registration to: Colorado Department of Public Health & Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Air Pollution Control Division: Small Business Assistance Program (SBAP): (303) 692-3150 (303) 692-3148 or (303) 692-3175 APEN forms: www.colorado.gov/cdphe/airforms Permit status: www.colorado.gov/cdphe/permitstatus FormAPCD-208-HydrocarbonLiquidLoadingAPEN-Ver.4-14-2014 (1).docx Permit Number: Section 05 — Stack Information (Combustion stacks must be listed here) Operator Stack ID No. Stack Base Elevation (feet) Stack Discharge Height Above Ground Level' (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) . Moisture (%) 4,836 Direction of stack outlet (check one): n Vertical ❑ Vertical with obstructing rainca Exhaust Opening Shape & Size (check one): n Circular: Inner Diameter (inches) = Section 07 — Control Device Information AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Hydrocarbon Liquid Loading' Please use the Fuel Dispensing Station APEN to report emissions from service stations and fleet refueling stations. Emission Source AIRS ID: 123 / 9D4D / Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Horizontal Datum (NAD27, NAD83, ; WGS84) UTM Zone', (12 or 13)' UTM Easting or Longitude (meters or degrees) UTM Northing or Latitude. (meters or degrees) Method of Collection for Location Data (e.g. map, GPSGoogleEarth) -104.391514 40.611086 COGCC Horizontal ❑ Down O Other: Length (inches) = Other (Describe): Width (inches) = GI Loading occurs using a vapor balance system. GI Combustion Device used for control of the loadout emissions. 95 #: % °F Rating: MMBtu/hr N Describe Any Other (Including VRU) Type: Enclosed Flare Make/Model/Serial Leed L30-001, 36" ECD VOC & HAP Control Efficiency: Requested: Minimum temp. to achieve requested control: Manufacturer Guaranteed: - Waste gas heat content: 2,648 99 % VOC & HAP Control Bffieieney; Requested' % Btu/scf Constant pilot light? ✓ Yes • No Pilot burner rating: MMBtu/hr Section 08 — Emissions Inventory Information ❑ State Emission Factors (Required for general permit GP07 - Optional for individual permit) ❑ Condensate VOC: 0.236 Lbs/BBL Benzene: 0.00041 Lbs/BBL n -Hexane: 0.0036 Lbs/BBL n Crude Oil VOC: 0.104 Lbs/BBL Benzene: 0.00018 Lbs/BBL . n -Hexane: 0.0016 Lbs/BBL ❑✓ Emission Factor Documentation attached (If using site specific emission factor) Data year for actual calendar year emissions below & throughput in Sec. 04 (e.g. 2007): Pollutant Control Device Description Primary NOx VOC CO Benzene n -Hexane Secondary Control Efficiency (% Reduction) Emission Factor Actual Calendar Year Emissions Requested Permitted Emissions Estimation Method or Uncontrolled Basis 0.068 Units Ib/MMBtu Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) 0.005 Emission Factor Source AP 42 Chap 5.2 4.256 lb/1,000 gal 3.13 1.05 AP 42 Chap 5.2 0.370 Ib/MMBtu 0.030 AP 42 Chap 5.2 0.0117 lb/1,000 gal 0.009 0.003 AP 42 Chap 5.2 0.1302 lb/1,000 gal 0.096 0.003 AP 42 Chap 5.2 Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. You may be charged an additional APEN fee for APEN re -submittal due to incorrectly filled -out APEN or missing information. 5Annual emission fees will be based on actual emissions reported here. nCheck box to request copy of draft permit prior to issuance. lic#t, Section 09 —Applicant Certification - I hereby certify that all information contained herein and information submitted with ,t,gphis-apphc�tton is complete, true and correct. If this is a registration as for coverage under general permit GP07, I further certify that this source is and will be operated in full compliance with eaentecii i q 'general permit GP07. 4115 Peg Young d to Supply Data Environmental Regulatory Manager 'Name of Legally Authorized Person (Please print) . Title r Page 2 of 2 FormAPCD-208-HydrocarbonLiquidLoadingAPEN-Ver.4-14-2014 (1).docx AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Natural Gas Venting Permit Number: 11 Y f E (J 1 ZZ Facility Equipment ID: SEP-1 [Leave blank unless APCD has already assigned a permit # & AIRS ID] Emission Source AIRS ID: 123 / 9D4D 100(i Section 01— Administrative Information Company Name: Bonanza Creek Energy Operating Company LLC Source Name: Coyote E-36 Production Facility (COGCC #439377) Source Location: SW/SW, Sec. 36, T8N, R63W Mailing Address: 41017"' Street, Suite 1400 Denver, CO [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 02 — Requested Action (check applicable request boxes) Request for NEW permit or newly reported emission source NAICS, or SIC Code: 1311 County: Weld Elevation: 4,836 Feet ZIP Code: 80202 Person To Contact: Jerry Dismukes Phone Number: 303-803-1724 E-mail Address: jdismukes@bonanzacrk.com Fax Number: Section 03 — General Information For existing sources, operation began on: Normal Hours of Source Operation: General description of equipment and purpose: / / 720-279-2331 ❑ Request MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O Change • a any name ❑ Change permit limit O Trans O Request to limit HAPs with a Federally enforceab ❑ Request APEN update only (check the box below that app ❑ Revision to actual calendar year emissions for emission inventq~ry Update 5 -Year APEN term without change to permit limits or previously reported emissions Additional Info. & Notes: ❑ Other For new or reconstructed sources, the projected startup date is: 2 / 8 / 2015 24 hours/day 7 days/week 52 weeks/year One (1) low pressure gas/oil separator Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.gov/cdphe/attainment) Section 04 — Processing Equipment Information Description of Source': ❑ Well Head Casing • Gas/liquid Separator ❑ Pneumatic Pump:. ❑ Compressor Rod Packing ❑ Blowdowns: Other: Description: Make: Make: # of events: Model: Model: Volume: Yes Serial #: # of pistons: MMscf/event No Capacity: Leak rate: Don't know gal./min. Scf/hr/pist. Maximum Vent Rate (scf/hr) Actual Volume (MMscf/yr) Requested Volume z (MMscf/yr) Vent Gas Heating Value (Btu/scf) Process Parameters: 210 2.2 1,705 Molecular Wt VOC (wt %). Benzene -. (wt %)` ° Toulene: I (wt %) Ethylbenzene ' ,(wt4%),,*' Xylene (wt °%) n Hexane - m(wi %) x:"...,: Vented Gas Properties: 30.8 50.32 0.11 0.11 0.04 0.06 0.80 E Submit a representative gas analysis (including BTEX & n -Hexane) to support calculations 'Only one source type may be reported per APEN. 'Requested values will become permit limitations. Requested level shall be a "not to exceed value". FORM APCD-211 330105 Page 1 of 2 Colorado Department of Public Health and Environment Air Pollution Control Division (APCD) This notice is valid for five -(5) years. Submit a revised APEN prior to expiration of five-year term, or when a significant change is made (increase production, new equipment, change in fuel type, etc). Mail this form along with a check for $152.90 to: Colorado Department of Public Health & Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Air Pollution Control Division: (303) 692-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 APEN forms:http://www.colorado.gov/cdphe/oilgaspermits Application status:http://www.colorado.gov/cdphe/permitstatus ® Check box to request copy of draft permit prior to issuance. ® Check box to request copy of draft permit prior to public notice. 3.d Form APCD-211 Natural Gas Venting APEN_Low Pressure Separator AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Natural Gas Venting Permit Number: Emission Source AIRS ID: 123 / 9D4D / Section 05 — Stack Information (Combustion stacks must be listed here) Operator Stack - ID No. ' Stack Base Elevation " (feet) Stack Discharge, Height Above ` Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/see) Moisture (%) ECD-1 4,836 1,273 Direction of stack outlet (check one): ® Vertical ❑ Vertical with obstructing raincap Exhaust Opening Shape & Size (check one): ® Circular: Inner Diameter (inches) = Section 07 — Control Device Information Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Horizontal Datum (NAD27, NAD83, WGS84) UTM Zone (12 or 13) UTM Easting or Longitude (meters or degrees) ; UTM Northing or r Latitude (meters or degrees) I of Collection , IAmation Data (e.g map GPS, GoogleEarth) -104.391514 40.611086 COGCC ❑ Horizontal 0 Down ❑ Other: Length (inches) = 0 Other (Describe): Width (inches) = • VRU used for control of: ►4 Combustion Device used for control of: Low Pressure Gas Rating: 1 MMBtu/hr Size: Make/Model: Leed L30-0011, 36" Type: Enclosed Flare Make/Model/Serial #: ECD Requested VOC & HAP Control Efficiency: % VOC & HAP Control Efficiency: Requested: 95 % Manufacturer Guaranteed: 98 % Annual time that VRU is bypassed (emissions vented): % Minimum temp. to achieve requested control: °F Waste gas heat content: 1,705 Btu/scf The VRU recycles venting omissions to: Constant pilot light? 14 Yes • No Pilot bunter rating: MMBtu/hr • Describe Any Other: Section 08 — Emissions Inventory Information & Emission Control Information Attach any emission calculations and emission factor documentation to this APEN form. Emission Factor Documentation attached Data year for actual calendar yr. emissions below & throughput above (e.g. 2007): Pollutant Control Device Description Overall Collection Efficiency Control Efficiency (% Reduction) Emission Factor Actual Calendar Year 3 Emissions3 Requested Permitted Emissions 4 Estimation Method or Emission Factor Source Primary Secondary UncBoasislled Units Uncontrolled (Tons/Year) Controlled Tons/Year) U( ) (Tons/Year) ( Controlled Toni/Year) VOC Enclosed Flare 100 95 40,920.7 Ib/MMscf 45.06 2.25 Mass Balance NOx 0.068 lb/MMbtu 0.13 AP42 Tb 13.5-1 CO 0.37 lb/MMbtu 0.69 AP42 Tb 13.5-1 SOx 1.39e-3 lb/MMbtu 0.003 AP42 Tb 13.5-1 Benzene Enclosed Flare 100 95 89.8 Ib/MMscf 0.099 0.005 Mass Balance Toulene Enclosed Flare 100 95 86.6 lb/MMscf 0.095 0.005 Mass Balance Ethylbenzene Enclosed Flare 100 95 29.3 lb/MMscf 0.032 0.002 Mass Balance Xylene Enclosed Flare 100 95 48.5 lb/MMscf 0.053 0.003 Mass Balance n -Hexane Enclosed Flare 100 95 647.9 lb/MMscf 0.713 0.036 Mass Balance Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. ' Annual emission fees will be based on actual emissions reported here. If left blank, annual emission fees will be based on requested emissions. 4If Requested Permitted Emissions is left blank, the APCD will calculate emissions based on the information supplied in sections 03 - 07. Sectio 9 —Applicant Certification - I hereb ertify that all ' f atio contained herein and information submitted with this application is complete, true and correct. 241/ Peg Young ,,r,,Y.i l<<2, Environmental Regulatory Manager Sign ture of ' erson egall uthorized o Supply Data ate Name of Legally Authorized Person (Plea`s pftAt)t Title FORM APCD-211 Page 2 of 2 3.d Form APCD-211 Natural Gas Venting APEN_Low Pressure Separator AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Natural Gas Venting Permit Number: I I WE °III Facility Equipment ID: FL -1 Section 01— Administrative Information [Leave blank unless APCD has already assigned a permit # & AIRS ID] Emission Source AIRS ID: 123 / 9D4D [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Section 02 — Requested Action (check applicable request boxes) Company Name: Bonanza Creek Energy Operating Company LLC Source Name: Coyote E-36 Production Facility (COGCC #439377) Source Location: SW/SW, Sec. 36, T8N, R63W Mailing Address: 410 17th Street, Suite 1400 Denver, CO Person To Contact: Jerry Dismukes E-mail Address: Jdismukes@bonanzacrk.com Section 03 — General Information For existing sources, operation began on: Normal Hours of Source Operation: General description of equipment and purpose: NAICS, or SIC Code: 1311 County: Weld Elevation: 4,836 Feet ZIP Code: 80202 Phone Number: 720-440-6133 Fax Number: 720-279-2331 / 001 ® Request for NEW permit or newly reported emission source ❑ Request MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment CI ❑ Change permit limit ❑ Change company name Transfer , wnership ❑ Request to limit HAPs with a Federally enforcea ❑ Request APEN update only (check the box below ❑ Revision to actual calendar year emissions for emissi. n Update 5 -Year APEN term without change to permit limits or prevy reported emissions Process Flares to combust produced gas from high pressure separator ❑ Other Additional Info. & Notes: For new or reconstructed sources, the projected startup date is: 2 / 8 / 2015 24 hours/day 7 days/week 52 weeks/year Two (2) enclosed flares used to combust associated gas vented from the high-pressure separator. Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.gov/cdphe/attainment) Section 04 — Processing Equipment Information Description of Source': ❑ Well Head Casing ® Gas/liquid Separator ❑ Pneumatic Pump: Make: Model: Serial #: El Compressor Rod Packing Make: Model: # of pistons: ❑ Blowdowns: # of events: 111 Other: Description: Don't ® Yes CI No ❑ know Volume: MMscf/event Capacity: Leak rate: gal./min. Scf/hr/pist. Maximum Vent Rate (scf/hr) Actual Volume (MMscf/yr) Requested Volume2 (MMscf/yr) Vent Gas Heating Value (Btu/scf) Process Parameters: 18,125 71.2 1,299 Molecular Wt. Vented Gas Properties: 23.0 VOC (wt °/0) Benzene (wt %) Toulene (wt %) Ethylbenzene (wt %) Xylene (wt%) n -Hexane (wt 27.69 0.06 0.06 0.02 0.04 0.46 Colorado Department of Public Health and Environment Air Pollution Control Division (APCD) This notice is valid for five (5) years. Submit a revised APEN prior to expiration of five-year term, or when a significant change is made (increase production, new equipment, change in fuel type, etc). Mail this form along with a check for $152.90 to: Colorado Department of Public Health & Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 For guidance on how to complete this APEN form: Air Pollution Control Division: (303) 692-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 APEN forms:http://www.colorado.gov/cdphe/oilgaspermits Application status:http://www.colorado.gov/cdphe/permitstatus ® Submit a representative gas analysis (including BTEX & n -Hexane) to support calculations 'Only one source type may be reported per APEN. 'Requested values will become permit limitations. Requested level shall be a "not to exceed value". FORM APCD-211 Page 1 of 2 QN/1 so 2t?15 ® Check box to request copy of draft permit prior to issuance. ® Check box to request copy of draft permit prior to public notice. 3.e Form APCD-21 I Natural Gas Venting APEN_Temporary Flare AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Natural Gas Venting Permit Number: Emission Source AIRS ID: 123 / 9D4D / Section 05 — Stack Information (Combustion stacks must be listed here) Operator Stack ID No. Stack Base Elevation (feet) Stack Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) Moisture (%) FL -1 1,273 Direction of stack outlet (check one): Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Horizontal Datum (NAD27, NAD83, WGS84) UTM Zone (12 or 13) UTM Easting or Longitude (meters or degrees) UTM Northing or Latitude (meters or degrees) Method of Collection for Location Data (e.g. map, GPS, GoogleEarth) -104.391514 40.611086 COGCC ® Vertical ❑ Vertical with obstructing raincap Exhaust Opening Shape & Size (check one): ® Circular: Inner Diameter (inches) = Section 07 — Control Device Information ❑ Horizontal ❑ Down ❑ Other: Length (inches) = ❑ Other (Describe): Width (inches) = ■ VRU used for control of: /1 Combustion Device used for control of: Produced Gas Rating: 10 MMBtu/hr Size: Make/Model: Type: Enclosed Flare Make/Model/Serial #: two (2) MRW enclosed flares Requested VOC & HAP Control Efficiency: % % VOC & HAP Control Efficiency: Requested: 95 % Manufacturer Guaranteed: Waste gas heat content: 1,299 98 Annual time that VRU is bypassed (emissions vented): The VRU recycles venting emissions to: Minimum temp. to achieve requested control: °F Btu/scf Constant pilot light? /L1 Yes ■ No Pilot burner rating: MMBtu/hr • Describe Any Other: Section 08 — Emissions Inventory Information & Emission Control Information Attach any emission calculations and emission factor documentation to this APEN form. ❑ Emission Factor Documentation attached Data year for actual calendar vr. emissions below & throunhaut above (e.e. 20071: Pollutant Control Device Description p Overall Collection Efficiency Control Efficiency (% Reduction) Emission Factor Actual Calendar Year Emissions 3 4 Requested Permitted Emissions Estimation Method or Emission Factor Source Primary Secondary Uncontrolled Basis Units Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) VOC Enclosed Flare 100 95 16,773.2 lb/MMscf 596.9 29.85 Mass Balance NOx 0.068 lb/MMbtu 3.14 AP42 Tb 13.5-1 CO 0.37 lb/MMbtu 17.10 AP42 Tb 13.5-1 SOx 1.04e-3 lb/MMbtu 0.05 AP42 Tb 13.5-1 Benzene Enclosed Flare 100 95 38.2 lb/MMscf 1.36 0.07 Mass Balance Toulene Enclosed Flare 100 95 39.3 lb/MMscf 1.40 0.07 Mass Balance Ethylbenzene Enclosed Flare 100 95 14.2 lb/MMscf 0.50 0.023 Mass Balance Xylene Enclosed Flare 100 95 23.1 lb/MMscf 0.82 0.04 Mass Balance n -Hexane Enclosed Flare 100 95 279.6 lb/MMscf 9.95 0.50 Mass Balance Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Annual emission fees will be based on actual emissions reported here. If left blank, annual emission fees will be based on requested emissions. 4If Requested Permitted Emissions is left blank, the APCD will calculate emissions based on the information supplied in sections 03 - 07. Sectio —Applicant Certification - I hereby certify that all info ation c ntained herein and information submitted with this application is complete, true and correct. / �j C ►� Peg Young Environmental Regulatory Manager Si a e o rson Legally /thorized to : upply Data to Name of Legally Authorized Pers(Please`print) Title 10/� FORM APCD-211 Page 2 of 2 3.e Form APCD-211 Natural Gas Venting APEN Temporary Flare Hello