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Home My WebLink About20173747.tiffCOLORADO Department of Public Health kr Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 11500 St PO Box 758 Greeley, CO 80632 October 25, 2017 Dear Sir or Madam: On October 26, 2017, the Air Pollution Control Division will begin a 30 -day public notice period for Bonanza Creek Energy Operating Company, LLC - Antelope CPF 13-21 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 Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, / Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303.642.7000 www.colorado.gov/cdphe f—� John W. Hickenlooper, Gaverr,or i Larry Wotk, MD, MSPH. Executive Director and Chief Medical Officer P..1yVli'c / colt 7 c.c.= PLCCrinn TP), IALCJT), C E-s-f>`f-t(aoo ![E ) tc.r3O(I"] 2017-3747 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Bonanza Creek Energy Operating Company, LLC - Antelope CPF 13-21 Production Facility - Weld County Notice Period Begins: October 26, 2017 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Bonanza Creek Energy Operating Company, LLC Facility: Antelope CPF 13-21 Production Facility Oil and gas production facility NESW SEC 21 TSN R62W Weld County The proposed project or activity is as follows: New points for VRU downtime; condensate tanks; water tanks; truck loadout; slop tank 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 15WE1001 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 1 Division Information Engineer: Timothy Sharp Control Engineer: Stefanie Rucker Review Date: 03/25/2016 Application Date: 11/16/2015 Facility Identifiers Permit No. 15WE1001 AIRs County # 123 !Weld Facility # 9DF2 Facility Type: exploration and production facility O Located 1n the 8 -hour non -attainment area? Administralnformation Potentially located in ozone nonattainment area 1 True Minor Q Synthetic Minor for l VOC I'" NOx r co Company Name: Bonanza Creek Energy Operating Company, LLC Source Name: Antelope CPF 13-21 Production Facility Source Location: SIC: NESW SEC 21 T5N R62W 1311 Mailing Address Address 1: Address 2: ty, State Zip: Bonanza Creek Energy Operating Company, LLC 410 17th Street, Suite 1400 Denver CO, 80202 Person To Contact Name: Phone: Fax: Email: Jerry Dismukes 000-000-0000 000-000-0000 idisrnukes@bcnanzacrk.com Requested Action Self Certification Required? Issuance Number: Yes 2 Source Description: Oil and gas exploration and production facility known as the Antelope CPF 13-21 Production Facility, located in the NESW SEC 21 T5N R62W, Weld County, Colorado. Point Name Type Control ' Action 007 LPGFL Separator Venting Flare Newly reported source 008 TLO Loadout Flare Newly reported source 009 TWT-01 Water Tanks Flare Newly reported source 010 SLOP -01 Condensate Tanks Flare Newly reported source 011 CNDTK-01 Condensate Tanks _ Flare Newly reported source One low-pressure separator controlled by one enclosed flare during VRU downtime. Flare has a minimum control 007 efficiency of 95% Equipment Description This source vents natural gas from. Emissions from this source are: a well head separator routed to a flare Natural gas Venting from a Weil head separator, Emis310nS from this source are routed to a flare. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10 - Displacement Equation (10 4-3) Ex=Q*MW*Xx/C Ex = emissions of pollutant x Q = Volumetric flow rate/volume of gas processed MW = Molecular weight of gas = SG of gas* MW of air Xx ; mass fraction of x in gas C = molar volume of ideal gas (379 sof/lb-mot) at 60E and 1 atm Maximum Vent Rate Throughputica MW 1790 scfltir 12.18 .MMscf/yr 40.3 b/lb-mat 1390.4109591 0.0333898831 sof/Fir MMscffd mole 46 MW Ibx/Ibmol mass fraction Ib/hr lb/yr tov Helium 000 4.0026 0.000 0000 0130 0.00 0.000 CO2 2,21 0 80 44.01 28.013 _ 0 971 0.223 _ 0 024._ _ 3 56 0 82 31190 84 15.60 N2 0 006, 7157.06 3 58 methane 68.14 16.041 10.930 0,271 40 10 351245 73 175.62 ethane 13.54 30,063• 4.071 0 101 14 94 130844 44 65 42 propane 8 99 44,092 3.965 0 0981 1455 127420 31 63 71 isobutane 0 98 58.118 0_572 0 014 2,10 18389.87 9 19 n -butane 3 04 58.118; 1 76B 0 044 6 49. 56818,82 28,41 isooentane 0 59 72.114 0 425 0.011 1.56 13673.50. 6.84 n-oentane 0.78 72.114 0 563 0 014 2.06 18079.15 9 04 cyclopentane 0 08 70 13 0 057 0 001 0.21 1841.34 0.92 n -Hexane 0 20 86.18 0.173 0.004 0.62. 5544,71 2,77 cycllhexane 0 08 84,16 0.070 0.002 0 26 2244.87 1.12 Otherhexanes 025 86.18 0,218 0005 0.80,, 7015.36 351 heptanes 0 05 100.21 0.053 0 001 0 20 1713.29 0.86 mwth_ytcyclohaYane 0 05 98,19 0 047 0.001 0 17 1511.51 0.76 224-TMP 0 02 114.23 0.021 0_001 0.08; 690.15 0.35 Benzene 0 03 78.12 0.023 0 001 3 08; 728 06 0 36 Toluene 0 03 92,15 0 024 0.001 0 09 784.78 0.39 Elhylbenzene 0 01 106.17 0.008 0.000 0.03 245 86 0.12 Xylenes 0.01 106,17 0.015. 0.000 Q 05 467 44 0.23 C6+ Hesaie8 0 03 56503.61016 16.104 0.400 59.08 517522.38 256,76 V(70 mass frac 0 598 Notes Mole %, MW, and mass fractions from Critter Creek 2-03H gas analysis collected XX/XX/XX Emissions are based on 8760 hours of operation per year I calculated the average MW of C8+ based on the average MW on the analysis for the gas Total VC C luncontrolled) plus 20% 387 355 464,81 15WE1001.CP2.xlsm One low-pressure separator controlled by one enclosed flare during VRU downtime. Flare has a minimum control 007 efficiency of 95%. Flaring Information Equipment Description Flare to combust low-pressure aol s wnr as during VRU downtime Manufacturer Tornado Model 40' Flare Stack Serial Number 12345678 Gas Heating Value 1549 Biu/scf Throughput 18806 82 MMBtulyr meter installed: Modeled liquid thorughput to separator: SCF vented gas/BBL liquid throughput: VRU Information Equipment Description Eoigine to recompress gae to sales line Make TBD Model TBD Requested Control 100.00 °/ Annual Bypass Tim 50 00% Backup Flare Overall Control 95 00% No 1,000 bbl/yr 121764 scf/bbl Combustion emission factor source: AP -42: Chapter 13.5 0.07 Ilb NOX/MMBtu Emissions Summary Table 0 37 Ifb COfMMBtu Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 76324 lb/MMscf 3816.21 lb/MMscf 4648 tpy 23.2 tpy Gas Analysis Nox 0.07 Ib/MMBTU 0.07 lb/MMBTU 0.6 tpy 0.6 tpy AP -42 CO 037 lb/MMBTU 0.37 lb/MMBTU 3.5 tpy 3.5 tpy AP -42 Benzene 396.77 lb/MMscf 19.84 lb/MMscf 4833 lb/yr 242 lb/yr Gas Analysis n -Hexane 2617.63 lb/MMscf 130.8815 lb/MMscf 31883 lb/yr 1594 lb/yr Gas Analysis Toluene 352.160 lb/MMscf 17.6080 lb/MMscf 4289 lb/yr 214 lb/yr Gas Analysis Xylenes 159 410 lb/MMscf 7.9705 lb/MMscf 1942 lb/yr 97 lb/yr Gas Analysis Ethvlbenzene 51.510 lb/MMscf 2.5755 lb/MMscf 627 lb/yr 31 !b/yr Gas Analysis Regulatory Applicability AOCC Renulation I This scums is subject to the opacity requirements for flares in Section II.A.5:'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity' ACC Regulation 2 Section I.A applies to ail emission sources. "No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air." AOCC Rsoulation 7 Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014? No This separator is not subject to Reg 7 Section XVII,G 15WE1001.CP2.xlsm 008 Hydrocarbon Loadout to Tanker Trucks Calculations L = 12.46*S*P*M/T (AP -42: Chapter 5.2, Equation 1) L = loading losses in lb per 1000 gallons loaded The table of inputs below enables you to calculate the loading loss emissions factor "L". If you choose to use a state default emissions factor, you may enter is directly into cell 814 in units lb/1,000 gallons which will overwrite Factor Meaning Value Units Source S Saturation Factor 1 AP -42 P True Vapor Pressure 2.61 psia Sales Oil A M Molecular Weight of Vap 33.45 lb/lb-mole AP -42 T Liquid Temperature 524 deg. R Field Data L 2.08 lb/10^3 gal 8.72E-02 lb/bbl Annual requested Throughput Annual requested VOC emissions Control: Flare Efficiency: 95.00% Collection Ef198.70% NCRPs Component Benzene 0.0032 n -hexane 0.0463 Toluene 0.0026 Xylenes 0.0007 Source: Mass Fraction Oil Analysis Emissions Summa Table 1972497 BBL/yr 82844874 gal/yr 171984 lb/yr 85.99 tpy alysis If the operator provides HAP speciation from a stable "sales oil" analysis, enter the mass fraction from this data. Alternatively, if the operator modeled a pressurized oil to develop a site specific emissions factor, enter the modeled mass fraction for the Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 8.72E-02 lb/bbl 86.0 tpy 5.4 tpy AP -42 Benzene 2.80E-04Ib/bbl 552.2 lb/yr 27.6 lb/yr AP -42 n -Hexane 4.03E-03 lb/bbl 7955 lb/yr 398 lb/yr AP -42 Toluene 2.28E-04 lb/bbl 450 lb/yr 23 lb/yr AP -42 Xylenes 6.12E-05 lb/bbl 121 lb/yr 6 lb/yr AP -42 Regulatory Review Regulation 3 - APEN and Permitting Requirements Is this site considered an exploration and production location (e.g. well pad)? If yes, review the following two exemptions for applicability: Does the operator unload less than 10,000 gallons 1238 BBLs) per day of crude oil on an annual average basis? If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section II D 1.1 Does this operator unload less than 6,750 bbls per year of condensate via splash fill or 16,308 bbls per year of condensate via submerged fill procedure? Yes/No if yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B, Section II D 'I I Yes/No Yes/No 009 Three (3) above ground 500 bbl produced water storage tank Emissions Calculations [Requsted Throughput 1265820 Control Flare Efficiency 95.00% Emissions Summary Table bbl Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.013 Ib/bbl 8.22783 tpy 0.411392 tpy CDPHE Benzene 0.0003Ib/bbl 379.746 lb/yr 18.9873 lb/yr CDPHE n -Hexane 0.0001 lb/bbl 126.582 lb/yr 6.3291 lb/yr CDPHE Regulatory Review Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section I1.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (only needed if using flare) Peculation 2 -- Odor Section I.A - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. 010 One (1) above ground 500 bbl atmospheric condensate storage tank Requsted Throughput 535 bbl Control Flare Efficiency 95.00%I Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 96.9149 lb/bbl _ 25.9 tpy 1.3 tpy E&P TANK Benzene 0.1244 lb/bbl 66.554 lb/yr 3,3277 lb/yr E&P TANK _ n -Hexane 0.9395 lb/bbl 502.6325 lb/yr 25.13163 lb/yr E&P TANK Regulatory Review Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (only needed if using flare) Regulation 2 — Odor Section I.A - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Requlation 6 - New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. This source is not subject because each tank is less than 19,800 gallons (471 bbl) NSPS OOOO: for storage vessels in the natural gas production, transmission, and processing segments. This source is not subject because each tank emits less than 6 tpy VOC. Regulation 7 — Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Applicant is not subject to the emission control requirements for condensate tanks since it is located in an attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS,,. (Applicant is not currently subject to this since actual uncontrolled emissions are less than 20 tpy of VOC.) 011 eighteen (18) above ground 500 bbl atmospheric condensate storage tank Requsted Throughput 1972216 bbl Control Efficiency Flare 95.00%i Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.44 lb/bbl 433.9 tpy 21.7 tpv E&P TANK Benzene 0.002 lb/bbl _ 3944.432 lb/yr 197.2216 lb/yr E&P TANK n -Hexane 0.015 lb/bbl 29583.24 lb/yr 1479.162 lb/yr E&P TANK Regulatory Review Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section Il. A and B of this regulation. Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (only needed if using flare) Reauiation 2 — Odor Section I.A - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Requlation 6 - New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. This source is not subject because each tank is less than 19,800 gallons (471 bbl) NSPS OOOO: for storage vessels in the natural gas production, transmission, and processing segments. This source is not subject because each tank emits less than 6 tpy VOC. lRequiation 7 — Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Applicant is not subject to the emission control requirements for condensate tanks since it is located in an attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is not currently subject to this since actual uncontrolled emissions are less than 20 tpy of VOC.) STATE OF COLOFADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 CONSTRUCTION PERMIT PERMIT NO: 15WE1001 Issuance 2 DATE ISSUED: ISSUED TO: Bonanza Creek Energy Operating Company LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Antelope 13-21 Central Production Facility, located in the NESW of Section 21, Township 5N, Range 62W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Point Description DEHY-1 001 One (1) Triethylene glycol (TEG), natural gas dehydration unit (make, model, serial number: TBD) with a design capacity of 12.0 MMscf per day. This emissions unit is equipped with two (2) Kimray, model 21020, gas -glycol pumps with a design capacity of 3.5 gallons per minute. Only one Kimray gas -glycol pump will be operated at any given time. The second Kimray gas -glycol pump serves as a back-up only. This unit is equipped with a flash tank, reboiler and still vent. Stripping gas is not used. Emissions from the still vent are routed to an air- cooled condenser and then to a flare with a minimum control efficiency of 95%. Emissions from the flash tank are 100% recycled to the sales gas line or to the fuel gas system. LPGFL 007 Low-pressure separators controlled by enclosed combustion device(s) during VRU downtime. ECDs have a minimum control efficiency of 95%. L-01 008 Hydrocarbon Loadout to Tanker Trucks controlled by vapor balance and enclosed combustion device(s). ECDs have a minimum control efficiency of 95%. PWT-01 009 Three (3) above ground 500 bbl produced water storage tank controlled by enclosed combustion device(s). ECDs have a minimum control efficiency of 95%. AIRS ID: 123/9DF2 Page 1 of 20 Dehy SWM Version 2012-1 Colorado Department of Public Health and Environment Air Pollution Control Division Facility Equipment ID AIRS Point Description SLOP -01 010 One (1) above ground 500 bbl atmospheric condensate storage tank controlled by enclosed combustion device(s). ECDs have a minimum control efficiency of 95%. CNDTK-01 011 Eighteen (18) above ground 500 bbl atmospheric condensate storage tank controlled by enclosed combustion device(s). ECDs have a minimum control efficiency of 95%. 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 sea), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the tatter of commencement of operation or issuance of this permit, by submitting a Notice of Startup .form to the Division. The Notice of Startup form may be downloaded online at httns://www.colorado.gov/paoific/cdphe/other-air- permitting-notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section I II.G.1 and can result in the revocation of the permit. 2, Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, I I I.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F,4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Reference: Regulation No. 3, Part B, Section III,E.) 5. The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. AIRS ID: 123/9DF2 Page 2 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division (Reference: Regulation No. 3, Part B, III.E.) 6. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Monthly Limits: Facility Equipment ID AIRS Point Pounds per Month Emission Type NOx VOC CO DEHY-1 001 -- 561 --- Point LPGFL 007 --- 3941 i 731 Point L-01 008 --- 578 --- Point Point PWT-01 009 --- 85 --- SLOP -01 010 221 --- Point CNDTK-01 011 --- 3653 578 Point (Note: Monthly limits are based on a 31 -day month.) The owner or operator shall calculate monthly emissions based on the calendar month. Facility -wide emissions of each individual hazardous air pollutant shall be less than 1,359 lb/month. Facility -wide emissions of total hazardous air pollutants shall be less than 3,398 lb/month. Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type NOx VOC CO DEHY-1 001 --- 3.3 --- Point LPGFL 007 23.2 4.3 Point L-01 008 3.4 Point PWT-01 009 0.5 --- Point SLOP -01 010 1.3 1.2 Point CNDTK-01 011 --- 21.5 3.4 Point See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility -wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. AIRS ID: 123/9DF2 Page 3 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division During the first twelve (12) months of operation, compliance with both the monthly and annual emission limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve- month total shall apply to all permitted emission units, requiring an APEN, at this facility. 8. Compliance with the emission limits in this permit shall be demonstrated by running the GRI GlyCalc model version 4.0 or higher on a monthly basis using the most recent extended wet gas analysis and recorded operational values (including gas throughput, lean glycol recirculation rate, and other operational values specified in the O&M Plan). Recorded operational values, except for gas throughput, shall be averaged on a monthly basis for input into GRI GlyCalc and be provided to the Division upon request. 9. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit (Reference: Regulation No.3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled DEHY-1 001 Air-cooled condenser and enclosed flare for the still vent VOC & HAPs LPGFL 007 Enclosed flare VOC & HAPs L-01 008 Vapor balance with enclosed flare VOC & HAPs PWT-01 009 Enclosed flare VOC & HAPs SLOP -01 010 Enclosed flare VOC & HAPs CNDTK-01 011 Enclosed flare VOC & HAPs 10. 100% of emissions that result from the flash tank associated with this dehydrator shall be recycled to the sales gas line or fuel gas system. AIRS ID: 123/9OF2 Page 4 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division PROCESS LIMITATIONS AND RECORDS 11 This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Monthly Limit (31 days) DEHY-1 001 Natural gas throughput 4,380 MMscf/yr 372 MMscf/month LPGFL 007 Gas Vented from Separator 12.2 MMscf/yr 1.04 MMscf/month L-01 008 Oil Loaded 1,972,529 BBL/yr 167,529 BBL/month PWT-01 009 Produced Water Throughput 1,265,820 BBL/yr 107,508 BBLlmonth SLOP -01 010 Condensate Throughput 535 BBL/yr 46 BBL/month CNDTK-01 011 Condensate Throughput 1,972,314 BBL 167,512 BBL/month The owner or operator shall monitor monthly process rates based on the calendar month. During the first twelve (12) months of operation, compliance with both the monthly and annual throughput limitations is required. After the first twelve (12) months of operation, compliance with only the annual limitation is required. 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. 12. This unit shall be limited to the maximum lean glycol circulation rate of 3.5 gallons per minute. The lean glycol recirculation rate shall be recorded daily in a log maintained on site and made available to the Division for inspection upon request. (Reference: Regulation No. 3, Part B, II.A.4) STATE AND FEDERAL REGULATORY REQUIREMENTS 13. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 14. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 15. This equipment is subject to the control requirements for glycol natural gas dehydrators under Regulation No. 7, Section XII.H. Beginning May 1, 2005, uncontrolled actual emissions of volatile organic compounds from the still vent and vent from any gas - condensate -glycol (GCG) separator (flash separator or flash tank), if present, shall be reduced by at least 90 percent through the use of air pollution control equipment. AIRS ID: 123/9OF2 Page 5 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division This source shall comply with all applicable general provisions of Regulation 7, Section XII. 16. The flare(s) covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). These requirements include, but are not limited to: • XVII.B.2.b If a 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, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. • XVIi.B.2.d Auto -igniters: All combustion devices used to control emissions of hydrocarbons must be equipped with and operate an auto -igniter as follows: • XVII.B.2.d.(i) All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device. • XVII.B.2.d.(ii) 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. 17. Point 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. 18. Point 001: This equipment is subject to the control requirements for glycol natural gas dehydrators under Regulation No. 7, Section XVII.D (State only enforceable). These requirements include, but are not limited to: XVII.D.3. Beginning May 1, 2015, still vents and vents from any flash separator or flash tank on a glycol natural gas dehydrator located at an oil and gas exploration and production operation, natural gas compressor station, or gas -processing plant subject to control requirements pursuant to Section XV1I.D.4., shall reduce uncontrolled actual emissions of hydrocarbons by at least 95 percent on a rolling twelve-month basis through the use of a condenser or air pollution control equipment. If a combustion device is used, it shall have a design destruction efficiency of at least 98% for hydrocarbons. XVII.D.4. The control requirement in Section XVII.D.3. shall apply where: XVII.D.4.a. Uncontrolled actual emissions of VOCs from a glycol natural gas dehydrator constructed on or after May 1, 2015, are equal to or greater than two (2) tons per year. Such glycol natural gas dehydrators must be in compliance with Section XVII.D.3. by the date that the glycol natural gas dehydrator commences operation. 19. Point 008: This source is located in an ozone non -attainment or attainment -maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements AIRS ID: 123/9DF2 Page 6 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 20. Point 008: 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. E): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. b. All compartment hatches (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. c. The owner or operator shall inspect loading equipment and operations on site at the time of the inspection to ensure compliance with the conditions (a) and (b) above. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request 21. Point 010; Point 011: This source is subject to Regulation Number 7, Section XII. The operator shall comply with all applicable requirements of Section XII and, specifically, shall: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for condensate storage tanks; and Ensure that the combustion device controlling emissions from this storage tank be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. (Regulation Number 7, Section XII.C.) (State only enforceable) 22. Point 010; Point 011: 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. 23. Point 010; Point 011: 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 AIRS ID: 123/9DF2 Page 7 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division 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. 24. Point 009; Point 010; Point 011: The storage tanks covered by this permit are subject to Regulation 7, Section XVII.C emission control requirements. These requirements include, but are not limited to: Section XVII.C.1. Control and monitoring requirements for storage tanks XVII.C.1.b. Owners or operators of storage tanks with uncontrolled actual emissions of VOCs equal to or greater than six (6) tons per year based on a rolling twelve-month total must 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. XVII.C.1.b.(i)(a) Control requirements of Section XVII.C.1.b. must be achieved within ninety (90) days of the date that the storage tank commences operation. XVII.C,1.d. Beginning May 1, 2014, or the applicable compliance date in Section XVII.C.1.b.(i), whichever comes later, owners or operators of storage tanks subject to Section XVII.C.1. must conduct audio, visual, olfactory ("AVO") and additional visual inspections of the storage tank and any associated equipment (e.g. separator, air pollution control equipment, or other pressure reducing equipment) at the same frequency as liquids are loaded out from the storage tank. These inspections are not required more frequently than every seven (7) days but must be conducted at least every thirty one (31) days. Monitoring is not required for storage tanks or associated equipment that are unsafe, difficult, or inaccessible to monitor, as defined in Section XVII.C.1.e. The additional visual inspections must include, at a minimum: XVII.C.1.d.(i) Visual inspection of any thief hatch, pressure relief valve, or other access point to ensure that they are closed and properly sealed; XVII.C.1.d.(ii) Visual inspection or monitoring of the air pollution control equipment to ensure that it is operating, including that the pilot light is lit on combustion devices used as air pollution control equipment; XVII.C.1.d.(iii) If a combustion device is used, visual inspection of the auto -igniter and valves for piping of gas to the pilot light to ensure they are functioning properly; XVII.C.1.d.(iv) Visual inspection of the air pollution control equipment to ensure that the valves for the piping from the storage tank to the air pollution control equipment are open; and XVII.C.1.d.(v) If a combustion device is used, inspection of the device for the presence or absence of smoke. If smoke is observed, either the equipment must be immediately shut-in to investigate the potential cause for smoke and perform repairs, as necessary, or EPA Method 22 must be conducted to determine whether visible emissions are present for a period of at least one (1) minute in fifteen (15) minutes. AIRS ID: 123/9DF2 Page 8 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division XVII.C.1.e. If storage tanks or associated equipment is unsafe, difficult, or inaccessible to monitor, the owner or operator is not required to monitor such equipment until it becomes feasible to do so. XVII.C.2. Capture and monitoring requirements for storage tanks that are fitted with air pollution control equipment as required by Sections XII.D. or XVII.C.1. XVII.C.2.a. Owners or operators of storage tanks must route ail hydrocarbon emissions to air pollution control equipment, and must operate without venting hydrocarbon emissions from the thief hatch (or other access point to the tank) or pressure relief device during normal operation, unless venting is reasonably required for maintenance, gauging, or safety of personnel and equipment. Compliance must be achieved in accordance with the schedule in Section XVII.C.2.b.(ii). XVII.C.2.b. Owners or operators of storage tanks subject to the control requirements of Sections XII.D,2., XVII.C.1.a, or XVIl.C.1.b. must develop, certify, and implement a documented Storage Tank Emission Management System ("STEM") plan to identify, evaluate, and employ appropriate control technologies, monitoring practices, operational practices, and/or other strategies designed to meet the requirements set forth in Section XVII.C.2.a. Owners or operators must update the STEM plan as necessary to achieve or maintain compliance. Owners or operators are not required to develop and implement STEM for storage tanks containing only stabilized liquids. The minimum elements of STEM are listed below. XVII.C.2.b.(i) STEM must include selected control technologies, monitoring practices, operational practices, and/or other strategies; procedures for evaluating ongoing storage tank emission capture performance; and monitoring in accordance with approved instrument monitoring methods following the applicable schedule in Section XVIl.C.2.b.(ii) and Inspection Frequency in Table 1. XVII.C,2.b.(ii) Owners or operators must achieve the requirements of Sections XVII.C.2.a. and XVII.C.2.b. and begin implementing the required approved instrument monitoring method in accordance with the following schedule: XVII.C.2.b.(ii)(a) A storage tank constructed on or after May 1, 2014, must comply with the requirements of Section XVII.C.2.a. by the date the storage tank commences operation. The storage tank must comply with Section XVII.C.2.b. and implement the approved instrument monitoring method inspections within ninety (90) days of the date that the storage tank commences operation. XVII.C.2.b.(ii)(d) Following the first approved instrument monitoring method inspection, owners or operators must continue conducting approved instrument monitoring method inspections in accordance with the Inspection Frequency in Table 1. Table 1 — Storage Tank Inspections Threshold: Storage Tank Uncontrolled Actual VOC Emissions (tpy) Approved Instrument Monitoring Method Inspection Frequency Phase -In Schedule AIRS ID: 123/9DF2 Page 9 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division > 6 and < 12 I Annually January 1, 2016 > 12 and < 50 Quarterly July 1, 2015 > 50 Monthly January 1, 2015 XVII.C.2.b.(iii) Owners or operators are not required to monitor storage tanks and associated equipment that are unsafe, difficult, or inaccessible to monitor, as defined in Section XV1I.C.1.e. XVII.C.2.b.(iv) STEM must include a certification by the owner or operator that the selected STEM strategy(ies) are designed to minimize emissions from storage tanks and associated equipment at the facility(ies), including thief hatches and pressure relief devices. XVII.C.3. Recordkeeping XVII.C.3. The owner or operator of each storage tank subject to Sections XII.D. or XVII.C. must maintain records of STEM, if applicable, including the plan, any updates, and the certification, and make them available to the Division upon request. In addition, for a period of two (2) years, the owner or operator must maintain records of any required monitoring and make them available to the Division upon request, including: XVII.C.3.a. The AIRS ID for the storage tank. XVII.C.3.b. The date and duration of any period where the thief hatch, pressure relief device, or other access point are found to be venting hydrocarbon emissions, except for venting that is reasonably required for maintenance, gauging, or safety of personnel and equipment. XVII.C,3.c. The date and duration of any period where the air pollution control equipment is not operating. XVII.C.3.d. Where a combustion device is being used, the date and result of any EPA Method 22 test or investigation pursuant to Section XVII.C.1.d.(v). XVII.C.3.e. The timing of and efforts made to eliminate venting, restore operation of air pollution control equipment, and mitigate visible emissions. XV1I.C.3.f. A list of equipment associated with the storage tank that is designated as unsafe, difficult, or inaccessible to monitor, as described in Section XVII.C.1.e., an explanation stating why the equipment is so designated, and the plan for monitoring such equipment. 25 This source is subject to the requirements of 40 CFR, Part 63, Subpart HH - National Emission Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities including, but not limited to, the following: • §63.764 - General Standards o §63.764 (e)(1) -The owner or operator is exempt from the requirements of paragraph (d) of this section if the criteria listed in paragraph (e)(1)(i) or (ii) of AIRS ID: 123/9DF2 Page 10 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division this section are met, except that the records of the determination of these criteria must be maintained as required in §63.774(d)(1). ■ §63.764 (e)(1)(ii) — The actual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere are less than 0.90 megagram per year, as determined by the procedures specified in §63.772(b)(2) of this subpart. • §63.772 - Test Methods, Compliance Procedures and Compliance Demonstration o §63.772(b) - Determination of glycol dehydration unit flowrate or benzene emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate or benzene emissions to meet the criteria for an exemption from control requirements under §63.764(e)(1). ■ §63.772(b)(2) - The determination of actual average benzene emissions from a glycol dehydration unit shall be made using the procedures of either paragraph (b)(2)(i) or (b)(2)(ii) of this section. Emissions shall be determined either uncontrolled, or with federally enforceable controls in place. §63.772(b)(2)(i) — The owner or operator shall determine actual average benzene emissions using the model GRI-GLYCaIc TM Version 3.0 or higher, and the procedures presented in the associated GRI-GLYCaIc TM Technical Reference Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit and may be determined using the procedures documented in the Gas Research Institute (GRI) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI-95/0368.1); or • §63.772(b)(2)(ii) - The owner or operator shall determine an average mass rate of benzene emissions in kilograms per hour through direct measurement using the methods in §63.772(a)(1)(i) or (ii), or an alternative method according to §63.7(f). Annual emissions in kilograms per year shall be determined by multiplying the mass rate by the number of hours the unit is operated per year. This result shall be converted to megagrams per year. • §63.774 - Recordkeeping Requirements o §63.774 (d)(1) - An owner or operator of a glycol dehydration unit that meets the exemption criteria in §63.764(e)(1)(i) or §63.764(e)(1)(ii) shall maintain the records specified in paragraph (d)(1)(i) or paragraph (d)(1)(ii) of this section, as appropriate, for that glycol dehydration unit. • §63.774 (d)(1)(ii) - The actual average benzene emissions (in terms of benzene emissions per year) as determined in accordance with §63.772(b)(2). OPERATING & MAINTENANCE REQUIREMENTS AIRS ID: 123/9OF2 Page 11 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division 26. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing, basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section lll.G.7.) 27. Point 001: The condenser outlet temperature shall be recorded as per the frequency required in the approved O&M Plan. This information shall be maintained in a log on site and made available to the Division for inspection upon request. The condenser outlet temperature shall not exceed 160 °F on a monthly average basis. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 28. Point 001; Point 007; Point 008; Point 009; Point 010; Point 011: The owner or operator shall demonstrate compliance with opacity standards, using EPA Method 22 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 (1) minute in any fifteen (15) minute period during normal operation. (Reference: Regulation No. 7, Section XVII.A.II) 29, Point 001: The owner or operator shall complete the initial annual extended wet gas analysis testing required by this permit and submit the results to the Division as part of the self -certification process to ensure compliance with emissions limits. (Reference: Regulation No. 3, Part B, Section III.E.) 30. Point 010; Point 011: The operator shall complete site specific sampling including a compositional analysis of the pre -flash pressurized condensate routed to these storage tanks and a sales oil analysis to determine RVP and API gravity. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine a site -specific emissions factor using Division approved methods. Results of site -specific sampling and analysis shall be submitted to the Division as part of the self -certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. Periodic Testing Requirements 31. Point 001: The owner or operator shall complete an extended wet gas analysis prior to the inlet of the TEG dehydrator on an annual basis. Results of the extended wet gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per this permit and be provided to the Division upon request. ADDITIONAL REQUIREMENTS 32. All previous versions of this permit are cancelled upon issuance of this permit. 33. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: AIRS ID: 123/9DF2 Page 12 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO)) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. 34. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). 35. MACT Subpart HH - National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities major stationary source requirements shall apply to this stationary source at any such time that this stationary source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of Subpart HH. {Reference: Regulation No. 8, Part E) GENERAL TERMS AND CONDITIONS 36. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 37. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III,G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for AIRS ID: 123/9DF2 Page 13 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division obtaining final authorization to operate are located in the Requirements to Self - Certify for Final Authorization section of this permit. 38. This permit is issued in reliance upon the accuracy and completeness 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. 39. 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. 40. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 41. Section 25-7-114.7(2)(a), C.R.S. requires that ail sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. AIRS ID: 123/9OF2 Page 14 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division 42. 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. Sy: Timothy Sharp Permit Engineer Permit History Issuance Date Description Issuance 1 February 16, 2016 Issued to Bonanza Creek Energy Operating Company LLC Permit for a TEG Dehydration unit at a synthetic minor oil and gas facility. Issuance 2 This Issuance Issued to Bonanza Creek Energy Operating Company LLC for points 007, 008, 009, 010 and 011 at a synthetic minor facility. AIRS ID: 123/9OF2 Page 15 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (ADEN) 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: hitslIwww.caiorado_gcvlbacificrcdche/agcc-regs 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emission Rate (lb/yr) Are the emissions reportable? Controlled Emission Rate (lb/yr) 001 Benzene 71432 33,441 Yes 1,245 Toluene 108883 39,487 Yes 1,129 Ethylbenzene 100414 9,129 Yes 174 Xylenes 1330207 35,314 Yes 622 n -Hexane 110543 7,911 Yes 114 2,2,4- Trimethylpentane 540841 12 No 1 007 Benzene 71432 4838 Yes 242 n -Hexane 110543 31910 Yes 1596 Toluene 108883 4294 Yes 216 Ethylbenzene 100414 628 Yes 32 Xylenes 1330207 1944 Yes 98 2,2,4- Trimethylpentane 540841 2966 Yes 150 008 Benzene 71432 352 Yes 22 n -Hexane 110543 5064 Yes 318 Toluene 108883 288 Yes 18 Xylenes 1330207 75 No 6 2,2,4- Trimethylpentane 540841 382 Yes 24 AIRS ID: 123/9DF2 Page 16 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division 009 Benzene 71432 379.7 Yes 19 n -Hexane 110543 126.6 No 6.3 010 Benzene 71432 67 No 3.3 n -Hexane 110543 503 Yes 25 011 Benzene 71432 3944.4 Yes 197.2 n -Hexane 110543 29583.2 Yes 1479.2 5) The emission levels contained in this permit are based on the following emission factors: Point 001: The emission levels contained in this permit are based on information provided in the application and the GRI GlyCalc 4.0 model. The model assumed the inlet gas temperature of 120°F and pressure of 800 psig. The permitted glycol recirculation rate is 3.5 gallons per minute. The source specified flash tank operation at a temperature of 150°F and a pressure of 125 psig, with 100% recompression/recycle of flash gas emissions. Still vent vapors are routed to an air-cooled condenser permitted at a maximum outlet temperature of 160°F at a pressure of 12.24 psia. Condenser emissions are controlled by an enclosed combustor. The enclosed combustor is granted a 95% reduction for the control of uncondensed vapors. Uncontrolled emission factors are based on the sum of the flash tank and still vent emissions from the Glycalc report. Controlled emissions are based on 100% recompression/recycle of the flash tank emissions and a 95% control of vapors from the condenser effluent stream. Point 007: Pollutant Weight Fraction of Gas r/o) Emission Factors Uncontrolled Ib/MMscf Emission Factors Controlled Ib/MMscf Source NOx (ib/MMBTU) --- 0.068 0.068 AP -42 CO (Ib/MMBTU) 0.31 0.31 AP -42 VOC 71.54 75976 3798.8 Gas Analysis Benzene 0.3736 396.77 I 19.8385 Gas Analysis Toluene 0.3316 352.160 17.608 Gas Analysis Ethylbenzene 0.0485 51.510 2.5755 Gas Analysis Xylenes 0.1501 159.410 7.9705 Gas Analysis n -hexane 2.4648 2617.63 130.8815 Gas Analysis Point 008: Pollutant Emission Factors Uncontrolled lb/1000gal loaded - Source VOC 1.32E+00 AP -42 Benzene 4.25E-03 AP -42 AIRS ID: 123/9DF2 Page 17 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division Pollutant Emission Factors Uncontrolled lb/1000ga1 loaded - Source n -Hexane 6,12E-02 AP -42 Toluene 3.46E-03 AP -42 Xylenes 9.29E-04 AP -42 The uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L = 12.46*S*P*M/T S = 1.0 (Submerged loading: dedicated normal service) P (true vapor pressure) = 2.6 psia M (vapor molecular weight) = 33.5 lb/lb-mol T (temperature of liquid loaded) = 524 °R Point 009: Pollutant Emission Factors Uncontrolled lb/BBL Produced Water Throughput Source VOC 0.013 ProMax Benzene 0.0003 ProMax Note: The controlled emissions for this point are based on the flare control efficiency of 95%. Point 010: Pollutant Emission Factors Uncontrolled lb/BBL Condensate Throughput Source VOC 96.9149 ProMax N -hexane 0.9395 ProMax Note: The controlled emissions for this point are based on the flare control efficiency of 95%. AIRS ID: 123/9DF2 Page 18 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division Point 011: Pollutant Emission Factors Uncontrolled Ib/BBL Condensate Throughput Source VOC 0.44 E&P TANK n -Hexane 0.015 E&P TANK Benzene 0.002 E&P TANK Note: The controlled emissions for this point are based on the flare control efficiency of 95%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, Benzene, Toluene, Xylene, Total HAPs NANSR Synthetic Minor Source of: VOC, Benzene, Toluene, Xylene, Total HAPs PSD True Minor Source MACT HH Area Source Requirements: Applicable 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A — Subpart KKKK NSPS Part 60, Appendixes Appendix A — Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A — Subpart Z MACT 63.600-63.1199 Subpart M — 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 AIRS ID: 123/9OF2 Page 19 of 20 Colorado Department of Public Health and Environment Air Pollution Control Division MACT 63.8980 -End Subpart NNNNN — Subpart XXXXXX 9) A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at: http'llwww.colorado riovfpaciflcicdphelair-permit-self-certification AIRS ID: 123/9OF2 Page 20 of 20 AIR POLLUTANT EMISSION NOTICE (ADEN) & Application for Construction Permit — Natural Gas Venting Permit Number: j JP, -.A [Leave blank unless APCD bas already assigned a permit # & AIRS ID] Emission Source AIRS ID: 123 / 9DF2 / c y fl Facility Equipment ID: LPGFL Section 01— Administrative Information Company Name: Bonanza Creek Energy Operating Company, LLC NAILS, or Antelope CPF 13-21 Production Facility (COGCC# Source Name: 441276) Source Location: NE/SW Sec. 21, T5N, R62W Mailing Address: 410 17`b Street, Suite 1400 Denver, CO SIC Code: [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 ❑ Request MODIFICATION to existing permit (check each box below that applies) County: Weld ❑ Change fuel or equipment ❑ Change company name Elevation: 4,672 Feet ❑ Change permit limit ❑ Transfer of ownership ❑ Request to limit HAPs with a Federally enforceable limit on PTE ZIP Code: 80202 ❑ Request APEN update only (check the box below that applies) 1311 Person To Contact: Jerry Dismukes Phone Number: 303-803-1724 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: Fax Number: 720-305-0802 Additional Info. & Notes: ❑ Other Revision to actual calendar year emissions for emission inventory Update 5 -Year APEN term without change to permit limits or previously reported emissions 10 / 08 / 2015 For new or reconstructed sources, the projected startup date is: 24 hours/day 7 days/week 52 weeks/year Low pressure gas from the low pressure separators and vapor recovery towers is controlled by six (6) enclosed flares when the VRU compressors are down. 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 • Gaslliouid Senarator ❑ Pneumatic Pump: Make: ❑ Compressor Rod Packing Make: ❑ Blowdowns: El Other: Description: Model: Model: # of events: Volume: E Yes ❑ No ❑ Don't know Serial #: # of pistons: IVIIVIscf/event Capacity: Leak rate: gal./min. Scf/hr/pist. Maximum Vent Rate (scf/hr) Actual Volume (MMsef/yr) Requested Volume2 (MMsegyr) Vent Gas Heating Value (Btu/set) Process Parameters: 1,390 NA 12.18 2,236 Molecular Wt. VOC (wt %) Benzene (wt %) Toulene (wt %) Ethylbenzene (wt %) Xylem (wt %) n-Hexane (wt %) Vented Gas Properties: 40.3 68.6730 0.3622 0.3216 0.0472 0.1459 2.3912 El 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 shell be a "not to exceed value" FORM APCD-211 34 0 621e" 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). ',Tail this form along with a check for 5152.90 to: Colorado Department of Public *Oh &.96a,vironment 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 idN NFU d 2-015 • Lheck box to request copy 01 draft emit prior to issuance. Check box to request copy of draft permit prior to public notice. d7 Form APCD-2 11 Natural Gas Venting APEN_ECD AIR POLLUTANT ENIISSION NOTICE (ADEN) & Application for Construction Permit — Natural Gas Venting Permit Number: Section 05 — Stack Information (Combustion stacks must be listed here) Operator Stack ID No Stack Base Elevation ({eft) Stack Discharge Height Above Ground Level (feet) Temp- (`F) Flow Rate (ACFM) Velocity (ft/sec) Moisture (%) rc>wu-61 4,672 1273 Emission Source AIRS ID: 123 / 9DF2 / Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or i 1TM) Horizontal Datum (NAD27, NAD83, UTM Zone UTM Easting or Longitude UTM Northing or Latitude Method of Collection for Location Data (e -g. map, WGSII4) (12 or 13) (meters or degrees) (meters or degrees) GPS, GoogleEartli) NAD83 13 -104.33316 40.38429 COGCC Direction of stack outlet (check one): ® Vertical ❑ Vertical with obstructing raincap Exhaust Opening Shape & Size (check one): ® Circular: Inner Diameter (inches) = 48 Section 07 — Control Device Information ❑ Horizontal ❑ Down ❑ Other: Length (inches) _ ❑ Other (Describe): Width (inches) — ■ VRU used for control of: 11 Combustion Device used for control of: Low Pressure Gas Rating: 4 MMBtu/hr Size: Make/Model: Type: Enclosed Flares Make/Model/Serial #: Six (6) ECDs (SN: 80060, 80070, 80059, 80069,031504-9-3,031504-9-1) 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: 2,236 Btu/scf The VRU recycles venting emissions to: Constant pilot light? 11 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. Z Emission Factor Documentation attached Data year for actual calendar yr- emissions below & tbrougltpu t above (e.g. 20117): i Pollutant Control Device Description Overall Collection Efficiency Control Efficiency (% Reduction) - Emission Factor Actual Calendar Year Emissions 4 Requested Permitted hnussitnis ,A- -{-; Fsciuiaiinn td iii i or Eniissi,+ti Factor Source • Primar}, Secondary Uncontrolled Basis Units Uncontrolled Tons/Year(Tons/Year) Controlled Uncontrolled (Tons/Year ) ( ) Controlled (Tons/Year) VOC ECD 100 95 73,047.5 lb/MMscf '199.1 21.3 Mass Balance NOX 0.068 lb/MA/btu NA O, 5 AP42 Tb 13.5-1 CO 0310 lb/M114btu NA 14 2 AP42 Tb 13-5-1 SOx _ <0.001 1b/MMbtu NA 0 Mass Balance P Benzene ECD 100 95 385-3 lb/M1VIscf 'j.'l o.Il-7 Mass Balance Toluene ECD 100 95 3411 lb/NIIVIscf 2. 9 O , foci Mass Balance Ethylbenzene ECD 100 95 50.2 1b/MMsef O. 3 c G E S Mass Balance Xylem ECD 100 95 155.2 lb/MMscf I. a -I---. O. b ti - Mass Balance n -Hexane ECD 100 95 2,543.5 lb/IVlMscf S fJ , / Mass Balance Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not Haled above, NA ' Annual emission fees will be based on actual emissions repelled here. I I' 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. frk_ 0 -07 - Section 09 —Applicant Certification - I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. R[.-• Enviromentai Regulatory � J��: � 2L2X PegYouug Manager Supply Data Date Name of Legally t utlknrized Person [P3 eJl ia)i5Title Page 2 of 2 S�`c ci7 Form APCD-211 Natural Gas Venting APEN_ECD NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) Permit Number: Company Name: Plant Location: Person to Contact: E-mail Address: Bonanza Creek Energy Operating Company, LLC NE/SW Sec_ 21, T5N, R62W Jerry Dismukes JDismukes@BonazaCrk.com AIRS 1D Number: 123/9DF2 County: Weld Phone Number: 303-803-1724 Zip Code: 80202 Fax Number: 720-305-0802 Chemical Abstract Service (CAS) Number Chemical Name I Control Equipment / Reduction (%) Emission Factor (Include Units) Emission Factor Source Uncontrolled Actual Emissions Controlled Actual Emissions (lbs/year) (lbs/year) 540-84-1 2,2,4-Trimethylpentai 95 236.4 Ib/MMscf AP -42 3608.1 180.4 Calendar Year for which Actual Data Applies: 1274x_eA4 /4-(6,2 Si r1atu of ers regally P fhorized to Supply Data Peg Young Name of Person Legally Authorized to Supply Data (Please print) .'fl,l,x,r.-,,.-6 N/A r/ *op ;.1 Date r6 pjs Environmental Regulatory Manager Title of Person Legally Authorized to Supply Data Form Revision Date: April 14, 2014 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Hydrocarbon Liquid Loading' Permit Number: tool Please use the Fuel Dispensing Station ADEN 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 I 9DF2 Facility Equipment ID: TLo Section 01— Administrative Information Company Name: Source Name: Source Location: Mailing Address: Person To Contact: E-mail Address: Phone Number: [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] Bonanza Creek Energy Operating Company, LLC Antelope CPF 13-21 Production Facility (COGCC# 441276) NE/SW Sec. 21, T5N, R62W NAICS, or SIC Code: Section 02 — Requested Action (Check applicable request boxes) l c F Action Applies To: 0 Individual Permit ❑ General Permit GP07 ❑1 Request NEW permit or newly reported emission source ❑ Request REGISTRATION for coverage under GP07 & concurrent request for CANCELLATION of individual permit number: 1311 ❑ Request MODIFICATION to existing permit (check each box below that applies) ❑ Change process or equipment ❑ Change company name ❑ Transfer of ownership ❑ Other 410 17th Street, Suite 1400 County: Weld Denver, Colorado Jerry Dismukes JDismukes@bonanzacrk_corn Elevation: 4,672 Feet ❑ Change permit limit ZIP Code: 80202 D Request to limit HAPs with a Federally enforceable limit on PTE 303-803-1724 Fax Number: 720-305-0802 Section 03 — General Information Date operation began or projected startup date: General description of equipment and purpose: Addl. Info. & Notes: Request APEEN update only. Note — Emissions data must be completed. Blank APENs will not be accepted 10 / 08 / 2015 Normal Hours of Source Operation: Loading of condensate into tanker trucks 24 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 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/ozoue) ► Does this source load gasoline into transport vehicles? If "Yes", provide an applicability determination of state and federal rules. Section 04 — Loading Information Product Loaded: 0 Condensate ❑ Crude Oil Other: BBL of condensate per year ■ If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Annual Volume Loaded: Requested2: 1,972,497 bbVyear Actual calendar year: NA bbUyear 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 Facto?: 1 Average Temperature of Bulk Liquid Loaded: 64 °F True Vapor Pressure: 2.61 psia @ 60 °F Molecular Weight of Displaced Vapors: 33.45 ► If this ADEN is being filed for vapor losses from pressurized loading lines, complete the following: Loads per year: Requested2: #/yr. Actual Calendar Year: #/yr. Load Line Volume4: Ft3/truckload Vapor Recovery Line Volume4: You may be charged an additional APEN fee for APEN re -submittal due to incorrectly filled -out APEN or missing information. Requested values will become permit limitations for individual construction permits. "-Please refer to AP -42, Table 5.2-1 for information on saturation factors (found online at: http;llmvw.ena.eovIttniehiefIao42khp51iadex.htmq. List the lolal volume for ill Lines in each category and attach your calculations of these volumes. Lb/lb-mol Product Density: Lb/ft 3 Ft3/truckload FORM APCD-208 ;mss -_. 4.0 it V/1 0 15 1\ f j FormAPCD-208-HydrocarbonLiquidLoadingAPEN-Ver.4-14 2014 (1).docx 1 t El El ❑r Yes Yes YesA YesA YesA Q ❑l ❑r No No No No No Don't know Don't know Don't know Don't know 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: (303) 692-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 APEN forms: www_colorado.gov/cdThe/airforms Permit status: www.colorado.gov/cdphe/permitstatus Page 1 of 2 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, Permit Number: Emission Source AIRS ID: 123 / 9DF2 / Section 05 — Stack Information (Combustion stacks must be listed here) Operator Stack S No. ID(feet) Stack Base Elevation (feet) Stack Discharge Height Above Ground Level Temp. (°F) Flow Rate (ACFM) Velocity (ftlsee) Moisture (%) ECD-D[1-6] 4,672 Direction of stack outlet (check one): Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Horizontal Datum (NAD27, NAD83, TJTM Zone UTM Easting or Longitude UTM Northing or Latitude Method of Collection for Location Data (e.g. map, WGS84) (12 or 13) (meters or degrees) (meters or degrees) GPS, GoogleEarth) NAD83 13 -104.33316 40.38429 COGCC EVertical Vertical with obstructing raincap Exhaust Opening Shape & Size (check one): 0 Circular: Inner Diameter (inches) = 48 Section 07 — Control Device Information ❑ Horizontal © Down ❑ Other: Length (inches) = ❑ Other (Describe): Width (inches) = 0 Loading occurs using a vapor balance system. 0 Combustion Device used for control of the loadout emissions. Type: Enclosed Flares Make/Model/Serial #: Rating: 1 MMBtu/hr ❑ Describe Any Other (Including VRU) 1 Six (6) ECI3s (501:00000, 60070, 60059, 00065, 031504-9-3, 031504-9-1) VOC & HAP Control Efficiency: Requested: 95 a/a Manufacturer Guaranteed: 98 VOC & HAP Control Efficiency: Requested: % Minimum temp. to achieve requested control: 'F Waste gas heat content: 1,964 Btu/scf Constant pilot light? n 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 L Crude Oil VOC: 0.104 Lbs/BBL Benzene: 0.00018 Lbs/BBL n -Hexane: 0.0016 Lbs/BBL ❑J 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): NIA Pollutant Control Device Description Control Efficiency (% Reduction) Emission Factor Actual Calendar Year Emissions5 Requested Permitted Emissions Estimation Method or Primary Secondary Uncontrolled Basis Units Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) Emission Factor Source NOx 0.068 lb/MMBtu N/A 0.130 . . AF-42Tables 135-182 VOC 1,321 Ib/1.000 ga1 /, b ,,II)3 ≤. 1_ AP 2 Chap 5.2 Co Identify in Section 07 0.310 ib/MMB1u N/A 0.592 - AP -0'_ T9b19 13.5-182 Benzene I 0.0042 Ib/1,000gal `.i....--, a. L133 OLUo03 (AP 42 Chap"5.2 n -Hexane 0.0611 Ib/1,000gal i , 6.-a3 -/ 0, 00y AP 42•Chap 5.2 Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Yee may be charged an additional APEN fee for APEN re submittal due to incorrectly filled -out ADEN or missing information. 5 Annual emission fees will be based on actual emissions reported here- A, ri Check box to request copy of draft permit prior to issuance. _ I l j Section 09 —Applicant Certification -I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. If this is a registration for ce' erne- under general permit GP07, I further certify that this source is and will be operated in full compliance with eachhc6ndition of general permit GP07. Sign( ure 14 Person Legally -13 Peg Young Environmental Regulatory Manager Name of Legally Authorized _Eers on- (Please print) Title Page 2 of 2 FonnAPCD-208-HydrocarbonLiquidLoadingAPEN-Ver.4-14-2014 (1).docx NON -CRITERIA REPORTABLE AIR POLLUTANT EMISSION NOTICE ADDENDUM (See reverse side for guidance on completing this form) Permit Number: Company Name: Plant Location: Person to Contact: E-mail Address: Bonanza Creek Energy Operating Company, LLC NE/SW Sec. 21, T5N, R62W Jerry Dismukes JDismukes@BonazaCrk.com AIRS ID Number: 123/9DF2 County: Weld Phone Number: 303-803-1724 Zip Code: 80202 Fax Number: 720-305-0802 Chemical Abstract Service (CAS) Number Chemical Name Control Equipment / Reduction (%) Emission Factor (Include Units) Emission Factor Source Uncontrolled Actual Emissions Controlled Actual Emissions (Ibs/ ear) lbs/ ear 540-84-1 • - 95 13.0046 lb/1,000-galAP-42 381.61 23.79 108-88-3 Toluene 95 0.0035 lb/1,000-gal- 286.66 17.87 Calendar Year for which Actual Data Applies: N/A -171 Signare of lersoLegally'Authorized to Supply Data Peg Young Name of Person Legally Authorized to Supply Data (Please print) . f/J, Date Environmental Regulatory Manager Title of Person Legally Authorized to Supply Data Form Revision Date: April 14, 2014 AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Produced Water Storage Tan (s)' Permit Number: Facility Equipment ID: [Leave blank unless APCD has already assigned a permit # & AIRS ID] Emission Source AIRS ID: 123 / 9DF2 / PWT-01 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization ] Section 01— Administrative Information Bonanza Creek Energy Operating Company, LLC Antelope CPF 13-21 Production Facility (COGCC# 441276) Company Name: Source Name: Source Location: NE/SW Sec. 21, T5N, R62W Mailing Address: 410 17th Street, Suite 1400 Denver, CO 1311 NAICS, or SIC Code: County: Weld Elevation: 4,672 Feet ZIP Code: 80202 Person To Contact: Jerry Dismukes Phone Number: 393-843-1724 E-mail Address: JDismukes@bonanzncrk.com Fax Number: 720-305-0802 Section O3 — General Information For existing sources, operation began on: 10 / 08 / 2015 This Storage Tank is Located at: Exploration & Production ® (E&P) Site ❑ Will this equipment be operated in any NAAQS nonattainment area? ► 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: Three (3) 500 -bbl produced water tanks. Section 02 — Requested Action (Check applicable request boxes) ® Request for NEW INDIVIDUAL permit ❑ Request for coverage under GENERAL PERMIT ❑ GP05 ❑ GP08 El Request MODIFICATION to existing INDIVIDUAL permit (check boxes below) El Change process or equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership ❑ Other ❑ 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 O4 — Storai Tanks) Information Requested Permit Limit: 1,265,820 Produced Water Throughput: Tank Design: E idstream or Downstream (Non-E&P) Site Yes ❑ No For new or reconstructed sources, the projected startup date is: hours/ Normal Hours of Source Operation: 24 day Are Flash Emissions anticipated at these tanks Actual: N/A Fixed Roof: El bbl/y ear bblly ear Internal Floating Roof Actual While Controls Operational: N/A ❑ External Floating Roof: bbi/year I Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of most recent storage vessel in storage tank (Month/Year) Date Of First Production (Month/Year) PWT-01 3, 500 -bbl 1,500 _ 06/2015 10/2015 Wells Serviced by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well . See attached Addendum CI ..❑ - v . 0 .._ 7 111 111 l l day s/ 52 weeks/ week year Yes ❑ No Yes ® No Yes ® No Yes ® No Yes El 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 odor to expiration of five-year term, or when a significant change made (increase production, new equipment, change in fuel type, cic). Mail this form along with a cheek for %i52.90 per APEN for non- E&P, midstream and downstream stony -en -or S152.90 for up to five (5) APENs for E&P sources and S254 €or each general permit registration to: Colorado Department of Public Health N.L'f nvironment APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Il: For guidance on how to complete this ANi.N form, Air Pollution Control Division: (303) 692-3150 Small Business Assistance Program (SBAP): '`"(30692-3148 or (303) 692-3I75 APEN forms: http://www.colorado.gov/cdphe/oiIgasAPENS Application status: http://www.colorado.gov/cdnhe/permitstatus FORM APCD-21117j Page 1 of 2 d2 Form APCD-2O7-ProducedWaterTank-APEN AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Produced Water Storage Tank(s)1 Permit Number: 5ectton u3 -- nraen. information tror lvxiastream sues only) Operator Stack ID No. Stack Base Elevation (feet) Stack Discharge Height Above Ground Level (feet) Temp. t"F1 Flow Rate ' (ACFM) Velocity (ft/sec) Moisture (%) Direction of stack outlet (check one): ® Vertical Emission Source AIRS ID: 123 / 9DF2 / Section 06 —Stack (Source. if no combustion) (Location tllalum & either l.at.fl.nna or UTh Horizontal Datum (NAD27, NAD63, 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) NAD83 13 -104.33316 40.38429 COGCC ❑ Vertical with obstructing raincap Exhaust Opening Shape & Size (check one): N Circular: Inner Diameter (inches) = 48 Section 1)7 — Control Device Information ❑ Horizontal ❑ Down ❑ 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) Make/ Model Type: Enclosed Flares VOC & HAP Control Efficiency: Requested Minimum temp. to achieve requested control: Constant pilot light? N Yes ❑ No Rating: 2 MMBtu/hr Six (6) ECDs (SN:80060, 80070, 80059, 80069, 031504-9-3, 031504-9-1) 95 % Manufacturer Guaranteed: 98 °F Waste gas heat content: 2,779 Btu/scf Pilot burner rating: MMBtu/hr 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 Description and flow diagram Section 09 -- Emissions Inventory Information & Emission Control Information ® Emission Factor Documentation attached Data year for actual calendar y r. emissions below & throughput in Sec. 04 (e.g. 2007): iNi=1 Pollutant Emission Factor Uncontrolled Basis Units Actual Calendar Year Emission l Requested Permitted Emissions Estimation Method or Emission Factor Source Uncontrolled (Tons/Year) Controlled (Tons/Year) Uncontrolled (Tons/Year) Controlled (Tons/Year) NOx 0.00005 lb/bbl N/A 0.03 CDPHE Memo VOC 0.013 lb/bbl 8.24 0.41 Promax CO 0.0001 lb/bbl N/A 0.08 CDPHE Memo Benzene 0.0003 lb/bbl 0.16 0,01 Promax Toluene Ethylbenzene Xylenes n -Hexane 0.0001 lb/bbl 0.06 0.003 Promax 2, 2, 4-Trimethy 1pe ntan e Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Section 10 —Applicant Certification - I hereb certify that all information contained herein and information submitted with this application is complete, true and correct. { / /I - /3 '20/3 Peg Young otur f Person Ifg l}y Auth r ed to Supply Data Date Name of Legally Authorized Person (Pease print), Title You will be charged dditional A P ' fee if the APEN is filled out incorrectly or is missing information and needs re -submittal 2 Annual emissions fees will be base on actual emissions reported here. If left blank, annual emissions fees will be based on requested emissions:' •'i 1. fa . "'r' 't Additional Information ❑ Required: Environmental Regulatory Manager Attach produced water laboratory analysis, stack test results and associated emissions calculations if you are requesting a site specific emissions factor according to the guidance in PS Memo 14-03 Check box to request copy of draft permit prior to issuance ClieO.. box to request cepy of draft permit prior to public notice LFORM APCD-207 ci Page 2 of 2 d2 Form APCD-207-ProducedWaterTank-APEN E&P Storage Tank Air Pollutant Emissions Notice (ADEN) Addendum Form' Company Name: Bonanza Creek Energy Operating Company, LLC Source Name: Antelope CPF 13-21 (COGCC# 441276) Emissions Source AIRS II)2: 123 / 9DF2 / Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 41371 Antelope E-A-21HNB @ 05 - 123 - 41370 Antelope 14-21-16XRLNB ►� 05 - 123 - 41372 Antelope E14-21-16XRLNC 14 05 - 123 - 41373 Antelope J14-21-16XRLNC ►4 05 - 123 - 36061 Antelope O-K-21HZ Il currently tied into ANT 1-21 Pad, will be tied into ANT CPF 13-21 sometime in 2016 _ 05 - 123 - 41974 State Antelope 21-24-28HNB currently being drilled for ANT J- 21 Pad, will be tied into ANT CPF 13- 21 sometime in 2016 05 - 123 - 41981 State Antelope F21-J-24-28HNC �� currently being drilled for ANT J- 21 Pad, will be tied into ANT CPF 13- 21 sometime in 2916 05 - 123 - 36015 State Antelope J-21-16XRL ❑currently tied into ANT 1-21 Pad, will be tied into ANT CPF 13-21 sometime in 2016 05 - 123 - 41984 State Antelope K21-O24-28HNC currently being drilled for ANT J- 21 Pad, will be tied into ANT CPF 13- 21 sometime in 2016 05 - 123 - 41977 State Antelope K31-034-28HNC ® currently being drilled for ANT J- 21 Pad, will be tied into ANT CPF 13- 21 sometime in 2016 05 - 123 - 41973 State. Antelope K-O-28HNB ® currently being drilled for ANT J- 21 Pad, will be tied into ANT CPF 13- 21 sometime in 2016 - - ❑ - - ❑ - - @ - - • - - - - ❑ - - ❑ - - ❑ - ❑ Footnotes: Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 dl a Form APCD-212-EP-StorageTank-APEN-Addendum- Condensate AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Storage Tank(s)1 Permit Number: I '5 U r i b ty it. [Leave blank unless APCD has already assigned a permit # & AIRS IDl Emission Source AIRS ID: 123 / 9DF2 Facility Equipment ID: SLOP -01 [Provide Facility Equipment ID to identify how this equipment is referenced within your organization ] Section 01— Administrative Information Company Name: Bonanza Creek Energy Operating Company, LLC Source Name: Antelope CPF 13-21 (COGCC #441276) Source Location: NE/SW Sec. 21, T5N, R62W Mailing Address: 410 17th Street, Suite 1400 Denver, CO NAICS, or 1311 SIC Code: County: Weld Elevation: 4,672 Feet ZIP Code: 80202 Person To Contact: Jerry Dismukes Phone Number: 303-803-1724 E-mail Address: JDismukes@bonanzacrk.com Fax Number: 720-305-0802 Section 03 — General Information For existing sources, operation began on: This Storage Tank is ® Exploration & Production Located at (E&P) Site Will this equipment be operated in any NAAQS nonattainment area? 09 / 02 / 2015 Midstream or Downstream (Non-E&P) Site ® Yes ❑ No I ()1 r, Section 02 — Requested Action (Check applicable request boxes) N Request for NEW INDIVIDUAL permit ❑ Request for coverage under GENERAL PERMIT ❑ GP01 ❑ GP08 El Request MODIFICATION to existing INDIVIDUAL permit (check boxes below) El Change process or equipment ❑ Change company name ❑ Change permit limit ❑ Transfer of ownership ❑ Other ❑ APEN Submittal for Permit Exempt/Grandfathered source ❑ APEN Submittal for update only (Please note blank APEN's will not be accepted) Addl. Into. & Nlor cs: Liquids from periodic compressor/gas lift dumps and fuel gas knockout liquids For new or reconstructed sources, the projected startup date is: Normal Hours of Source Operation: 24 hours/ day Are Flash Emissions anticipated at these tanks Is actual annual average hydrocarbon liquid throughput 500 bbl/day? El Yes ® No If "yes", identify the stock tank gas -to -oil ratio: Are these condensate tanks subject to Colorado Oil and Gas Conservation Commission (C0GCC) 805 series rules? If so, submit Fonn APCD-105. I► Are you requesting ? 6 ton/yr VOC emissions, or are uncontrolled actual emissions > 6 ton/yr? General description of equipment purpose: One (1) 500 -bbl slop tank for storage of compressor condensate dropout. Section 04 — Storage Tank(s) Information Requested Permit Limit 535 Condensate Throughput Actual: 178 Average API Gravity of Sales Oil: 72.8 Tank Design: Fixed Roof: N Internal Floating Roof bbl/year bbllyear Actual While Controls Operational: 178 degrees RVP of Sales Oil 20.11 ❑ External Floating Roof ❑ bbl/ year Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tauk (bbl) Installation Date of most recent storage vessel in storage tank (Month/Year) Date Of First Production (Month/Year) SLOP -01 1-500 bbl 500 06/2015 09/2415 Wells Serviced by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well - - i ❑ - - O - 0 - - 0 f I 7 days/ 52 weeks/ week year N Yes El No 0.53 Scf/bbl N Yes ❑ No ® Yes El 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 $15290_for up to five (5) APENs for E&P sources and $250 for,ea general permit registration to: n l[ II Colorado Department of Public Health & F,ny ronntent 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: (1113) 692-3150 Small Business Assistance Program (SBAP): (303) 692-3148 or (303) 692-3175 APEN forms: http://www.colorado.2ov/cdphe/oilgasAPENS Application status: http://www.colorado.gov/cdphe/permitstatus FORM APCD-205 0-61 Page 1 of 2 dl Form APCD-205-Condensate-Tanks-APEN Slop AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Storage Tank(s)t Permit Number: Section 05 — Stack Information (For Midstream sites oniv) Operator Stack ID No Stack Base Elevation (feet) Stack Discharge Height Above Ground Level (feet) Temp f°h) - Flow Rate (ACFM) r Velocity (ftlsee) Moisture (%) ECD-o[141 4,672 Direction of stack outlet (check one): ® Vertical ❑ Vertical with obstructing raincap Exhaust Opening Shape & Size (check one): ® Circular: Inner Diameter (inches) = 48 Section 07 — Control Device Information • Vapor Recovery Unit (VRU) used for control of the Storage Tank(s) Size: Make/Model: ® Combustion Device used for control of the Storage Tank(s) Type: Enclosed Flares Make/Model Rating: 1 MMBtu/hr Six (6) ECDs (SN: 80060, 80070, 80059, 80069,031504-9-3,031504-9-1) 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: 2,762 Btu/scf • Closed loop system used for control of the storage tank(s) lJseription_ Constant pilot light? 1 / Yes • No Pilot burner rating: MMBtu/hr ❑ Describe Any Other: Emission Source AIRS ID: 123 / 9DF2 / Section 06 —Stack (Source, if no combustion) Location tC}atrnn & either I_avLorm or IfTk1 Horizontal Datum (NAD27, NAD83, UTM Zone UTM Easting or Longitude UTM Northing or Latitude Method of Collection for Location Data (e.g. map, WGS84) (12 or 13) (meters or degrees) (meters or degrees) GPS, GoogleEarth) . NAD83 13 -104.33316 40.38429 COGCC ❑ Horizontal ❑ Down ❑ Other: Length (inches) = ❑ Other (Describe): Width (inches) _ Section 08—CaslLiquids Separation Technology Information IE&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? Up to 130 psig Please describe the separation process between the well and the storage tanks: See Attached Process Flow Description and Diagram. Section 09 —Emissions Inventory Information & Emission Control Information ® Emission Factor Documentation attached Data year for actual calendar yr. emissions below & thrnughpui in Sec. 04 (e.g. 2015 Pollutant Emission Factor Actual Calendar Year Emissions Requested Permitted Emissions Emission Factor Data Source Uncontrolled Basis Units ` (Tons/Year) - Uncontrolled (Tons/Year) f Controlled - - -- -- -. Uncontrolled (Tons/Year) _ — — ( ) Controlled Tons/Year NOx 0.068 lb/M11Btu NA 0.10 NA 0.26 AP42 Tb1 13.5-1 VOC 33.13 lb/bbl 8.87 0.44 26.60 1.33 Promax Model CO 0.31 lb/M1113tu NA 0.44 NA 1.19 AP42 Tbl 13.5-1 Benzene 0.041 lb/bbl 0.01 <0.001 0.03 0.002 Promax Model Toluene 0.044 lb/bbl 0.01 <0.001 0.04 0.002 Promax Model Ethylhenzene 0.013 lb/bbl 0.003 <0.001 0.01 <0.001 Promax Model Xylenes 0.025 lb/bbl 0.01 <0.001 0.02 <0.001 Promax Model n-Hcxane 0.325 Ib/bbl 0.09 0.004 0.26 - 0.013 Promax Model 2,2,4-Trirnethylpentane 0.701 lb/bbl 0.19 0.01 0.56 0.03 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 information contained herein and information submitted with this application is eompiete, true and correct. Peg Young Sigratffre ofiperson 1_ egallyjAut}lorizeta) n Supply Data Date Name of Legally ,Authurized Person (Please print) ' Title You wile charged q .additional ; fee if the APEN is filled out incorrectly or is missing information and needs to be resubmitted. - 2 Annual emissions fee vi I be based on actual emissions reported here. If left blank., annual emissions fees will be based on requested emissions. RECEIVE Additional Information ® Attach a pressurized plc -Lush condensate extended liquids analysis, RVP & API analysis of the post -Flash oil Required: Attach E&P Tanks input elttitss:ca estimate documentation (or coLilvalenl simulation rcporrlrest results) ❑ Attach EPA TANKS emcss,onanalvt.t if emission estimates do not contain worlirigfbreailr Leg losses Environmental Regulatory Manager � Check hoot to, copy of draft permit prior io Es;uarce- ® Check box io request copy of drat rcinn: prior to public VIOL IC:; FORM APCf-2f5 Page 2 of 2 Sew can dl Form APCD-205-Condensate-Tanks-APEN_Slop AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Storage Tank(s)' Permit Number: Facility Equipment ID: CNDTK-01 [Leave blank unless APCD has already assigned a permit 14 & AIRS ID] Emission Source MRS ID: 123 / 9DF2 / O t L [Provide Facility Equipment ID to identify how this equipment is referenced within your organization] Section 01— Administrative Information Section 02 — Requested Action (Check applicable request boxes) ® Request for NEW INDIVIDUAL permit ❑ Request for coverage under GENERAL PERMIT El GP01 ❑ GP08 Source Location: NE/SW Sec. 21, TSN, R62W County: Weld ❑ Request MODIFICATION to existing INDIVIDUAL permit (check boxes below) ❑ Change process or equipment El Change company name Mailing Address: 410 17th Street, Suite 1400 ❑ Change permit limit ❑ Transfer of ownership ❑ Other Denver, CO ❑ APEN Submittal for Permit Exempt/Grandfathered source Person To Contact: Jerry Dismukes Phone Number: 303-803-1724 El APEN Submittal for update only (Please note blank APEN's will not be accepted) Company Name: Bonanza Creek Energy Operating Company, LLC Source Name: Antelope CPF 13-21 Production Facility (COGCC# 441276) NAICS, or 1311 SIC Code: Elevation: 4,672 Feet E-mail Address: JDismukes@bonanzacrk.com Section 03 — General Information For existing sources, operation began on: ZIP Code: 80202 Atltil. Fax Number: 720-305-0802 Info. S. Noles: 10 / 08 / 2015 This Storage Tank is ® Exploration & Production CIMidstream or Downstream Located at: (E&P) Site (Non -1;&P) Site Will this equipment be operated in any NAAQS nonattainment area? ® Yes El No Is actual annual average hydrocarbon liquid throughput 500 bbl/day? ® Yes ❑ No The oil produced on site fluctuates above and below an API gravity of 40. The tanks are therefore permitted as condensate tanks to be conservative. For new or reconstructed sources, the projected startup date is: hours/ day Are Flash Emissions anticipated at these tanks If "yes", identify the stock tank, gas -to -oil ratio: Normal Hours of Source Operation: 24 ► 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: Section 04 — Store Tank(s) Information Requested Permit Limit: 1,972,216 Condensate Throughput: Average API Gravity of Sales Oil: Tank Design: Fixed Roof: ® Internal Floating Roof: ❑ 7 1 1 days/ week 52 weeks/ year ® Yes ❑ No 3.84 Scf/bbl Yes ❑ No ® Yes ❑ No Eighteen (18) S00 -bbl condensate production tanks for storage of condensate before being hauled away by tanker trucks. bbl/year Actual: 1,643,514 bbl/year Actual While Controls Operational: 1,643,514 40.3 degrees RVP of Sales Oil 8.1 External Floating Roof: ❑ bbl/ year 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-o1 18-500 bbl 9,000 06/2015 10/2015 Wells Serviced by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well - See Attached Addendum ❑ - ❑ - ❑ - _ ❑ - - ■ 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 ADEN 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 lief i si 4300 Cherry Creek Drive South Denver, CO 81t246-1530 For guidance on how to complete this APEN form: Air Pollution Comm! Division: (303) 692-3150 Small Business Assistance Program (SBA P}: (303) 692-3148 or (303) 692-3175 APENforms: Imp:" ttctt.coIc: +.1.7c{iphc: nilc.i;:ME'i'\ Application status: http://www.colorado ov/cdphe/permitstatus FORM APCD-29S Page 1 of 2 dl Form APCD-205-Condensate-Tanks-APEN CNDTK AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — Condensate Storage Tanks)' Permit Number: • • aecnon u7,— brnta fluorination (l'or" LvlluslrCanl sites onix) Operator Stack ID No Stack Base Elevation (feet) Shack Discharge Height Above Ground Level (feet) Temp (°F) Flow Rate (ACFM). Velocity (ft/sec) Moisture (%) Direction of stack outlet (check one): Exhaust Opening Shape & Size (check one): N Circular: Inner Diameter (inches) = 48 N Vertical ❑ Vertical with obstructing rainca Section 117 —Control Device Information • Vapor Recovery Unit (VRU) used for control of the Storage Tank(s) Size: Make/Model: ►E Combustion Device used for control of the Storage Tank(s) Type: Enclosed Flares Make/Model Rating: 3 MvtBtu/hr Six (6) ECDs (SN:80060, 80070, 80059, 80069, 031504-9-3, 031504-9-1) 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: 2,779 0tu/scf • Closed loop system used for control of the storage tank(s) Constant pilot light? I +t Yes • No Pilot burner rating: MMBtu/hr Description: • Describe Any Other: Section 08 — Gas/Liquids Separation Technolo2v Information (E&P Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 1-2 Emission Source AIRS ID: 123 / 9DF2 / Section 06 —Stack (Source. if no combustion) Location fl)alurn & either LatrLonsa or t TM Horizontal Datum (NAD27, NAD83, UTM Zone UTM Fasting or Longitude UTM Northing or Latitude Method of Collection for Location Data (e g map, WGS84) (12 or 13) (meters or degrees) (meters or degrees) GPS, GoogleEarth) NAD83 13 -104.33316 40.38429 COGCC ❑ Horizontal ❑ Down ❑ Other: Length (inches) = ❑ Other (Describe): Width (inches) psig Please describe the separation process between the well and the storage tanks: See Attached Process Flow Description and Diagram. Section 09 — Emissions Inventory Information & Emission Control Information ® Emission Factor Documentation attached Data year for actual calendar vr- emissions below & uhroughput In See, 04 (c.g. NM); 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) N0x 0.068 lb/MMEtu NA 0.61 NA 0.73 AP42 Tbl 13.5-1 V0C 0.44 lb/bbl 357.60 17.88 429.12 21.46 Promax Model CO 031 lb/ fJ%fBtu NA 2.78 NA 3.33 AP42 Tbl 115-1 Benzene 0,002 lb/bbl 1.910 0.095 2.292 0.115 Promax Model Toluene 0.002 lb/bbl 1.699 0.085 2.039 0.102 Promax Model Ethylbenzene 0.0003 lb/bbl 0.249 0.012 0.299 0.015 Promax Model Xylenes 0.001 lb/bbl 0.771 0.039 0.926 0.046 Promax Model n -Hexane 0.015 lb/bbl 12.584 0.629 15.101 0.755 Pronlax Model 2,2,4-Trimethylpentane 0.002 lb/bbl 1.260 0.063 1311 0.076 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 infor / 1 j1 Shit,Azure o'fPerson Le ll Authorized You Atilll be char_edin dditignal 2 Annual emissions lee Additional information El Required: El El Supply Data ation contained herein and information submitted with this application is .iis •kOmplete, true and correct ` - Peg Young Environmental gulatory Manager ate ' Name of Legally Authorized Person (Please print) "f'it]e fee if the APEN is filled out incorrectly or is missing information and needs to be resubmitted. i I be Ilan il on actual emissions reported here. If left blank. annual emissions fees will be based on requested emissions. Attach apressurizedpre-flash condensate extended lrytads analysis, RVP & API final ysts of the lost.- flash oil Attach E&P Tanks input & emission estimate documentation for equivalent .simulation report/test resullsp Attach EPA TANKS emission analysi$ ifemi55ion csnmatc5 do net cumein svort:nsibreativaglosses ® Check box to iecTeest`rnvv of draft icrrnil prreF to issuance. Check box to request copy of draft permit prior to puhlic notice FORM APCD-105 a Page 2 of 2 dl Form APCD-205-Condensate-Tanks-.ADEN-CNDTK E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Form' Company Name: Bonanza Creek Energy Operating Company, LLC Source Name: Antelope CPF 13-21 (COGCC# 441276) Emissions Source AIRS ID2: 123 / 9DF2 / Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Repor#ed Well 05 -123 - 41371 Antelope E-A-21HNB _ 05 -123 - 41370 Antelope 14-21-16XRLNB O 05 - 123 - 41372 Antelope E14-21-16XRLNC El 05 - 123 - 41373 Antelope J14-21-16XRLNC 05 - 123 - 36061 Antelope O-K-21HZ ❑currently tied into ANT J-21 Pad, will be tied into ANT CPF 13-21 sometime in 2016 05 - 123 - 41974 State Antelope 21-24-28HNB l currently being drilled for ANT J- 21 Pad, will be tied into ANT CPF 13- 21 sometime in 2016 05 - 123 - 41981 State Antelope F21-J-24-28HNC 4 currently being drilled for ANT J- 21 Pad, will be tied into ANT CPF 13- 21 sometime in 2016 05 - 123 - 36015 State Antelope J-21-16XRL ❑currently tied into ANT 3-21 Pad, will be tied into ANT CPF 13-21 sometime in 2016 05 - 123 - 41984 State Antelope K21-O24-2SHNC Ir- currently being drilled for ANT J- 21 Pad, will be tied into ANT CPF 13- 21 sometime in 2016 05 -123 - 41977 State Antelope K31-034-28HNC '� currently being drilled for ANT 3- 21 Pad, will be tied into ANT CPF 13- 21 sometime in 2016 05 -123 - 41973 State Antelope K-O-28HNB currently being drilled for ANT J- 21 Pad, will be tied into ANT CPF 13- 21 sometime in 2016 - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ Footnotes: ' Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A RECHVED , N0V 16 241 Sitl1111.16 S41.11LP+ LForm APCD-212 dla Form APCD-212-EP-StorageTank-APEN-Addendum Condensate Hello