The URL can be used to link to this page

Browse Search

Home My WebLink About20191985.tiffCOLORADO Department of Public Health & Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150O St PO Box 758 Greeley, CO 80632 May 20, 2019 Dear Sir or Madam: RECEIVED MAY 2 4 2019 WELD COUNTY COMMISSIONERS On May 23, 2019, the Air Pollution Control Division will begin a 30 -day public notice period for Outrigger DJ Operating LLC - Koki Compressor Station. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governor I Larry Wolk, MD, MSPH, Executive Director and Chief Medical Officer CC.QLC C9),HLC. T), tic 9 eQiedui cPPOLSI"lI QK�cNIGW) U0311ci 2019-1985 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Outrigger DJ Operating LLC - Koki Compressor Station - Weld County Notice Period Begins: May 23, 2019 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Outrigger DJ Operating LLC Facility: Koki Compressor Station Oil and Gas Compressor Station Section 26 T8N, R61 W, Weld County, Colorado Weld County The proposed project or activity is as follows: Source is building new compressor station with 6 natural gas engines, 50 MMSCF/D of dehydration capacity as well as various hydrocarbon storage tanks and permit blowdowns 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 18WE1084 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Comments may be submitted using the following options: • Use the web form at https://www.colorado.Qov/pacific/cdphe/air-permit-public-notices. This page also includes guidance for public participation • Send an email to cdphe.commentsapcd@state.co.us • Send comments to our mailing address: Christian Lesniak Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 COLORADO Qa&Th*eu m$m*a COPHE EL a COLORADO Air Pollution Control Division I Depanrnent of i b?fc Health b £nmonment Dedicated to protecting and improving the health and environment of the people of Colorado CONSTRUCTION PERMIT Permit number: 18WE 1084 Date issued: Issued to: Issuance: 1 Outrigger DJ Operating LLC Facility Name: Koki Compressor Station Plant AIRS ID: 123/9FFF Physical Location: Sec. 26 T8N R61 W County: Weld County Description: Natural Gas Compressor Station Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description CM -220 002 One (1) Waukesha, Model L-7044GSI, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1576 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Non selective catalytic reduction (NSCR) system and air - fuel ratio control CM -230 003 One (1) Waukesha, Model L-7044GSI, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1576 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Non selective catalytic reduction (NSCR) system and air- fuel ratio control CM -240 004 One (1) Waukesha, Model L-7044GSI, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1576 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Non -selective catalytic reduction (NSCR) system and air- fuel ratio control Page 1 of 26 COLORADO Air Pollution Control Division Department of Pi -5'. c Health Et Env moment Facility Equipment ID AIRS Point Equipment Description Emissions Control Description CM -250 005 One (1) Waukesha, Model L-7044G5I, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1576 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Non -selective catalytic reduction (NSCR) system and air fuel ratio control CM -260 006 One (1) Waukesha, Model L-7044GSI, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1576 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for natural gas compression. Non -selective catalytic reduction (NSCR) system and air fuel ratio control Compressor Blowdowns 007 Natural gas venting from 6 compressors during maintenance blowdown events. Emissions from this source are vented to the atmosphere. None TEG-01 008 One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: Propak, Model: 186039, Serial Number; TBD) with a design capacity of 25 MMscf per day. This emissions unit is equipped with 1 (Make: Kimray, Model: 21020 PV) gas driven glycol pump with a design capacity of 3.5 gallons per minute.' This dehydration unit is equipped with a still vent, flash tank, and reboiler burner. Stripping gas is injected into the reboiler. Emissions from the still vent are routed to an air - cooled condenser, and then to the Enclosed Flare. Emissions from the flash tank are recycled using a closed -vent system. TEG-02 009 One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: Propak, Model: 186039, Serial Number: TBD) with a design capacity of 25 MMscf per day. This emissions unit is equipped with 1 (Make: Kimray, Model: 21020 PV) gas driven glycol pump with a design capacity of 3.5 gallons per minute. This dehydration unit is equipped with a still vent, flash tank, and reboiler burner. Stripping gas is injected into the reboiler. Emissions from the still vent are routed to an air - cooled condenser, and then to the Enclosed Flare. Emissions from the flash tank are recycled using a closed -vent system. Page 2 of 26 COLORADO Air Pollution Control Division Depetment at Pt;b ic Health & Env anment Facility Equipment ID AIRS Point Equipment Description Emissions Control Description Slop Condensate Tanks O1O Six (6) - 400 bbl Slop Condensate Storage Vessels Enclosed Combustor Truck Loadout O11 Truck loadout of slop condensate None PW Tanks O12 Two (2) 400 BBL produced water storage tanks Enclosed Combustor Points 002-006: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Waukesha L -7044G51 engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, l submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at www.colorado.gov/cdphe/air/manage-permit. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 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, III.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions Page 3 of 26 ICOLORADO Air Pollution Control Division I Department of Peb'tc Health tt Environment of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 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. Points 002-006: The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operationor issuance of this permit. • manufacture date • construction date • order date • date of relocation into Colorado • manufacturer • model number • serial number This information shall be included with the equipment. (Reference: Regulation No. 3, Part B, III.E.) Notice of Startup submitted for the 6. Points 008, 009: The following information shall be provided to the Division within fifteen (15) days of the latter of commencement of operation or issuance of this permit. • The dehydrator manufacturer name, model number and serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation Number 3, Part B, III.E.) 7. 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. Page 4 of 26 COLORADO Air Pollution Control Division Department of i ub c Health & Environment EMISSION LIMITATIONS AND RECORDS 8. 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 N0X V0C CO CM -220 002 905 1,293 1,810 Point CM -230 003 905 1,293 1,810 Point CM -240 004 905 1,293 1,810 Point CM -250 005 905 1,293 1,810 Point CM -260 006 905 1,293 1,810 Point TEG-01 008 --- 1504 468 Point TEG-02 009 1504 468 Point Slop Condensate Tanks 010 --- 3686 641 Point Truck Loadout 011 --- 410 --- Point PW Tanks 012 --- 10 --- 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. Page 5 of 26 COLORADO Air Pollution Control Division Dtvanment of PLb!:ac !-tea$h & Envdtonment Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type NO, V0C CO CM -220 002 5.3 7.6 10.7 Point CM -230 003 5.3 7.6 10.7 Point CM -240 004 5.3 7.6 10.7 Point CM -250 005 5.3 7.6 10.7 Point CM -260 006 5.3 7.6 10.7 Point Compressor Blowdowns 007 --- 1.9 --- Point TEG-01 008 --- 8.9 2.8 Point TEG-02 009 --- 8.9 2.8 Point Slop Condensate Tanks 010 21.7 3.8 Point Truck Loadout 011 --- 2.4 --- Point PW Tanks 012 --- 0.1 --- 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. 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. Page 6 of 26 CDPHE 1, COLORADO Air Pollution Control Division I Department of P, b+c Health b Environment 9. Points 008 £t 009: 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, condenser temperature, flash tank temperature and pressure, wet gas inlet temperature, and wet gas inlet pressure. Recorded operational values for each dehydrator, except for gas throughput, shall be averaged on a monthly basis for input into the model and be provided to the Division upon request. 10. Points 008 Et 009: On a monthly basis, the owner or operator shall monitor and record operational values for each TEG dehydration unit including: condenser outlet temperature, flash tank temperature and pressure, wet gas inlet temperature, and wet gas inlet pressure. (Lean glycol recirculation rate shall be recorded at the frequency specified in condition 16 of this permit). These records shall be maintained for a period of five years. 11. Points 008 Et 009: For each dehydrator, the condenser outlet temperature shall not exceed 125 degrees F, on a rolling twelve-month average. The owner or operator shall calculate the rolling twelve-month average temperature by averaging all recorded condenser outlet temperature values as specified in this permit. 12. 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 CM -220 002 Non -Selective Catlytic Reduction (NSCR) and air/fuel ratio controller VOC, NOx, CO CM -230 003 Non -Selective Catlytic Reduction (NSCR) and air/fuel ratio controller VOC, NOx, CO CM -240 004 Non -Selective Catlytic Reduction (NSCR) and air/fuel ratio controller VOC, NOx, CO CM -250 005 Non -Selective Catlytic Reduction (NSCR) and air/fuel ratio controller VOC, NOx, CO CM -260 006 Non -Selective Catlytic Reduction (NSCR) and air/fuel ratio controller VOC, NOx, CO TEG-01 008 Still Vent: BTEX Condenser Et Enclosed Flare VOC and HAPs Flash Tank: Recycled using closed -vent system VOC and HAPs TEG-02 009 Still Vent: BTEX Condenser £t Enclosed Flare VOC and HAPs Flash Tank: Recycled using closed -vent system VOC and HAPs Slop Condensate Tanks 010 Enclosed Flare VOC and HAPs PW Tanks 012 Enclosed Flare VOC and HAPs Page 7 of 26 !COLORADO Air Pollution Control Division Depaimenz of 1 Lh e Health Et Envxonment PROCESS LIMITATIONS AND RECORDS 13. 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) CM -220 002 Consumption of natural gas as a fuel 105.50 MMscf 8.96 MMscf CM -230 003 Consumption of natural gas as a fuel 105.50 MMscf 8.96 MMscf CM -240 004 Consumption of natural gas as a fuel 105.50 MMscf 8.96 MMscf CM -250 005 Consumption of natural gas as a fuel 105.50 MMscf 8.96 MMscf CM -260 006 Consumption of natural gas as a fuel 105.50 MMscf 8.96 MMscf Compressor Blowdowns 007 Gas released during blowdown events 0.18 MMscf N/A TEG-01 008 Dry gas throughput 9,125.0 MMscf 775 MMscf TEG-02 009 Dry gas throughput 9,125.0 MMscf 775 MMscf Slop Condensate Tanks 010 Condensate Throughput 163,374 BBL 13876 BBL Truck Loadout 011 Condensate Loaded 24,000 BBL 2038 BBL PW Tanks 012 Produced Water Throughput 7,300,000 BBL 620,000 BBL The owner or operator shall calculate 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 Page 8 of 26 (COLORADO Air Pollution Control Division Department of Pt b c Health ft Envtonment throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 14. Points 002 - 006: Fuel consumption shall be measured by one of the following methods: individual engine fuel meter or facility -wide fuel meter attributed to fuel consumption rating and hours of operation. 15. Point 007: The owner or operator shall record the following information during each compressor blowdown. Records shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation No. 3 Part B, II.A.4) • Date and time of blowdown. • Estimated volume of each blowdown. In order to demonstrate compliance with the emission limitations of this permit, emissions due to blowdown activities shall be calculated on a monthly basis. The emissions calculations shall be based on the information collected above and the emission factors listed in the "Notes to Permit Holder" section of this permit. 16. Points 008 £t 009: 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 weekly in a log maintained on site and made available to the Division for inspection upon request. Glycol recirculation rate shall be monitored by one of the following methods: assuming maximum design pump rate, using glycol flow meter(s), or recording strokes per minute and converting to circulation rate. (Reference: Regulation Number 3, Part B, II.A.4) 17. Points 008 £t 009: The volume of dry gas throughput shall be measured by gas meter at the outlet of the dehydration system. 18. Points 008, 009: On a weekly basis, the owner or operator shall monitor and record operational values including: flash tank temperature and pressure, wet gas inlet temperature and pressure.These records shall be maintained for a period of five years. STATE AND FEDERAL REGULATORY REQUIREMENTS 19. 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) 20. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. a 4.) Page 9 of 26 ;COLORADO Air Pollution Control Division Depaqmenc of PLN,c Health & Enueonment 21. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 22. Points 002 - 006: This equipment is subject to the control requirements for stationary and portable engines in the 8 -hour ozone control area under Regulation No. 7, Section XVI.B.1. For rich burn reciprocating internal combustion engines, a non -selective catalyst reduction system and an air fuel controller shall be required. 23. Points 008, 009: This source is subject to Regulation Number 7, Section XII.H. The operator shall comply with all applicable requirements of Section XII and, specifically, shall: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for glycol natural gas dehydrators; and • • Ensure uncontrolled actual emissions of volatile organic compounds from the still vent and vent from any gas -condensate -glycol (GCG) separator (flash separator or flash tank), if present, shall be reduced by at least 90 percent on a rolling twelve-month basis through the use of a condenser or air pollution control equipment. (Regulation Number 7, Section XII.H.1.) 24. Points 008, 009: 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.17; 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 upon installation of the combustion device. 25. Points 008, 009: The glycol dehydration unit covered by this permit is subject to the emission control requirements in Regulation Number 7, Section 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 XVII.D.4., shall reduce uncontrolled actual emissions of hydrocarbons by at least 95% on a rolling twelve-month basis through the use of a condenser or air pollution control equipment. Page 10 of 26 COLORADO Air Pollution Control Division Department a Pub lc Health it Env€ronment 26. Points 008, 009: The glycol dehydration unit at this facility is subject to National Emissions Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities, Subpart HH. This facility shall be subject to applicable area source provisions of this regulation, as stated in 40 C.F.R Part 63, Subpart A and HH. (Regulation Number 8, Part E, Subpart A and HH) MACT HH Applicable Requirements Area Source Benzene emissions exemption §63.764 - General Standards §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 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 §63.772(b) - Determination of glyco€ 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). 563.772(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-GLYCalc TM, Version 3.0 or higher, and the procedures presented in the associated GRI-GLYCaIc TMTechnical 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 §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). Page 11 of 26 !COLORADO E Air Pollution Control Division Department of PLb'c Health & Envxonrnerzt 27. Point 010: 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) 28. Point 010: 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 emissionsduring 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. 29. Point 010: The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall install and operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons except where the combustion device has been authorized by permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation Number 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two years, made available to the Division upon request. This control requirement must be met within 90 days of the date that the storage tank commences operation. 30. Point 010: The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Section XVII.C.2. 31. Point 011: This source is located in an ozone non -attainment or attainment - maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.D.2) Page 12 of 26 COLORADO Air Pollution Control Aivisior► Depa*trnent of PLA c Health & Enmronrent 32. Point 011: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. 33. Point 011: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.D.2): a. The owner or operator shall inspect onsite loading equipment to ensure that hoses, couplings, and valves are maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. b. All compartment hatches at the facility (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. d. Inspect pressure relief devices (PRD) annually for proper operation and replace as necessary. PRDs shall be set to release at a pressure that will ensure flashing, working and breathing losses are not vented through the PRD under normal operating conditions. e. Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. OPERATING & MAINTENANCE REQUIREMENTS 34. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 35. Points 002 - 006: A source initial compliance test shall be conducted on the emissions points to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emission limits in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or Page 13 of 26 COLORADO Air Pollution Control Division Department of Th. h k Health b Environment annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. Volatile Organic Compounds using EPA approved methods. Formaldehyde 36. Points 008, 009: The owner or operator shall complete the initial extended wet gas analysis within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit. The owner or operator shall use this analysis to calculate actual emissions, as prescribed in the Emission Limitation and Records section of this permit, to verify initial compliance with the emission limits. The owner or operator shall submit the analysis and the emission calculation results to the Division as part of the self -certification process. (Reference: Regulation Number 3, Part B, Section III.E.) 37. Points 008, 009, 010: The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one minute in any fifteen -minute period during normal operation. (Regulation Number 7, Sections XII.C, XVII.B.2. and XVII.A.16) Periodic Testing Requirements 38. Points 002 - 006: This engine is subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. 39. Points 008, 009: The owner or operator shall complete an extended wet gas analysis prior to the inlet of the dehydration unit on an annual basis. Results of the 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 40. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or Page 14 of 26 COLORADO Air Pollution Control Division r paqrnent of Pub'tc Health & Environment For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of V0C or NO. per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative -operating scenario and is installing a permanent replacement engine. 41. Federal regulatory program requirements (i.e. PSD or NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction 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). GENERAL TERMS AND CONDITIONS 42. 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. 43. 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 Page 15 of 26 CDPHE COLORADO 1 Air Pollution Control Division Depalment of f'tb'!c Health & Ensmonmelt reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 44. 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. 45. 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. 46. 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 at) 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. 47. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 48. 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. Christian Lesniak Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Outrigger DJ Operating, LLC Page 16 of 26 COLORADO Air Pollution Control Division Department of P'ub'ic Health Et Environment 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 (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/acct-reps 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Facility Equipment ID AIRS Point Pollutant CAS # Uncontrolled Emission Rate (Ib/yr) Controlled Emission Rate (lb/yr) CM -220 CM -230 CM -240 CM -250 CM -260 002 003 004 005 006 Formaldehyde 50000 1,522 1,522 Methanol 67561 352 352 Acetaldehyde 75070 321 321 Acrolein 107028 303 303 Benzene 71432 182 182 1,3 -Butadiene 106990 76 76 Toluene 108883 64 64 Compressor Blowdowns 007 n -Hexane 110543 73 73 TEG-01 TEG-02 008 009 Benzene 71432 44369 1853 Toluene 108883 31418 1364 Ethytbenzene 100414 2920 130 Xylenes 1330207 7574 342 n -Hexane 110543 21331 384 224 TMP 540841 11 0 Slop Condensate Tanks 010 Benzene 71432 3856 193 Toluene 108883 1944 97 Page 17 of 26 COLORADO Air Pollution Control Division I Depakmens of PLb!".c Health b EnV ronment Ethylbenzene 100414 131 7 Xylenes 1330207 245 12 n -Hexane 110543 22023 1101 224 TMP 540841 16 1 Truck Loadout 011 Benzene 71432 73 73 Toluene 108883 135 135 Ethylbenzene 100414 30 30 Xylenes 1330207 61 61 n -Hexane 110543 403 403 224 TMP 540841 5 5 5) The emission levels contained in this permit are based on the following emission factors: Point 002 - 006: CAS Pollutant Emission Uncontrolled lb/MMBtu Factors - g/bhp-hr Emission Factors lb/MMBtu - Controlled g/bhp-hr NOx 3.7286 14.10 0.0926 0.35 CO 3.3319 12.60 0.1851 0.70 VOC 0.1957 0.74 0.1322 0.50 50000 Formaldehyde 0.0132 0.05 0.0132 0.05 67561 Methanol` 0.0031 0.01 0.0031 0.01 75070 Acetaldehyde 0.0028 0.01 0.0028 0.01 107028 Acrolein 0.0026 0.01 0.0026 0.01 71432 Benzene 0.0016 0.01 0.0016 0.01 106990 1,3 -Butadiene 0.0007 0.00 0.0007 0.00 108883 Toluene 0.0006 0.00 0.0006 0.00 Emission factors are based on a Brake -Specific Fuel Consumption Factor of 8337 Btu/hp-hr, a site -rated horsepower value of 1576, and a fuel heat value of 1091 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource NOx Manufacturer CO Manufacturer VOC Manufacturer 50000 Formaldehyde Manufacturer 67561 Methanol AP -42; Table 3.2-3 (7/2000); Natural Gas 75070 Acetaldehyde AP -42; Table 3.2-3 (7/2000); Natural Gas 107028 Acrolein AP -42; Table 3.2-3 (7/2000); Natural Gas 71432 Benzene AP -42; Table 3.2-3 (7/2000); Natural Gas 106990 1,3 -Butadiene AP -42; Table 3.2-3 (7/2000); Natural Gas 108883 Toluene AP -42; Table 3.2-3 (7/2000); Natural Gas Page 18 of 26 COLORADO Air Pollution Control Division Depamnent of MIST Health b Envxonment Point 007: CAS # Pollutant Weight Fraction of Gas (%) Uncontrolled Emission Factors (lb/MMSCF) Source VOC 32.56 20523.97 Mass balance Emissions from this point are based on blowdowns of gas from compressors. The volume of gas emitted per event is based on the following, as derived from engineering estimates: 2.5 MSCF per event per compressor The total volume of gas is based on the sum of the volume emitted for each event and for each compressor in a given compliance period. Points 008 Et 009: The emission levels contained in this permit are based on information provided in the application and the GRI GlyCalc 4.0 model. Controlled still vent emissions are based on a combustor control efficiency of 95.0% and the use of a condenser with a condenser temperature not exceeding 125 degrees Fahrenheit. A 50% emissions buffer has been applied to allcontrolled emissions by source to account for variation in gas composition. Flash tank emissions are recycled utilizing a closed vent system with no allowable downtime. Point 010: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 0.0096 ' 0.0096 AP -42 Chapter 13.5 CO 0.0438 0.0438 AP -42 Chapter 13.5 VOC 5.31 0.27 Promax 71432 Benzene 0.024 0.001 Promax 108883 Toluene 0.012 0.001 Promax 110543 n -Hexane 0.135 0.007 Promax Note: The controlled emissions factors for this point are based on a control efficiency of 95%. Point 011: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Source VOC 2.01 E-01 AP -42: Chapter 5.2, Equation 1 110543 n -Hexane 1.68E-02 AP -42: Chapter 5.2, Equation 1 Page 19 of 26 COLORADO Air Pollution Control Division Department of Pt,h'3c Health & Envronmeolt HAP emissions were calculated using predicted mass fractions of HAPs in pressurized condensate stream Point 012: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 3.23E-04 1.62E-05 EPA Tanks Note: The controlled emissions factors for this point are based on a control efficiency of 95%. Emissions were calculated assuming 2% hydrocarbons in produced water in EPA Tanks modeling software. 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) Points 002 -006: These engines are subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting - effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ia08.pdf 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: NOx, VOC, CO, benzene, toluene, n - hexane, total HAPs PSD or NANSR Synthetic Minor Source of: NOx, VOC, CO MACT ZZZZ Major Source Requirements: Not Applicable Area Source Requirements: Applicable MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Applicable 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories Page 20 of 26 COLORADO Air Pollution Control Division Department of Th b'=:c Health EP Ent ronnient MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE - Subpart PPP MACT 63.1440-63.6175 Subpart QQQ - Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX 10) A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at: http://www.co1orado.gov/pacific/cdphe/air-permit-self-certification Page 21 of 26 COLORADO Air Pollution Control Division Department of Th b'tc HPalch ft Etw:ronment ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility -Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with an engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state -only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on -site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. Page 22 of 26 COLORADO Air Pollution Control Division Depa menc of I1:b!:c Health Er Environment 2.1.2 The owner or operator may permanently replace the existing engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at www.colorada.Qov/cdphe/air/AOS. This submittal shall be accompanied by a certification from the Responsible Official indicating that "based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may, be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time, period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacementengine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at: www.colorado.gov/cdphe/portable-analyzer-monitoring-protocol Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. Page 23 of 26 COLORADO Air Pollution Control Division Department of tj.h'^.c Health & Enuronment For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd ® 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above -mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (S 60.331) and 40 CFR Part 72 (5 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State - Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non -selective catalyst and air fuel controller to reduce emission. Page 24 of 26 COLORADO Air Pollution Control Division Department of Pub?sc Health ft Environment Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVII.E - State -only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Max Engine HP Construction or Relocation Date Emission Standards in G/hp-hr NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500≤Hp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less 'than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the Permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § I.B (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. Page 25 of 26 COLORADO Air Pollution Control Division I Department of Pi:b'sc Health & Environment 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. Page 26 of 26 Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Package It Received Date: Review Start Date: Christian Lesniak 388695 10/9/2018 4/2/2019 Section 01- Facility Information Company Name: Outrgger DJ Operating Lit County AIRS ID: 123 Quadrant Section Township Range 26 EN 61 Plant AIRS ID: Facility Name: Physical Address/Location: County: Type of Facility: What industry segment? Oil & Natural Gas Production & Processing Is this facility located in a NAAQS non -attainment area? If yes, for what pollutant? Carbon Monoxide (CO) 9FFF Koki Compressor Station Section 26, Township 8N, Range 61W Weld County Natural Gas Compressor Station • Section 02 - Emissions Units In Permit Application Yes • Particulate Matter (PM) F' Ozone (NOx & VOC) AIRs Point # Emissions Source Type Equipment Name Emissions Control? Permit # Issuance # Self Cert Required? Action Engineering Remarks Natural Gas RICE •..:'. 18WE1084 Permit Initial Issuance Natural Gas RICE Ye 18WE1084 Permit Initial Issuance Natural Gas RICE C Ye 18WE1084 Permit Initial Issuance Natural Gas RICE CM -250 Yes 18WE1084 , Permit Initial Issuance Natur _3as RICE CM -260 18WE1084 Permit Initial Issuance 00, Maintenance Biowdowns Compressor Biowdow 18WE1084 Permit Initial Issuance 008 Dehydrator TEG-01 1:: 18WE1084 rc.. Permit Initial Issuance 009 Dehydrator TEG-02 Yes 18WE1084 Yes Permit Initial Issuance 010 CDndensate Tank cpOilTanks Yes 18WE1084 Yes Permit Initial Issuance 011 iciuid Loading Truck Loadout No 18WE1084 Yes Permit initial Issuance Produced Water Tank PW Tanks Yes 18WE1084 Permit initial Issuance Not initially included in application, bu provided by source -- Section 03 - Description of Project AIRS Point 001 is a GP02 (included in the same project) See 18WE1048.CP1(002-006) for engine PAs. Produced water tanks were not initially included in the permit application, but were submitted by applicant on April 26, 2019, due to the two tanks being liquid manifolded together, making the total tank emissions exceed APEN reportability thresholds for VOC. Section 04 - Public Comment Requi-ements Is Public Comment Required? If yes, why? Requesting _ynthetic Minor Permit Section 05 - Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? If yes, for what pollutants? If yes, attach a copy of Technical Ser.ices Unit modeling results summary. Yes No Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic rrinor? If yes, indicate programs and which pollutants: Prevention of Significant Deterioratior (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review ( VANSR) SO2 Is this stationary source a major source? If yes, explain what programs and which pollutants her( SO2 Prevention of Significant Deterioration (PSD) Title V Operating Permits (OP) Non -Attainment New Source Review (NANSR) n Yes NOx CO VOC PM2.5 PM10 TSP HAPs nrl VOC NOx CO basso, n PM2.5 PM10 TSP Fl • • HAPs • Section 01 - Administrative Information 123 9FFF 001 Facility AIRs ID: County Plant Point Section 02 - Equipment Description Details This source vents natural gas from: 6 compressors Emissions from this source are: vented to the atmosphere Natural gas venting from 6 compressors during maintenance blowdown events. Emissions from this source are vented to the atmosphere. Section 03 - Processing Rate Information for Emissions Estimates 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 scf/lb-mol) at 60F and 1 atm No of compressors: volume per event No. events per compressor: Total No, of events: 6 2.5 MSCF 12 72 TOTAL VOLUME VENTED: 0.18 MMSCF/yr Section 04 - Emissions Factors & Methodologies MW 23.89 Weight % Helium 0.00 CO2 4.50 N2 1.20 methane 47.22 ethane 14.32 propane 15.29 isobutane 2.16 n -butane 7.38 isopentane 2.10 n -pentane 2.71 cyclopentane n -Hexane 0.64 cyclohexane Other hexanes 1.33 heptanes 0.61 methylcyclohexane 224-TMP 0.00 Benzene 0.11 Toluene 0.06 Ethylbenzene 0.00 Xylenes 0.01 C8+ Heavies 0.16 Total 99.8 VOC Wt °% 32.56 Ib/Ib-mol Notes MW, and mass fractions provided by source. More conservative than previous issuance and more conservative than gas analysis used for glycalc. Emissions are based on 8760 hours of operation per year. This volume is derived from piping and instrumentation diagrams of the compressors. 18WE1084.CP1.xlsm Section 01- Administrative Information Emissions Summary Emission Factors Separator Venting Pollutant Uncontrolled Controlled Emission Factor Source (lb/MMscf) (Ib/MMscf) VOC 20523.9683 20523.9683 Benzene 69.3377 69.3377 Toluene 37.8206 37.8206 Ethylbenzene 0.0000 0.0000 Mass Balance Xylene 6.3034 6.3034 n -Hexane 403.4195 403.4195 224 TMP 0.0000 0.0000 Pollutant Primary Control Device Emission Factor Source Uncontrolled Uncontrolled (lb/MMBtu) lb/MMscf (Waste Heat Combusted) (Gas Throughput) PM10 PM2.5 SOx NOx CO Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) PM10 PM2.5 0.00 0.00 0.00 0.00 0.00 0 0.00 0.00 0.00 0.00 0.00 0 SOx 0.00 0.00 0.00 0.00 0.00 0 NOx 0.00 0.00 0.00 0.00 0.00 0 VOC 0.00 0.00 0.00 1.85 1.85 314 CO 0.00 0.00 0.00 0.00 0.00 0 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene 0 0 0 12 12 Toluene Ethylbenzene Xylene n -Hexane 224 TMP 0 0 0 7 7 0 0 0 0 0 0 0 0 1 1 0 0 0 73 73 0 0 _ 0 0 0 Section 06 - Regulatory Summary Analysis AQCC Regulation 2 _ Section LA applies to all 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." Section 08 - Technical Analysis Notes Source mass balance is taken from a Promax model of the entire facility. This is a low -emitting source with a reasonable assumption of VOC content. I will not require gas sampling. Source will track blowdown events and blowdown volumes based on the actual as -built design of the facility. 18WE1084.CP1.xlsm Glycol Dehydrator Emissions Inventory 008 Dehydrator Facility AIRs ID: 123 County 9FFF Plant 008 Point Section 02 - Equipment Description Details Dehydrator Information Dehydrator Type: Make: Model: Serial Number: Design Capacity: Recirculation Pump Information Number of Pumps Pump Type Make: Model: Design/Max Recirculation Rate: Dehydrator Equipment Flash Tank Reboiler Burner Stripping Gas Dehydrator Equipment Description Emission Control Device Description: t"riethyieneg:;fc'oiT.K>i) Propak 86039 TBD 25 Kim ray 21020 PV 3.5 MMscf/day gallons/minute , flash tank, and reboiler burner Stripping gas is injected into the reboiler. One (1) Triethylene glycol (TEG) natural gas dehydration unit (Make: Propak, Model: 86039, Serial Number: TBD) with a design capacity of 25 MMscf per day. This emissions unit is equipped with 1 (Make: Kimray, Model: 21020 PV) gas driven glycol pump with a design capacity of 3.5 gallons per minute. This dehydration unit is equipped with a still vent, flash tank, and reboiler burner. Stripping gas is injected into the reboiler. Emissions from the still vent are routed to an air-cooled condenser, and then to the Enclosed Flare. Emissions from the flash tank are routed directly to the Vapor Recovery Unit (VRU). Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Dehydrator Still Vent and Flash Tank (if present) Requested Permit Limit Throughput = 9,125.0 MMscf per year Requested Monthly Throughput = 775 MMscf per month Potential to Emit (PTE) Throughput = 9,125 MMscf per year Secondary Emissions - Combustion Device(s) for Air Pollution Control Still Vent Control Condenser: Condenser emission reduction claimed: Primary control device: Primary control device operation: Secondary control device: Secondary control device operation: Still Vent Gas Heating Value: Still Vent Waste Gas Vent Rate: Flash tank Control Primary control device: Primary control device operation: Secondary control device: Secondary control device operation: Flash Tank Gas Heating Value Flash Tank Waste Gas Vent Rate: Nocrr^.;toi 8760 hr/yr Requested Condenser Outlet Temperature: 95t Control Efficiency % Requested TO Temp Control Efficiency % 120 hr/yr 1300 Btu/scf 1.04E+03 scfh Jana fc ccr: foi hr/yr JAM 100% Control Efficiency % Control Efficiency % hr/yr 1626 Btu/scf 3.56E+02 scfh Section 04 - Emissions Factors & Methodologies Dehydrator No representative sample is being used. Source will be required to have initial and ongoing sampling of inlet gas. Input Parameters Inlet Gas Pressure Inlet Gas Temperature Requested Glycol Recirculate Rate psig deg F gpm STILL VENT Control Scenario Primary Secondary Controlled (lb/hr) Pollutant Uncontrolled (lb/hr) Controlled (lb/hr) VOC 27.9157 1.3476 27.9157 Benzene 2.8428 0.141 2.8428 Toluene 2.1175 0.1038 2-1175 Ethylbenzene 0.2059 0.0099 0.2059 Xylenes 0.5468 0.026 0.5468 n -Hexane 0.5863 0.0292 0.5863 224-TMP 0.0003 0.000015 0.0003 FLASH TANK Control Scenario Primary Secondary Pollutant Uncontrolled (lb/hr) Controlled (lb/hr) Controlled (lb/hr) VOC 45.7077 0 45.7077 Benzene 0.5338 0 0.5338 Toluene 0.2735 0 0.273S Ethylbenzene 0.0163 0 0.0163 Xylenes 0.0296 0 0.0296 n -Hexane L0371 0 1.0371 224 -TM P 0.0005 0 0.0005 Degrees F Degrees F Flash Tank Primary Control: Flash Tank Secondary Control: Waste Gas Combusted: Flash Tank Primary Control: Flash Tank Secondary Control: Still Vent Primary Control: Still Vent Secondary Control: Waste Gas Combusted: Still Vent Primary Control: Still Vent Secondary Control: Dry Gas Throughput: 9,125.0 MMscf/yr 0.0 MMscf/yr 9.1 MMscf/yr 0.0 MMscf/yr 11,843.5 Dry Gas Throughput: 9,125.0 MMscf/yr 0.0 MMscf/yr 0.0 MMscf/yr 0.0 MMscf/yr 17,765.3 775.0 0.8 Glycol Dehydrator Emissions Inventory Emission Factors Glycol Dehydrator Pollutant Uncontrolled Controlled (lb/MMscf) (lb/MMscf) Emission Factor Source (Dry Gas Throughput) (Dry Gas Throughput) VOC 136.02 is; GlyCalr. 4.0 Benzene 4.862304 0.20304 GlyC.alc4.0 Toluene 3.44304 0.149472 GlyCalr.4.0 Ethylbenzene 0.319968 0.014256 GlyCalr 4.0 Xylene 0.830016 0.03744 GiltCals 4.0 n -Hexane 2.337696 0.042048 GlyCalc 4.0 224 TMP 0.001152 0.0000216 GlyCals 4.0 Pollutant Still Vent Primary Control Device Uncontrolled Uncontrolled (lb/MMBtu) (lb/MMscf) Emission Factor Source (Waste Heat Combusted) (Waste Gas Combusted) PM10 0.0075 9.6863 AP -4i TTaie L4•2 (PM1QJPM.2.5) AP -42 Table L4-2 (PMI0/PM.2.51 AP -42 Table 1A-2 (SOX) AP -42 Chapter 133 Industrial Flares (NOx) AP -42 Cheptec 13.5 Industrlaa Flares (C.-: PM2.5 0.0075 9.6863 SOx 0.0006 0.7647 NOx 0.0680 88.4000 CO 0.3100 403.0000 Still Vent Secondary Control Device Emission Factor Source Uncontrolled Uncontrolled Pollutant (lb/MMBtu) (lb/MMscf) (Waste Heat Combusted) (Waste Gas Combusted) PM10 0.0000 PM2.5 0.0000 SOx 0.0000 NOx 0.0000 CO 0.0000 Flash Tank Primary Control Device Emission Factor Source Uncontrolled Uncontrolled Pollutant (lb/MMBtu) (Ib/MMscf) (Waste Heat Combusted) (Waste Gas Combusted) PM10 0.0000 PM2.5 0.0000 SOx 0.0000 NOx 0.0000 CO 0.0000 Flash Tank Secondary Control Device Emission Factor Source Uncontrolled Uncontrolled Pollutant (lb/MMBtu) (lb/MMscf) (Waste Heat Combusted) (Waste Gas Combusted) PM10 0.0000 PM2.5 0.0000 / SOx 0.0000 NOx 0.0000 CO 0.0000 Section 05 - Emissions Inventory Did operator request a buffer? Requested Buffer (%): Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) PM10 PM2.5 SOx NOx CO VOC 0.1 0.1 0.1 0.1 0.1 11 0.1 0.1 0.1 0.1 0.1 11 0.0 0.0 0.0 0.0 0.0 1 0.6 0.6 0.6 0.60 0.6 103 2.8 2.8 2.8 2.75 2.8 468 483.7 483.7 8.9 483.7 8.9 1504 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene 44369 44369 1853 44369 1853 Toluene 31418 31418 1364 31418 1364 Ethylbenzene 2920 2920 130 2920 130 Xylene 7574 7574 342 7574 342 n -Hexane 21331 21331 384 21331 384 224 TMP 11 11 0 _ 11 0 Section 06- Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XVII.B,D Dehydrator is subject to Regulation 7, Section XVII, B, D.3 Regulation 7, Section XVII.B.2.e Not enough information Regulation 7, Section XII.H Dehydrator is subject to Regulation 7, Section XII.H Regulation 8. Part E. MACT Subpart HH (Area) The dehy unit meets the benzene exemption Regulation 8, Part E, MACT Subpart HH (Major) You have indicated that this facility is not subject to Major Source requirements of MACT HH. Regulation 8, Part E, MACT Subpart HHH You have indicated that this facility is not subject to MACT HHH. (See regulatory applicability worksheet for detailed analysis) Glycol Dehydrator Emissions Inventory Section 07 - Initial and Periodic Sampling and Testing Requirements Was the extended wet gas sample used in the GlyCalc model/Process model site -specific and collected within a year of application submittal? If no, the permit will contain an "Initial Compliance" testing requirement to demonstrate compliance with emission limits Does the company request a control device efficiency greater than 95% for a flare or combustion device? No If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling If the company has requested a control device efficiency greater than 95%, is a thermal oxidizer or regenerative thermal oxidizer being used to achieve it? If yes, the permit will contain a condition specifying the minimum combustion chamber temperature for the thermal oxidizer Is the company using a thermal oxidizer AND requesting a minimum combustion chamber temperature lower than 1,400 degrees F? No Nct If yes, the permit will contain an "Initial Compliance" testing requirement AND a permit condition specifying the minimum combustion chamber temperature for the thermal oxidizer. 08 - Technical Analysis Notes Points 008 & 009 are identical dehydrators. Source has submitted a Promax model for the entire facility, with the wet gas stream predicted by the model. I have requested that the source send me a Glycalc report, which will confirm that benzene emissions fall below the benzene exemption. Source has claimed that the Glycalc results show lower emissions than the promax, so I am allowing the Promax to serve as the basis of the requested dehydrator emissions rather than the promax, although Glycalc will be required for ongoing compliance. The source has seemingly given post -condenser emissions as "uncontrolled" for the still vent. I am requesting that the source give the pre -condenser emission rates to serve as the basis for uncontrolled emissions. Source has sent Glycalc run to replace Promax, and asked to apply a buffer to emissions. Source has specified a 50% buffer to be applied to both primary and secondary emissions. Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 008 Process # 01 SCC Code Uncontrolled Pollutant Emissions Factor Control % Units PM10 0.015 0.0 lb/MMscf PM2.5 0.015 0.0 lb/MMscf SOx 0.001 0.0 Ib/MMscf NOx 0.132 0.0 lb/MMscf VOC 106.0 98.2 Ib/MMscf CO 0.604 0.0 Ib/MMscf Benzene 4.862 95.8 lb/MMscf Toluene 3.443 95.7 lb/MMscf Ethylbenzene 0.320 95.5 Ib/MMscf Xylene 0.830 95.5 lb/MMscf n -Hexane 2.338 98.2 Ib/MMscf 224 TM P 0.001 98.1 lb/MMscf Dehydrator Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements Source is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? You have indicated that source is in the Non -Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.2)? Yes Yes Source requires a permit Colorado Regulation 7, Section XII.H 1. Is this glycol natural gas dehydrator located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area (Reg 7, Section XII.H.1 and 2)? 2. Is this glycol natural gas dehydrator located at an oil and gas exploration and production operation', natural gas compressor station, natural gas drip station or gas -processing plant (Reg 7 Section 3. Is the sum of actual uncontrolled emissions of VOC from any single dehydrator or group of dehydrators at a single stationary source equal to or greater than 15 tpy (Reg 7, Section XII.H.3.b)? 4. Are actual uncontrolled emissions of VOC from the individual glycol natural gas dehydrator equal to or greater than 1 tpy (Reg 7, Section XII.H.3.a)? Yes Yes Dehydrator is subject to Regulation 7, Section XII.H Section XII.H — Emission Reductions from glycol natural gas dehydrators MACT Analysis 1. Is the dehydrator located at an oil and natural gas production facility that meets either of the following criteria: a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)); OR A facility that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final b. end user2 (63.760(a)(3))? 2. Is the dehydrator located at a facility that is a major source for HAPs? Yes Go to MACT HH Area Source Requirement section to determine MACT HH applicability 40 CFR, Part 63, Subpart MACT HH, Oil and Gas Production Facilities Area Source Requirements 1. Is the dehydrator a triethylene glycol (TEG) dehydration unit (63.760(b)(2))? Exemptions 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per day (63.764(e)(1)(i)? 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr (63.764(e)(1)(ii)? 3. Is the unit located inside of a UA plus offset and UC boundary area? Yes No Yes The dehy unit meets the benzene exemption Subpart A, General provisions per §63.764 (a) Table 2 §63.765 - Emissions Control Standards Do Not Apply §63.773 - Monitoring Standards Do Not Apply §63.774 - Recordkeeping §63.775 - Reporting Standards Do Not Apply Major Source Requirements Does the facility have a facility -wide actual annual average natural gas throughput less than 0.65 MMscf/day AND a facility -wide actual annual average hydrocarbon liquid throughput less than 249.7 Small or Large Dehy Determination 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 3.001747 MMscf per day (63.761)? 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr (63.761)? Small Dehy Requirements 3. Did construction of the small glycol dehydration unit commence on or before August 23, 2011 (63.760(b)(1)(i)(B) and (C )? 4. For this small dehy, is a control device required to meet the BTEX emission limit given by the applicable equation? You have indicated that this facility is not subject to Major Source requirements of MACT HH. Subpart A, General provisions per §63.764 (a) Table 2 §63.765 - Emissions Control Standards §63.773 - Monitoring §63.774 - Recordkeeping §63.775 - Reporting 40 CFR, Part 63, Subpart MACT HHH, Natural Gas Transmission and Storage Facilities 1 Is the facility wide actual annual average natural gas throughput less than 0.9994051 MMscf/day and glycol dehydrators the only HAP emission source (63.1270(f))? Small or Large Dehy Determination 2a. Is the actual annual average flowrate of natural gas to the glycol dehydration unit less than 9.994051 MMscf per day (63.1270(b)(2))? 2b. Are actual annual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere less than 1,984.2 lb/yr (63.1270(b)(2))? Small Dehy Requirements 3. Did construction of the small glycol dehydration unit commence on or before August 23, 2011 (63.1270(b)(2) and (3) )? 4. For this small dehy, is a control device required to meet the BTEX emission limit (standard?) given by the applicable equation? You have indicated that this facility is not subject to MACT HHH. Subpart A, General provisions per §63.1274 (a) Table 2 §63.1275 - Emissions Control Standards §63.1281 -Control Equipment Standards §63.1283 - Inspection and Monitoring §63.1284 - Record keeping §63.1285 - Reporting Colorado Regulation 7, Section XVII.D 1. Is the denydrator subject to an emissions control requirement under MACT HH or HHH (Regulation 7, Section XVII.B.5)? 2. Is this dehydrator located at a transmission/storage facility? 3. Is this dehydrator located at an oil and gas exploration and production operation , natural gas compressor station or gas processing plant (Reg 7, Section XVII.D.3)? 4. Was this glycol natural gas dehydrator constructed before May 1, 2015 (Reg 7 Section XVII.D.4.b)? If constructed prior to May 1, 2015, are uncontrolled actual emissions from a single glycol natural gas dehydrator equal to or greater than 6 tons per year VOC or 2 tpy VOC if the 4a. dehydrator is located within 1,320 feet of a building unit or designated outside activity area (Reg 7, Section XVII.D.4.b)? S. If constructed on or after May 1, 2015, are uncontrolled actual emissions from a single glycol natural gas dehydrator equal to or greater than 2 tpy VOC (Regulation 7, Section XVII.D.4.a)? No No Yes No Dehydrator is subject to Regulation 7, Section XVII, B, D.3 Section XVII.B - General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section X ✓II.D.3 - Emissions Reduction Provisions Alternative Emissions Control (Optional Section) 6. Is this glycol natural gas dehydrator controlled by a back-up or alternate combustion device (i.e., not the primary control device) that is not enclosed? Not enough information Section XVII.B.2.e - Alternative emissions control equipment Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act; , its implementing regulations, and Air Quality Control Commission regulations. the language of the statute or regulation will control. The use of non -mandatory language such as "recommend." "may," -should," and "can,- is intended to describe APCD interpretations and recommendations. Mandatory terminology such as "must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations. but this document does not establish legally binding requirements in and of itself. Condensate Storage Tank(s) Emissions Inventory 010 Corndensat• Tank [Fealty AIRS ID: 123 County 9F Fa Plant 010 Point Section 022jqulpment Description Details Detailed Emissions Unit Sht(6)- 400 Obi Stop Cnndornata Storage Vaasa Description: Emission Control Device EnctmedCornbustor Description: Requested Overall VOC & HAP Control Efficiency %: 95 Section 03 - Processing Rata Information for Emissions Estimates PrimaryEmissions - St orago Tani4 s) Actual Condensate Throughput = `Requested Permit Limit Throughput = 275 Barrels (bbl) per year 38a17K Barrels (bbl) per year Potential to Emit (PTE) Condensate Throughput= 161,314 Barrels (bbl) per year Secondary Emissions - Combustion Devices) Heat content of waste gas = 2384 Btu/scf Volume Of waste gas emitted per BBL of liquids produced = 62.5 scf/bbl Actual heat content of waste Ras routed to combustion device = Requested heat content of waste Ras routed tc combustion device . Potential to Emit (PIE) heat content of waste gas routed to combustion device Sadism (14_E missions Factors & Methodologies yrt,�IsE..n Will this storage tank emit flash emissions? Actual Condensate Throughput While Emissions Controls Operating = Requested Monthly Throughput = 13875 Barrels (bbl) per month 0 MMBTU per year 24,343 MMBTU per year 24.343 MMBTU per year Emission Factors Condensate Tank Emission Factor Source Pollutant Uncontrolled Controlled (Ile/bbl) (lb/bbl) (Condensate Throughput) (Condensate Throughput) VOC S 31 0.J Spa %peek E f. (c•+ri rosto Inv., Sit •Swcscalt 61.fkewlap.tr.?) $Tte tyrr'N'c ul.(fnclu4es P,ur; 1ReSpecoit CI. (*chides•^tato' Zcs*SptcATtt.F,(tn itiNet ,40..i 7rte:cocm.LF.iiHct`lases: Fete 3pec is g.F,tirlezudaetAszt) Benzene 0.024 0.001 Toluene 0.012 0.001 Ethylbenzono 0201 0.003 Xyleno 0002 0.000 n -Hexane 0.135 0.007 224 TMP 0.000 0.000 Control Device Emission Factor Source Uncontrolled Uncontrolled Pollutant (Ib/MMBtu) (lb/bbl) (waste heat combusted) (Condensate Throughput) PM10 0.0075 ., 1 . Aral Table 1.4-2 }FM10/PSA1.5i 4P4 Val IA -2 (PM1s31Prat2.5J AP47 Chapter 133 ratba rAl Mats (NOKi /s. •42 carve.' 13.3 indistr,t$ flares (C!„) .. PM2.5 0-007, _ _ .. NO* &ONO o :: CO 03100 0 0.2b; Section 05 - EntiMi its Myent ry Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Units Uncontrofled Controlled (tons/year) (torts/year) Requested Monthly Units Controlled fibs/month) VOC PM10 PM2.5 NO* CO 433.9 0.0 0.0 433.9 21.7 3686 i 0.1 0.0 0.0 0.1 0.1 13 01 0.0 0.0 0.1 0: 15 0.3 0.0 0.0 023 0.3 141 1 8 0.0 0.0 3.g _ 3.8 MI Hazardous Air Pollutants potential to Emit Uncontroted Ilbs/year) Actual Emissions incontroled Controlled Iles/yaerl Ilbs/yearl Requested Permit Limits Uncontrolled Controlled (bs/year) fibs/year) Benzene Toluene Ethylbenzene Kylene . :43E. 0 3 3356 193 1444 0 0 1944 97 L. 0 0 131 ? 0 0 245 ._ n-Hoxano ..'2? 0 0 22023 1.=I 224 TMP 0 0 16 • Section 06 - Rotolatory Summary Analysis Regulation 3, Part A, B Source requires a permit Regulation 7, Section XII.C, 0, E. c Storagetank is subject to Regulation 7 Section .XII.C-F Regulation 7, Section XII.G, C Etcram Tank is not subject to Regulation 7, Section X11.6 Regulation 7, Section XVII9, C.1, C3 Storage tank is subject to Raetnlatlon 7, Section XVII, 8, Cl & C.3 Regulation 7. Section XVII.C.2 St redo tank 'a subject to Regulation 7 Section XVII.C.2 Regulation 6, Part A, NSPS Subpart Kb 3t :. -ago Tank is not suOiact to NSPS Kb Regulation 6, Part A, NSPS Subpart 0000 St cage Tank is not subject to NSPS 0000 Regulation 8, Part E, MACT Subpart HH Storage Tank is not subject to MAC it ii 1 Sae regulatory applicability worksheet for detailed anatysk) Barrels (bbl) per year I Staicn107 - Initial and. Per(odic_bmtdlntiodt*intli t ltrents Does the company use the state default emissions factors to estimate emissions? IIIIIIII If yes, are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? If yes, the permit will contain an "Initial Convince" testing requirement to develop a site specific emission factor based on guidelines in PS Memo 05-01. Does the company use a site specific emissions factor to estimate emissions? ryse.y: • ; If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facaity being permitted? This sample should be consdered representative which generally means site -specific and collected within one year of the application received date. However, If the facility has not been modified (e.g., no new wells brought online), then it may be appropriate to use an older site -specific sample. If no, the permit wal contain an "Initial Compliance testing requirement to develop a site specific emissions factor based On (oldies In PSNMm005.O1. Does the company request a control device efficient, greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device band on Wet and outleteoneenaataon sampling Sod ion 08 - Technical Analysis Notes Source used a Promo: model to estimate the entire tacility. Source has clarified that condensate from these tanks has flashed previously at well -sites, and that most of the liquid In the incoming stream Is water . I believe that the source estimation is rather :onservative in this light as source has modeled this as a flashing stream in order to be conservative. and I do not believe that testing makes sense, and according to the source, may not be feasible to let a reliable pressurized sample. Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point N 010 Process N SCC Code Pollutant PM10 PM 2.3 NO: VOC CO Benzene Toluene Ethylbenzene Xylene nHevane .'"24TMP Uncontrolled Emissions Factor 0.03 0.03 0.24 126.5 1.10 036 0.28 0.02 0.04 3.21 0.00 Control% Units 0 lb/1,000 gallons condensate throughput 0 lb/1,000 gallons condensate throughput 0 lb/1.000 gallons condensate throughput 95 lb/1.000 gallons condensate throughput 0 lb/1.000 gallons condensate throughput 95 lb/1,000 gallons condensate throughput 95 lb/1.000 gallons condensate throughput 95 lb/1.000 gallons condensate throughput 95 lb/1.000 gallons condensate throughput 95 lb/1.030 gallons condensate throughput 95 lb/1000 gallons condensate throughput 90(16 K:\PA\21718\18W E 1084.CPl.xlsm Condensate Tank Regulatory Analysis Worksheet Colorado Re ulation 3 Parts A and B - APEN and Permit Re uirements _ source is in the Non Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the constriction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total fac.lity uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part 8, Section II.D3)? You have indicated that source is in the Non -Attainment Area Yes NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.2)? Source requires a permit No Colorado Regulaion 7, Section XII.C-F 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at an oil and gas exploration and production operation', natural gas compressor station or natural gas drip station? 3. Is this storage tank located upstream of a natural gas processing plant? Storage tank is subject to Regulation 7, Section XII.C-F Yes Yes Yes Section XII C.1 — General Requirements for Air Pollution Control Equipment — Prevention of Leakage Section XII Cl - Emission Estimation Procedures Section XII.D - Emissions Control Requirements Section XII.E - Monitoring Section XII.F - Recordkeeping and Reporting Colorado Regulaton 7, Section XII.G 1. Is this storage tank located in the 8 -hr ozone control area or any ozone non -attainment area or attainment/maintenance area? 2. Is this storage tank located at a natural gas processing plant? 3. Does this storage tank exhibit "Flash" (e.g. storing non -stabilized liquids) emissions and have uncontrolled actual emissions greater than or equal to 2 tons per year VOC? Storage Tank is not subject to Regulation 7, Section XII.G Section XII.G3 - Emissions Control Requirements Section XII.C._ - General Requirements for Air Pollution Control Equipment - Prevention of Leakage Section XII.C.2 — Emission Estimation Procedures Colorado Regulation 7, Section XVII 1. Is this tank looted at a transmission/storage facility? 2. Is this condensate storage tank' located at an oil and gas exploration and production operation , well production facility2, natural gas compressor station3 or natural gas processing plant? 3. Is this condensate storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions` of this storage tank equal to or greater than 6 tons per year VOC? Storage tank is subject to Regulation 7, Section XVII, B, C.1 & C.3 Section XVII.B — General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.C.1 - Emissions Control and Monitoring Provisions Section XVII.C3 - Recordkeeping Requirements 5. Does the condensate storage tank contain only "stabilized" liquids? Yes Yes No No Yes Yes Yes No Storage tank is subject to Regulation 7, Section XVII.C.2 Section XVII.C2 • Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels 1. Is the individual storage vessel capacity greater than or equal to 75 cubic meters (m3) (-472 BBLs]? 2. Does the storage vessel meet the following exemption in 60.111b(d)(4)? a. Does the vessel has a design capacity less than or equal to 1,589.874 m3 (-10,000 BBL] used for petroleum' or condensate stored, processed, or treated prior to custody transfer2 as defined in 60.11lb? 3. Was this condensate storage tank constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after July 23, 1984? 4. Does the tank neet the definition of "storage vessel"3 in 60.11lb? 5. Does the storage vessel store a "volatile organic liquid (VOL)" as defined in 60.111b? 6. Does the storage vessel meet any one of the following additional exemptions: a. Is the storage vessel a pressure vessel designed to operate in excess of 204.9 kPa (`29.7 psi] and without emissions to the atmosphere (60.110b(d)(2))?; or b. The design capacity is greater than or equal to 151 m3 (-950 BBL; and stores a liquid with a maximum true vapor pressure' less than 33 kPa (60.110b(b))?; or c. The design capacity is greater than or equal to 75 M3 (`472 BBL] but less than 151 m1 (^950 BBL] and stores a liquid with a maximum true vapor pressure' less than 15.0 kPa(60.110b(b))? No Source Req Go to next Source Req Continue -' Continue -' Source is st Continue - Storage Tar Continue -' Go to then Go to then Source is st Source is st Storage Tar Storage Tank is not subject to NSPS K Subpart A, General Provisions §60.112b - Emissions Control Standards for VOC §60.113b - Test ng and Procedures §60.115b - Reporting and Recordkeeping Requirements §60.116b - Monitoring of Operations 40 CFR, Part 60, Subpart 0000, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Is this condensate storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this condensate storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015? 3. Are potential VCC emissions2 from the individual storage vessel greater than or equal to 6 tons per year? 4. Does this condensate storage vessel meet the definition of "storage vessel" per 60.5430? 5. Is the storage vessel subject to and controlled in accordance with requirements for storage vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Subpart HH? Storage Tank is not subject to NSPS 0000 Yes Nu Subpart A, Gene -al Provisions per §60.5425 Table 3 §60.5395 - Emissions Control Standards for VOC §60.5413 - Testing and Procedures §60.5395(g) - Notification, Reporting and Recordkeeping Requirements 460.5416(c) - Cover and Closed Vent System Monitoring Requirements §60.5417 - Control Device Monitoring Requirements [Note: If a storage vessel is previously determined to be subject to NSPS 0000 due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS 0000 per 60.5365(e)(2) even if potential VOC emissions drop below 6 tons per year) 40 CFR, Part 63, Subrart MACT HH, Oil and Gas Production Facilities 1. Is the storage tanK located at an oil and natural gas production facility that meets either of the following criteria: a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)); OR b. A facilty that processes, upgrades or stores natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end user3 (63.760(a)(3))? 2. Is the tank located at a facility that is major' for HAPs? 3. Does the tank meet the definition of "storage vessel"` in 63.761? 4. Does the tank meet the definition of "storage vessel with the potential for flash emissions"' per 63.761? 5. Is the tank subject to control requirements under 40 CFR Part 60, Subpart Kb or Subpart 0000? Storage Tank is not subject to MACT HH Subpart A, General provisions per §63.764 (a) Table 2 §63.766 - Emissions Control Standards §63.773 - Monitoring §63.774 - Recordkeeping §63.775 - Reporting RACT Review RACT review is reouired if Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets both criteria, then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act. its implementing regulations. and Air Quality Control Commission regulations. This document is not a rale or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable In the event of any conflict between the language of this document and the language of the Clean Air Act., its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as 'recommend," 'may.' 'should' and 'can,' is intended to describe APCD interpretations and recommendations Mandatory terminology such as 'must' and 'required` are intended to describe controlling requirements under the terms of the Clean Air Act and kit Quality Control Commission regulations. but this document does not establish legally binding requirements in and of itself Continue Storage Tar Continue -' Storage Tar Hydrocarbon Loadout Emissions Inventory 011 Liquid Loading Facility AIRs ID: 123 9F1F 011 County Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Is this loadout controlled? Truck loadout of slop condensate No Control 0.00 Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Hydrocarbon Loadout Actual Volume Loaded = Barrels (bbl) per year Actual Volume Loaded While Emissions Controls Operating = Requested Permit Limit Throughput = 24,000 Barrels (bbl) per year Requested Monthly Throughput = 2038 Barrels (bbl) per month Potential to Emit (PTE) Volume Loaded = Secondary Emissions - Combustion Device(s) 28,800 Barrels (bbl) per year Section 04 - Emissions Factors & Methodologies Does the company use the state default emissions factors to estimate emissions? Are the emissions factors based on a stabilized hydrocarbon liquid sample drawn at the facility being permitted? Loading Loss Equation L = 12.46*S*P*M/T No MMBTU per year MMBTU per year MMBTU per year Barrels (bbl) per year A site specific stabilized hydrocarbon liquid sample must be provided to develop a site specific emissions factor. Factor Meaning Value Units Source S saturation Factor 0.6 "Y - l AP -42 Chapter 5.2 Table 5.2-1 Submerged Lc_. - - Dedicated florrr'a1Sendc-. P True Vapor Pressure 5.0032 psia M Molecular Weight of Vapors 66 Ib/Ib-mol T Liquid Temperature 515.83 Rankine L Loading Losses 4.785799452 lb/1000 gallons 0.201003577 lb/bbl Component Mass Fraction Emission Factor Units Source Benzene 0.01517 0.003049224 lb/bbl From Promax - Slop Condensate Tank Liquids Toluene 0.028 0.0056281 lb/bbl From Promax - Slop Condensate Tank Liquids Ethylbenzene 0.00631 0.001268333 lb/bbl From Promax - Slop Condensate Tank Liquids Xylene 0.01264 0.002540685 lb/bbl From Promax - Slop Condensate Tank Liquids n -Hexane 0.0836 0.016803399 lb/bbl From Promax - Slop Condensate Tank Liquids 224 TMP 0.0011 0.000221104 lb/bbl From Promax - Slop Condensate Tank Liquids Emission Factors Hydrocarbon Loadout Emission Factor Source Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) (Volume Loaded) (Volume Loaded) VOC 2.01E-01 2.01E-01 Site Specific - AP -42: chapter 5.2, Equation 1 Site Specific - AP -42: Chapter 5.2, Equation 1 `cite Specific - AP -42: Chapter 5.2, Equation 1 Site Specific - AP -42: Chapter 5,2, Equation 1 -�- ite Specific - AP -42: Chapter 5.2, Equation 1 Site Specific - AP -42: Chapter 5.2, Equation 1 ",P-42: Chapter 5.2, Equation 1 Benzene 3.05E-03 3.05E-03 Toluene 5.63E-03 5.63E-03 Ethylbenzene 1.27E-03 1.27E-03 Xylene 2.54E-03 2.54E-03 n -Hexane 1.68E-02 1.68E-02 224 TMP 2.21E-04 2.21E-04 Control Device Emission Factor Source Uncontrolled Uncontrolled Pollutant (lb/MMBtu) (lb/bbl) (waste heat combusted) (Volume Loaded) PM10 0.00E+00 PM2.5 0.00E+00 SOx 0.00E+00 NOx 0.00E+40 CO 0.00E+00 11 of 16 K:\PA\2018\18WE1084.CP1.xlsm Hydrocarbon Loadout Emissions Inventory Section OS - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) PM 10 0.00 0.00 0.00 0.00 0.00 0 PM2.5 SOx NOx VOC CO 0.00 0.00 0.00 0.00 0.00 0 0.00 0.00 0.00 0.00 0.00 0 0.00 0.00 0.00 0.00 0.00 0 2.89 0.00 0.00 2.41 2.41 410 0.00 0.00 0.00 0.00 0.00 0 Hazardous Air Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 88 0 0 73 73 162 0 0 135 135 37 0 0 30 30 73 0 0 61 61 484 0 0 403 403 224 IMP 6 0 0 5 5 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit RACT - Regulation 3, Part B, Section III.D.2.a The loadout must be operated with submerged fill to satisfy RACT. (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testing Requirements You have indicated above the source is not controlled. The following question does not require an answer. Section 08 - Technical Analysis Notes Source has submitted emission calculations using Promax, based on assumptions from slop tank condensate. Emission factor is high, but lower than state EF. Given the non -flashing nature and conservative emissions for the condensate (Point 010), I am accepting these emissions. I have used a different basis for HAP estimation than the source; source initially used modeled "flashing" gas, however, I have used the pressurized stream from Promax as a basis for HAPs, as it has a higher concentration, and I expect more heavier species to remain in the liquid over time. Emissions are low and source is uncontrolled. For this low of emissions, submerged fill loading is sufficient for RACT. Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 011 Process # 01 SCC Code 4-06-001-32 Crude Oil: Submerged Loading Normal Service (S=0.6) Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 lb/1,000 gallons transferred PM2.5 0.00 0 lb/1,000 gallons transferred SOx 0.00 0 lb/1,000 gallons transferred NOx 0.00 0 lb/1,000 gallons transferred VOC 4.8 0 lb/1,000 gallons transferred CO 0.00 0 Ib/1,000 gallons transferred Benzene 0.07 0 lb/1,000 gallons transferred Toluene 0.13 0 lb/1,000 gallons transferred Ethylbenzene 0.03 0 lb/1,000 gallons transferred Xylene 0.06 0 lb/1,000 gallons transferred n -Hexane 0.40 0 lb/1,000 gallons transferred 224 TMP 0.01 0 lb/1,000 gallons transferred 12 of 16 K:\PA\2018\18WE1084.CP1.xlsm Hydrocarbon Loadout Regulatory Analysis Worksheet Colorado Regulation 3 Parts A and B - APEN and Permit Requirements Source is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section 11.0.1.1)? 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? 4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill? 5. Is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 6. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? You have indicated that source is in the Non -Attainment Area NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? Go to next 2. Is the loadout located at an exploration and production site (e.g., well pad) (Regulation 3, Part B, Section II.D.1.1)? Go to ques' 3. Is the loadout operation loading less than 10,000 gallons (238 BBLs) of crude oil per day on an annual average basis? 4. Is the loadout operation loading less than 6,750 bbls per year of condensate via splash fill? 5. is the loadout operation loading less than 16,308 bbls per year of condensate via submerged fill procedure? 6. Are total fa:ility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.2)? Yes No Yep Source requires a permit 7. RACT - Are uncontrolled VOC emissions from the loadout operation greater than 20 tpy (Regulation 3, Part B, Section III.D.2.a)? No The loadout must be operated with submerged fill to satisfy RACT. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control The use of non -mandatory language such as 'recommend, "'may," "should, " and 'can, "is intended to describe APCD interpretations and recommendations Mandatory terminology such as 'must" and `required" are intended to descnbe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself The loadou The loadou Produced Water Storage Tank(s) Emissions Inventory 012 Produced Water Tank Facility AIRs ID: County 9FFF Plant 012 Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Two (2) 400 BBL produced water storage tanks Emission Control Device Enclosed combustors) Description: Requested Overall VOC & HAP Control Efficiency %: 95 Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Storage Tank(s) Actual Produced Water Throughput = Barrels (bbl) per year Actual Produced Water Throughput While Emissions Controls Operating = Requested Permit Limit Throughput = 7,300,000 Barrels (bbl) per year Requested Monthly Throughput = 620000 Barrels (bbl) per month Potential to Emit (PTE) Produced Water Throughput = Secondary Emissions - Combustion Device(s) Heat content of waste gas =_ Volume of waste gas emitted per BBL of liquids produced = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = 8,760,000 Barrels (bbl) per year 2384 Btu/scf 0.02 scf/bbl 0 MMBTU per year 348 MMBTU per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = 418 MMBTU per year Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Emission Factors Produced Water Tank Pollutant Uncontrolled Controlled (lb/bbl) (lb/bbl) Emission Factor Source (Produced Water Throughput) (Produced Water Throughput) VOC 3.23E-04 1.62E -0S Site Specific EPA TANKS E.F. Working a Benzene 0.000 Site Specific EPA TANKS E.F. Working and Breath Toluene 0.000 Site Specific EPA TANKS E.F. Working and Breath Ethylbenzene 0.000 Site Specific EPA TANKS E.F. Working and Breath Xylene 0.000 Site Specific EPA TANKS E.F.•Vtforking and Breath: n -Hexane 0.000 Site Specific EPA TANKS F.F. Vfarkinq and Break Site Specific EPA TANKS E. 224 TMP 0.000 Pollutant Control Device Emission Factor Source Uncontrolled Uncontrolled (lb/MMBtu) (lb/bbl)I (Produced Water Throughput) (waste heat combusted) PM10 0.0075 0.0000 AP -1.2 Table 1.4-2 (PM10/Prdi.2.5) AP -42 Table 1.4-2 (PM10/PM:2.S) AP -42 Chapter 13.5 Industrial Flares (NOx) AP -42 Chapter 13.5 industrial Flares (CC PM2.5 0.0075 0.0000 NOx 0.0680 0.0000 CO _ 0.3100 0.0000 Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (lbs/month) VOC 1.4 0.0 0.0 1.18 0.1 10 PM10 0.0 0.0 0.0 0.0 0.0 0 PM2.5 0.0 0.0 0.0 0.0 0.0 0 NOx 0.0 0.0 0.0 0.01 0.0 2 CO 0.1 0.0 0.0 0.05 0.1 9 Hazardous Air Pollutants Potential to Emit Uncontrolled (lbs/year) Actual Emissions Uncontrolled Controlled (lbs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (lbs/year) (lbs/year) Benzene 0 0 0 0 0 Toluene 0 0 0 0 0 Ethylbenzene 0 0 0 0 0 xylene 0 0 0 0 C n -Hexane 0 0 0 0 0 224 TMP 0 0 . 0 0 0 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Section XVII.B, C.1, C.3 Storage Tank is not subject to Regulation 7, Section XVII Regulation 7, Section XVII.C.2 Storage Tank is not subject to Regulation 7, Section XVII.C.2 Regulation 6, Part A, NSPS Subpart OOOO Storage Tank is not subject to NSPS OOOO (See regulatory applicability worksheet for detailed analysis) 14 of 16 K:\PA\2018\18WE1084.CP1.xlsm Produced Water Storage Tank(s) Emissions Inventory Section 07 - Initial and Periodic Sampling and Testing Requirements Does the company use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid water sample drawn at the facility being permitted and analyzed using flash liberation analysis? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor. See PS Memo 14-03, questions 5.9 and 5.12 for additional guidance on testing. Yes Does the company request a control device efficiency greater than 95% for a flare or combustion device? If yes, the permit will contain and initial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling Section 08 - Technical Analysis Notes Produced water from various facilities. Water has flashed previously, and only working and breathing is expected. Source calculated emissions in EPA Tanks, assuming 2% hydrocarbons (using gasoline RVP = 15), with the rest as water. This is sufficiently conservative where I will not require testing of the water to verify. In calculating combustion emissions, source has included pilot emissions (which are larger than just combustion of waste gas) and are not reportable. Section 09 - Inventory SCC Coding and Emissions Factors AIRS Point # 012 Process # SCC Code 01 4-04-003-15 Fixed Roof Tank, Produced Water, working+breathing+flashing losses Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.00 0 Ib/1,000 gallons liquid throughput PM2.5 0.00 0 Ib/1,000 gallons liquid throughput NOx 0.00 0 Ib/1,000 gallons liquid throughput VOC 0.0 95 lb/1,000 gallons liquid throughput CO 0.00 0 lb/1,000 gallons liquid throughput Benzene 0.00 95 lb/1,000 gallons liquid throughput Toluene 0.00 95 lb/1,000 gallons liquid throughput Ethylbenzene 0.00 95 lb/1,000 gallons liquid throughput Xylene 0.00 95 Ib/1,000 gallons liquid throughput n -Hexane 0.00 95 lb/1,000 gallons liquid throughput 224 TMP 0.00 95 lb/1,000 gallons liquid throughput 15 of 16 K:\PA\2018\18WE1084.CP1.xlsm Produced Water Storage Tank Regulatory Analysis Worksheet Please note that NSPS Kb might be might be applicable for certain tanks at water management and injection facilities. If the tanks you are reviewing are at one of these facilities, please review NSPS Kb. Colorado Regulation 3 Parts A and B - APEN and Permit Re uirements Source is in the Non -Attainment Area ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the operator claiming less than 1% crude oil and is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1.M) 3. Are total facility uncontrolled VOC emissions greater than S TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.3)? You have indicated that source is in the Non -Attainment Area Yes NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1 TPY (Regulation 3, Part A, Section II.D.1.a)? 2. Is the operator claiming less than 1% crude oil and is the tank located at a non-commercial facility for processing oil and gas wastewater? (Regulation 3, Part B, Section II.D.1.M) 3. Are total facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section II.D.2)? Source requires a permit No Colorado Regulation 7, Section XVII 1. Is this tank located at a transmission/storage facility? 2. Is this produced water storage tank1 located at an oil and gas exploration and production operation , well production facility?, natural gas compressor station3 or natural gas processing plant? 3. Is this produced water storage tank a fixed roof storage tank? 4. Are uncontrolled actual emissions' of this storage tank equal to or greater than 6 tons per year VOC? Storage Tank is not subject to Regulation 7, Section XVII Yes No Yes Yes Section XVII.B — General Provisions for Air Pollution Control Equipment and Prevention of Emissions Section XVII.C.1 - Emissions Control and Monitoring Provisions Section XVII.C.3 - Record keeping Requirements 5. Does the produced water storage tank contain only "stabilized" liquids? If no, the following additional provisions apply. No Storage Tank is not subject to Regulation 7, Section XVII.C.2 Section XVII.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment 40 CFR, Part 60, Subpart OOOO, Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution 1. Is this produced water storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this produced water storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2011 and September 18, 2015? 3. Are potential VOC emissions? from the individual storage vessel greater than or equal to 6 tons per year? 4. Does this produced water storage vessel meet the definition of "storage vessel"1 per 60.5430? Storage Tank is not subject to NSPS OOOO Yes No Subpart A, General Provisions per §60.5425 Table 3 §60.5395 - Emissions Control Standards for VOC §60.5413 - Testing and Procedures §60.5395(g) - Notification, Reporting and Recordkeeping Requirements §60.5416(c) - Cover and Closed Vent System Monitoring Requirements §60.5417 - Control Device Monitoring Requirements [Note: If a storage vessel is previously determined to be subject to NSPS OOOO due to emissions above 6 tons per year VOC on the applicability determination date, it should remain subject to NSPS OOOO per 60.5365(e)(2) even if potential VOC emissions drop below 6 tons per year] RACT Review RACT review is required if Regulation 7 does not apply AND if the tank is in the non -attainment area. If the tank meets both criteria, then review RACT requirements. Disclaimer This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act,, its implementing regulations. and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use of non -mandatory language such as -recommend, "'may, " "should," and "can, "is intended to describe APCD interpretations and recommendations Mandatory terminology such as 'must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations. but this document does not establish legally binding requirements in and of itself Source Req Go to next Source Req Continue -' Continue -' Go to the n Storage Tar Storage Tar Continue -' Storage Tar Summary of Preliminary Analysis - NG RICE Company Name Outrigger DJ Operating LLC Facility Name Koki Compressor Station Facility Location Sec. 26 T8N R61W Facility Equipment ID CM -220 Permit No. AIRS Review Date Permit Engineer 18WE1084 123/9 F F F/002 01/01/1900 Christian Lesniak Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) Waukesha, Model L-7044GSI, Serial Number To Be Determined, natural gas -fired, turbo -charged, 4SRB reciprocating internal combustion engine, site rated at 1576 horsepower. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control This emission unit is used for natural gas compression. Natural Gas Consumption Requested (mmscf/yr) 105.50 Requested (mmscf/m) 8.96 Fuel Heat Value (btu/scf) 1091 BSCF (Btu/ho-hr) 8337 Emission Factor Sources Hours of Operation PTE Calculated at (hpy) 8760 Permit limits calculated at (hpy) 8760 Uncontrolled Controlled NOx Manufacturer 0 VOC Manufacturer 0 CO Manufacturer 0 Formaldehyde Manufacturer 0 SOX AP -42; Table 3.2-3 (7/2000): Natural Gas No Control TSP Manufacturer No Control PM 10 Manufacturer No Control PM2.5 Manufacturer No Control Other Pollutants Describe EF sources - HAPs etc. Describe EF sources - HAPs, etc. Point Summary of Criteria Emissions (t Uncontrolled Requested Controlled Requested PTE Proposed Efficiency Control NOx 214.6 5.3 214.6 97.5% VOC 11.3 7.6 11.3 32A% CO 191.7 10.7 191.7 94.4% SOx 0.0 0.0 0.0 0.0% TSP 0.6 0.6 0.6 0.0% PM10 0.6 0.6 0.6 0.0% PM2.5 0.6 0.6 0.6 0.0% Total HAPs* 0.0 0.0 1.4 0.0% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (lb/yr HAP Name Uncontrolled Requested Controlled Requested PTE Proposed Efficiency Control Formaldehyde 1522 1522 1522 0.0% Methanol 352 352 352 0.0% Acetaldehyde 321 321 321 0.0% Acrolein 303 303 303 0.0% Benzene * 182 0.0% 1,3 -Butadiene * * 76 0.0% Toluene * * 64 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT ZZZZ New/Recon 4SRB over 500 HP located at a(n) Area Source Reg Standards 7 XVII.E (g/hp-hr) NOx: 1.0 CO: 2.0 VOC: 0.7 Reg requirements) 7 XVI.B (Ozone applies? NAA Yes MACT ZZZZ (area source) Is this source engine requirements? subject to MACT ZZZZ area Yes NSPS JJJJ Is this engine subject to NSPS JJJJ? Yes Note: been JJJJ adopted requriements into Reg are not 6. currently included as permit conditions because the reg has not Comments/Notes Multiple engines part of facility -wide permit included with other equipment for new compressor station. Engines are all same model. Emissions are per engine Spark Ignition Engine APEN Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for spark ignition (e.g. gas -fired) reciprocating internal combustion engines (RICE). If your engine is a compression ignition engine (e.g. diesel -fired) or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: AIRS ID Number: 12.3/aFFP / 002" [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Outrigger DJ Operating LLC Site Name: Koki Compressor Station Site Location: Sec. 26 T8N R61 W Mailing Address: pCode1200 17th Street, Suite 900 (Include Zip Code) Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 237120 Contact Person: Cody Kerrigan Phone Number: 720-361-2551 E -Mail Address2: ckerrigan@outriggerenergy.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 388684 COLOR ADO Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑✓ NEW permit OR newly -reported emission source (check one below) ❑✓ STATIONARY source ❑ PORTABLE source ❑✓ Request coverage under a Construction Permit O Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,875 must be submitted along with the APEN filing fee. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment ❑ Change company name4 ❑ Add point to existing permit ❑ Change permit limit 0 Transfer of ownerships ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacement6 Additional Info Et Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 5 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 6 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? If yes, provide the Company Equipment Identification No. CM -220 Yes General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.gov/cdphe/attainment) Normal Flours of Source Operation: 24 hours/day 7 TBD ✓❑ Yes ❑ No Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 days/week 52 weeks/year June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 COLORADO 2 I A� °`f'r7,7a,°in:N %.atilt _ En�Lunm.nl Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking Power 0 Emergency (max. 500 hrs/year) 0 Compression O Pump Jack ❑ Water Pump 0 Other: What is the maximum number of hours this engine will be used for emergency back-up power? hours/year Engine Make: Waukesha Engine Model: L-7044GSI Serial Number7: TBD What is the maximum designed horsepower rating? 1576 hp What is the maximum manufacturer's site -rating? 1576 hp 1,175 kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8,337 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke 4 -Stroke Combustion: ❑ Lean Burn ['Rich Burn Aspiration: 0 Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? 0 Yes ❑ No If yes, what type of AFRC is in use? ❑ O2 Sensor (mV) ❑NOx Sensor (ppm) 0 Other: Is this engine equipped with a Low-NOx design? ❑ Yes 0 No Engine Dates: What is the manufactured date of this engine? 2018 What date was this engine ordered? TBD What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? O Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 3 I AV1COLOR ADO !t==o `., Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit tt and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.62965/-104.16590 Operator Stack ID No. Discharge Height` Above Ground Level (feet) Temp. F (° ) Flow Rate ACFM) Velocity (ft/sec) CM -220 TBD 1,217 8,343 40 Indicate the direction of the Stack outlet: (check one) 0 Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 0 Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): Interior stack diameter (inches): ❑ Upward with obstructing raincap TBD interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100% Load (SCF/hour) Actual Annual Fuel Use (MMSCFI year) Requested Annual Permit Limits (MMSCF/year) 12,043 -- 105.50 From what year is the actual annual amount? Indicate the type of fuel used9: O Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑✓ Field Natural Gas Heating value: 1,091 BTU/scf ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): $ Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 4 I A al I COLORADO p_ Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes O No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.s SOx NOx NSCR/AFRC 97.5% VOC CO NSCR/AFRC 94.4% Other: Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions 10 Requested Annual Permit 8 Emission Limits) Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) TSP (PM) 0.01941 lb/MMBtu AP -42 - - 1.12 1.12 PM10 0.01941 lb/MMBtu AP -42 - - 1.12 1.12 PM2.5 0.01941 lb/MMBtu AP -42 - - 1.12 1.12 SOx 0.000588 lb/MMBtu AP -42 - - 0.03 0.03 NOx 14.10 g/hp-hr Manufacturer - - 214.58 5.33 VOC 0.74 g/hp-hr Manufacturer - - 11.26 7.61 CO 12.60 g/hp-hr Manufacturer - - 191.75 10.65 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 0 Yes ❑ No lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract (CAS) ( ) Number Emission Factor Actual Annual Emissions10 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (pounds/year) Controlled Emissions (pounds/year) 1521.82 (PTE) Formaldehyde 50000 0.05 g/hp-hr Manufacturer 1521.82 (PTE) Acetaldehyde 75070 2.79E-03 lb/MMbtu AP -42 321.13 (PTE) 321.13 (PTE) Acrolein 107028 2.63E-03 lb/MMbtu AP -42 302.71 (PTE) 302.71 (PTE) Benzene 71432 Other: Methanol 3.06E-03 lb/MMbtu AP -42 352.20 (PTE) 352.20 (PTE) 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 5 I Aay;coLoRAD0 V E.J u «t:� Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit 11 and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP02. �.y�K 10/9//2 Signature of Legally Authorized Person (not a vendor or consultant) Date Cody Kerrigan Engineering Manager Name (please print) Title Check the appropriate box to request a copy of the: ✓0 Draft permit prior to issuance E✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $1,875, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 6 I AV COLORADO Depanman:otn:rl Ha lle_ EnvItonm.r.I RECEIVED OCT - 9 2018 Spark Ignition Engine APEN Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for spark ignition (e.g. gas -fired) reciprocating internal combustion engines (RICE). If your engine is a compression ignition engine (e.g. diesel -fired) or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. APCD stationer, Permit Number: gA► l ►r 1 O AIRS ID Number: 113 '4FFF' oo 3 U V[Leave blank [unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Outrigger DJ Operating LLC Site Name: Koki Compressor Station Site Location: Sec. 26 T8N R61 W lu Address: p Code) 1200 17th Street, Suite 900 (Include Zip Code) Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 237120 Contact Person: Cody Kerrigan Phone Number: 720-361-2551 E -Mail Address2• ckerrigan@outriggerenergy.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 388685 1 I ACOLORADO V r;,_z.;•,;?n":.., Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action 0 NEW permit OR newly -reported emission source (check one below) ✓❑ STATIONARY source O PORTABLE source O Request coverage under a Construction Permit O Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,875 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name4 ❑ O Change permit limit O Transfer of ownerships O -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacement6 Additional Info Et Notes: Add point to existing permit Other (describe below) 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 5 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 6 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? If yes, provide the Company Equipment Identification No. CM -230 Yes General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: //www.colorado.gov/cdphe/attainment) Normal Hours of Source Operation: 24 hours/day 7 TBD ❑✓ Yes ❑ No Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 days/week 52 weeks/year June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 [COLORADO 2 I AV! ,4,I:o1fT,� fimUhbEnmmnm.�.l Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit 11 and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking Power 0 Emergency (max. 500 hrs/year) ❑✓ Compression ❑ Pump Jack ❑ Water Pump 0 Other: What is the maximum number of hours this engine will be used for emergency back-up power? hours/year Engine Make: Waukesha Engine Model: L-7044GSI Serial Number7: TBD What is the maximum designed horsepower rating? 1576 hp What is the maximum manufacturer's site -rating? 1576 hp 1,175 kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8,337 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke [14 -Stroke Combustion: 0 Lean Burn ✓❑ Rich Burn Aspiration: ❑ Natural D Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ✓❑ Yes 0 No If yes, what type of AFRC is in use? ❑ OZ Sensor (mV) ❑NOx Sensor (ppm) 0 Other: Is this engine equipped with a Low-NOx design? ❑ Yes [ No Engine Dates: What is the manufactured date of this engine? 2018 What date was this engine ordered? TBD What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? ❑ Yes 0 No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 COLOR ADO 3 I e _: oer�eem �i:�u:•non,..r.i Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit II and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.62965/-104.16590 Operator Stack ID No. Discharge Height Above Ground Level - "" (feet) Temp. ('F) Flow Rate (ACFM) :' Velocity (ft/sec) CM -230 TBD 1,217 8,343 40 Indicate the direction of the Stack outlet: (check one) 0 Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) 0Circular Interior stack diameter (inches): ❑ Square/Rectangle Interior stack diameter (inches): ❑ Other (describe): ❑ Upward with obstructing raincap TBD Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate ® 100% Load (SCFlhour) ;. ' Actual Annual Fuel Use (MMSCF/year) Requested Annual Permit Limits (MMSCF/year) 12,043 -- 105.50 From what year is the actual annual amount? Indicate the type of fuel used9: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) 0 Field Natural Gas Heating value: 1 091 BTU/scf 9 ❑ Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑Other (describe): Heating Value (give units): a Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 4 I A. COLORADO F:e�;lh Ewabonny,.l Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? Q✓ Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.5 SOx NOx NSCR/AFRC 97.5% VOC CO NSCR/AFRC 94.4% Other: Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions 10 Requested Annual Permit 8 Emission Limits) Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) TSP (PM) 0.01941 Ib/MMBtu AP -42 - - 1.12 1.12 PM10 0.01941 Ib/MMBtu AP -42 - - 1.12 1.12 PM2.5 0.01941 Ib/MMBtu AP -42 - - 1.12 1.12 SOX 0.000588 tb/MMBtu AP -42 - - 0.03 0.03 NOx 14.10 g/hp-hr Manufacturer - - 214.58 5.33 VOC 0.74 g/hp-hr Manufacturer - - 11.26 7.61 CO 12.60 g/hp-hr Manufacturer - - 191.75 10.65 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 Q✓ Yes ❑ No lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) NumberMfg. Emission Factor Actual Annual Emissions1° Uncontrolled Basis Units(AP-42, Source etc) Uncontrolled Emissions (pounds/year) 1521.82 (PTE) Controlled Emissions (pounds/year) 1521.82 (PTE) Formaldehyde 50000 0.05 g/hp-hr Manufacturer Acetaldehyde 75070 2.79E-03 Ib/MMbtu AP -42 321.13 (PTE) 321.13 (PTE) Acrolein 107028 2.63E-03 Ib/MMbtu AP -42 302.71 (PTE) 302.71 (PTE) Benzene 71432 Other: Methanol 3.06E-03 Ib/MMbtu AP -42 352.20 (PTE) 352.20 (PTE) 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 I � COLORADO 5 I �. ,o :Vy r„�„on,..n1 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP02. io/911e Signature of Legally Authorized Person (not a vendor or consultant) Date Cody Kerrigan Engineering Manager Name (please print) Title Check the appropriate box to request a copy of the: Q✓ Draft permit prior to issuance Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $1,875, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 6 I ®COLORADO ' Spark Ignition Engine APEN Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for spark ignition (e.g. gas -fired) reciprocating internal combustion engines (RICE). If your engine is a compression ignition engine (e.g. diesel -fired) or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. R.CENEU 9 i018 ptation3 Permit Number: AIRS ID Number: I 23 /CI FFF1 00+ 8'iNEI Ogg - [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Outrigger DJ Operating LLC Site Name: Koki Compressor Station Site Location Site Location: Sec. 26 T8N R61 W County: Weld NAICS or SIC Code: 237120 Mailing Address: (Include Zip Code) 1200 17th Street, Suite 900 Denver, CO 80202 Contact Person: Cody Kerrigan Phone Number: 720-361-2551 Portable Source E -Mail Address2: Home Base: ckerrigan@outriggerenergy.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 388686 1 I AYI COLORADO 11 1===., E Erm =., Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ✓❑ NEW permit OR newly -reported emission source (check one below) ❑ STATIONARY source ❑ PORTABLE source ❑✓ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,875 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name4 ❑ ❑ Change permit limit ❑ Transfer of ownerships ❑ -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ▪ APEN submittal for permit-exempt/grandfathered source O Notification of Alternate Operating Scenario (AOS) permanent replacement6 Additional Info Et Notes: Add point to existing permit Other (describe below) 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 5 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 6 This does not apply to General Permit GP02, as it does rut contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? If yes, provide the Company Equipment Identification No. CM -240 Yes General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: //www.colorado. Rov/cdphe/attainment) Normal Hours of Source Operation: 24 hours/day 7 TBD ❑✓ Yes ❑ No Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 days/week 52 June -Aug: 25 weeks/year Sept -Nov: 25 Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 if ICOLOfl ADO lieyrt vn: of n . in 2 I Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking Power ❑ Emergency (max. 500 hrs/year) 0 Compression O Pump Jack ❑ Water Pump O Other: What is the maximum number of hours this engine wilt be used for emergency back-up power? hours/year Engine Make: Waukesha Engine Model: L-7044GSI Serial Number: TBD What is the maximum designed horsepower rating? 1576 hp What is the maximum manufacturer's site -rating? 1576 hp 1,175 kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8,337 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke 0 4 -Stroke Combustion: ❑ Lean Burn Rich Burn Aspiration: ❑ Natural 0 Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? D Yes O No If yes, what type of AFRC is in use? O OZ Sensor (mV) ❑NOx Sensor (ppm) 0 Other: Is this engine equipped with a Low-NOx design? ❑ Yes ❑✓ No Engine Dates: What is the manufactured date of this engine? 2018 What date was this engine ordered? TBD What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? ❑ Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 COLORADO 3 I A_ a ntt� ti�FSEnui.nnm.r.� Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.62965/-104.16590 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. (`F) Flow Rate (ACFM) Velocity (ft/sec) CM -240 TBD 1,217 8,343 40 Indicate the direction of the Stack outlet: (check one) 0 Upward Horizontal Indicate the stack opening and size: (check one) Circular Square/Rectangle Other (describe): Downward Other (describe): Interior stack diameter (inches): Interior stack diameter (inches): ❑ Upward with obstructing raincap TBD Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100% Load (SCF/hour) Actual Annual Fuel Use (MMSCF/ year) Requested Annual Permit Limits (MMSCF/ year) 12,043 -- 105.50 From what year is the actual annual amount? Indicate the type of fuel used9: Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) O✓ Field Natural Gas Heating value: 1,091 BTU/scf Propane (assumed fuel heating value of 2,300 BTU/scf) Landfill Gas Heating Value: BTU/scf Other (describe): Heating Value (give units): 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 4 I A COLORADO ger.rtm�ni o!P 1 k�a1115 Er.v.31331vr1 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit U and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? p✓ Yes 0 No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.s SOX NOx NSCR/AFRC 97.5% VOC CO NSCR/AFRC 94.4% Other: Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions 10 Requested Annual Permit 8 Emission Limit(s) Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) TSP (PM) 0.01941 lb/MMBtu AP -42 - - 1.12 1.12 PM10 0.01941 lb/MMBtu AP -42 - - 1.12 1.12 PM2.s 0.01941 Ib/MMBtu AP -42 - - 1.12 1.12 SOX 0.000588 lb/MMBtu AP -42 - - 0.03 0.03 NOx 14.10 glhp-hr Manufacturer - - 214.58 5.33 VOC 0.74 g/hp-hr Manufacturer - - 11.26 7.61 CO 12.60 g/hp-hr Manufacturer - - 191.75 10.65 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 0 Yes 0 No lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract (CAS) Service CAS Number Emission Factor Actual Annual Emissions10 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (pounds/year) Controlled Emissions (pounds/year) Formaldehyde 50000 0.05 g/hp-hr Manufacturer 1521.82 (PTE) 1521.82 (PTE) Acetaldehyde 75070 2.79E-03 lb/MMbtu AP -42 321.13 (PTE) 321.13 (PTE) Acrolein 107028 2.63E-03 lb/MMbtu AP -42 302.71 (PTE) 302.71 (PTE) Benzene 71432 Other: Methanol 3.06E-03 lb/MMbtu AP -42 352.20 (PTE) 352.20 (PTE) 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 //�� COLORADO 5 Hea:t� � E�:•n�nnn.nl Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP02. /0/9// 8 Signature of Legally Authorized Person (not a vendor or consultant) Date Cody Kerrigan Engineering Manager Name (please print) Title Check the appropriate box to request a copy of the: 0✓ Draft permit prior to issuance E✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $1,875, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call:' Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 ®VICOLORADO Fea.IM E E�ulrnvn•nl Spark Ignition Engine APEN Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for spark ignition (e.g. gas -fired) reciprocating internal combustion engines (RICE). If your engine is a compression ignition engine (e.g. diesel -fired) or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Qov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 1$,v!✓' 68+' AIRS ID Number: 123 tot FFF/ 00 6 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Outrigger DJ Operating LLC Site Name: Koki Compressor Station Site Location: Sec. 26 T8N R61 W Mailing Address: (Include Zip Code) 1200 17th Street, Suite 900 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 237120 Contact Person: Cody Kerrigan Phone Number: 720-361-2551 E -Mail Address2: ckerrigan@outriggerenergy.com Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 388687 ap COLORADO 1 I • ; h:o« li.al�h b �:Wunm.�� Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑✓ NEW permit OR newly -reported emission source (check one below) ❑r STATIONARY source ❑ PORTABLE source ✓❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,875 must be submitted along with the APEN filing fee. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment O Change company name4 ❑ Add point to existing permit ❑ Change permit limit O Transfer of ownerships O Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacement6 Additional Info £t Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. .4 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 5 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 6 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? If yes, provide the Company Equipment Identification No. CM -250 Yes General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http: / /www. colorado.gov/cdphe /attainment) Normal Hours of Source Operation: 24 hours/day 7 TBD ❑✓ Yes ❑ No Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 days/week 52 weeks/year June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 !COLORADO 2 I - H`uiM1in EEr:n rnn ni Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking Power 0 Emergency (max. 500 hrs/year) ❑✓ Compression ❑ Pump Jack 0 Water Pump ❑ Other: What is the maximum number of hours this engine will be used for emergency back-up power? hours/year Engine Make: Waukesha Engine Model: L-7044GSI Serial Number: TBD What is the maximum designed horsepower rating? 1576 hp What is the maximum manufacturer's site -rating? 1576 hp 1,175 kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8,337 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke ❑✓ 4 -Stroke Combustion: ❑ Lean Burn ❑✓ Rich Burn Aspiration: 0 Natural Q Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑✓ Yes 0 No If yes, what type of AFRC is in use? ❑ OZ Sensor (mV) ❑NOx Sensor (ppm) ❑✓ Other: Is this engine equipped with a Low-NOx design? 0 Yes ❑✓ No Engine Dates: What is the manufactured date of this engine? 2018 What date was this engine ordered? TBD What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? O Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 /sv,COLORADO 3 mn..n:Rr n�m Neap _ Envlennn.nl Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (LatitudefLongitude or UTM) 40.62965/-104.16590 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. ('F) Flow Rate (ACFM) Velocity (ft/sec) CM -250 TBD 1,217 8,343 40 Indicate the direction of the Stack outlet: (check one) EJ Upward Horizontal Indicate the stack opening and size: (check one) 12 Circular O Square/Rectangle Other (describe): Downward Other (describe): Interior stack diameter (inches): Interior stack diameter (inches): ❑ Upward with obstructing raincap TBD Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate @ 100% Load (SCF/ hour) Actual Annual Fuel Use (MMSCF/ year) Requested Annual Permit Limit$ (MMSCF/year) 12,043 -- 105.50 From what year is the actual annual amount? Indicate the type of fuel used9: DI Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) ❑✓ Field Natural Gas Heating value: 1,091 BTU/scf Propane (assumed fuel heating value of 2,300 BTU/scf) Landfill Gas Heating Value: BTU/scf ❑Other (describe): Heating Value (give units): 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 4 I A. COLORADO Frrm^ro: ofv�c:.� Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ❑✓ Yes 0 No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.5 SOX NOx NSCR/AFRC 97.5% VOC CO NSCRfAFRC 94.4% Other: Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor t0 Actual Annual Emissionsl° Requested Annual Permit Emission Limits) Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) TSP (PM) 0.01941 Ib/MMBtu AP -42 - - 1.12 1.12 PM10 0.01941 lb/MMBtu AP -42 - - 1.12 1.12 PM2.5 0.01941 Ib/MMBtu AP -42 - - 1.12 1.12 SOX 0.000588 lb/MMBtu AP -42 - - 0.03 0.03 NO 14.10 g/hp-hr Manufacturer - - 214.58 5.33 VOC 0.74 g/hp-hr Manufacturer - - 11.26 7.61 CO 12.60 g/hp-hr Manufacturer - - 191.75 10.65 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 ❑✓ Yes O No lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions10 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (pounds/year) Controlled Emissions (pounds/year) Formaldehyde 50000 0.05 g/hp-hr Manufacturer 1521.82 (PTE) 1521.82 (PTE) Acetaldehyde 75070 2.79E-03 Ib/MMbtu AP -42 321.13 (PTE) 321.13 (PTE) Acrolein 107028 2.63E-03 Ib/MMbtu AP -42 302.71 (PTE) 302.71 (PTE) Benzene 71432 Other: Methanol 3.06E-03 lb/MMbtu AP -42 352.20 (PTE) 352.20 (PTE) 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 COLORADO 5 I A'_ 1n:ol� � luin IIRi E Ervlionnenl Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit 1t and AIRS ID] Section 8 - Applicant Certification hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP02. /O/91/8 Signature of Legally Authorized Person (not a vendor or consultant) Date Cody Kerrigan Engineering Manager Name (please print) Title Check the appropriate box to request a copy of the: fJ Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $1,875, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 'COLOR ADO 6 I u�15E•.ulrcnm.nl Spark Ignition Engine APEN Form APCD-201 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for spark ignition (e.g. gas -fired) reciprocating internal combustion engines (RICE). If your engine is a compression ignition engine (e.g. diesel -fired) or your emission unit does not fall into the RICE category, there may be a more specific APEN for your source (e.g. compression ignition engine, mining operations, asphalt plant, crusher, screen, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options do not meet your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 143'(n/E1 AQ' - AIRS ID Number: 123 /4FFc/ uv�Q [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Outrigger DJ Operating LLC Site Name: Koki Compressor Station Site Location: Sec. 26 T8N R61W Mailing Address: (include Zip Code) 1200 17th Street, Suite 900 Portable Source Home Base: Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 237120 Contact Person: Cody Kerrigan Phone Number: 720-361-2551 E -Mail Address2: ckerrigan@outriggerenergy.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 388688 COLORADO .v fi.otih _ F�vul.crun-nl Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑✓ NEW permit OR newly -reported emission source (check one below) ❑✓ STATIONARY source ❑ PORTABLE source ✓❑ Request coverage under a Construction Permit ❑ Request coverage under General Permit GP023 (Natural Gas Only) If General Permit coverage is requested, the General Permit registration fee of $1,875 must be submitted along with the APEN filing fee. -OR - ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment ❑ Change company name4 ❑ Add point to existing permit O Change permit limit O Transfer of ownerships O Other (describe below) -OR - ❑ APEN submittal for update only (Blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - APEN submittal for permit-exempt/grandfathered source ❑ Notification of Alternate Operating Scenario (AOS) permanent replacement6 Additional Info Ft Notes: 3 Only one engine may be reported per APEN for GP02 coverage. Coverage under GP02 is voluntary. 4 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 5 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. 6 This does not apply to General Permit GP02, as it does not contain a provision for AOS permanent replacements. Section 3 - General Information Does this engine have a Company Equipment Identification No. (e.g. ENG-1, Engine 3, etc.)? If yes, provide the Company Equipment Identification No. CM -260 Yes General description of equipment and purpose: Natural Gas Compression For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? (http://www.colorado.gov/cdphe/attainment) Normal Hours of Source Operation: 24 hours/day 7 TBD ['Yes ❑ No Seasonal use percentage: Dec -Feb: 25 Mar -May: 25 days/week 52 weeks/year June -Aug: 25 Sept -Nov: 25 Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 Avfieitt+� Er.atinnmml Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Engine Information Engine Function: ❑ Primary and/or Peaking Power 0 Emergency (max. 500 hrs/year) ❑✓ Compression ❑ Pump Jack ❑ Water Pump ❑ Other: What is the maximum number of hours this engine will be used for emergency back-up power? hours/year Engine Make: Waukesha Engine Model: L-7044GSI Serial Number7: TBD What is the maximum designed horsepower rating? 1576 hp What is the maximum manufacturer's site -rating? 1576 hp 1,175 kW What is the engine Brake Specific Fuel Consumption at 100% Load? 8,337 BTU/hp-hr Engine Features: Cycle Type: ❑ 2 -Stroke 4 -Stroke Combustion: ❑ Lean Burn ❑✓ Rich Burn Aspiration: 0 Natural D Turbocharged Is this engine equipped with an Air/Fuel ratio controller (AFRC)? ❑✓ Yes 0 No If yes, what type of AFRC is in use? ❑ O2 Sensor (mV) ❑NOx Sensor (ppm) ❑✓ Other: Is this engine equipped with a Low-NOx design? ❑ Yes ❑✓ No Engine Dates: What is the manufactured date of this engine? 2018 What date was this engine ordered? TBD What is the date this engine was first located to Colorado? TBD What is the date this engine was first placed in service/operation? TBD What is the date this engine commenced construction? TBD What is the date this engine was last reconstructed or modified? TBD Is this APEN reporting an AOS replacement engine? O Yes ❑✓ No If yes, provide the make, model, and serial number of the old engine below: Engine Make: Engine Model: Serial Number: 7 The serial number must be submitted if coverage under GP02 is requested. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 AV COLORADO 3 I ,,rtnm,:o�hr Hec;:M 5 Fruteunm�nl Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.62965/-104.16590 Stack ID No. Discharge Height Above Ground Level (feet) Temp. (�F) Flow Rate ACFM) (ACFM) Velocity (ft/sec) CM-260 TBD 1,217 8,343 40 Indicate the direction of the Stack outlet: (check one) ❑✓ Upward ❑ Downward ❑ Horizontal ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/Rectangle ❑ Other (describe): Interior stack diameter (inches): ❑ Upward with obstructing raincap TBD Interior stack diameter (inches): Interior stack depth (inches): Section 6 - Fuel Data and Throughput Information Fuel Use Rate ® 100% Load- (SCF/ hour) Actual Annual Fuel Use F/ear) (MMSCyear) Requested Annual Permit Limit8 (MMSCF/y 12,043 -- 105.50 From what year is the actual annual amount? Indicate the type of fuel used9: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/scf) 0 Field Natural Gas Heating value: 1,091 BTU/scf O Propane (assumed fuel heating value of 2,300 BTU/scf) ❑ Landfill Gas Heating Value: BTU/scf ❑ Other (describe): Heating Value (give units): 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 9 If fuel heating value is different than the listed assumed value, provide this information in the "Other" field. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 4 I A. COLORADO jbar1nm :ot N:k:ic • H,.a[ily_ EiuieantrotI Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. The APCD website has a Natural Gas Fired Engines Calculator available to assist with emission calculations. Is any emission control equipment or practice used to reduce emissions? ID Yes ❑ No If yes, describe the control equipment AND state the overall control efficiency (% reduction): Pollutant Primary Control Equipment Description Overall Requested Control Efficiency (% reduction in emissions) TSP (PM) PM10 PM2.s SOx NOx NSCR/AFRC 97.5% VOC CO NSCR/AFRC 94.4% Other: Use the following tables to report criteria and non -criteria pollutant emissions from source: (Use the data reported in Section 6 to calculate these emissions.) From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions 10 Requested Annual Permit Emission Limit(s)8 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) TSP (PM) 0.01941 Ib/MMBtu AP -42 - - 1.12 1.12 PM10 0.01941 Ib/MMBtu AP -42 - - 1.12 1.12 PM 2.5 0.01941 lb/MMBtu AP -42 - - 1.12 1.12 SOx 0.000588 Ib/MMBtu AP -42 - - 0.03 0.03 NOx 14.10 g/hp-hr Manufacturer - - 214.58 5.33 VOC 0.74 g/hp-hr Manufacturer - - 11.26 7.61 CO - 12.60 g/hp-hr Manufacturer - - 191.75 10.65 Does the emissions source have any uncontrolled actual emissions of non -criteria pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 Q Yes ❑ No lbs/year? If yes, please use the following table to report the non -criteria pollutant (HAP) emissions from source: Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract (CAS) ( ) Number Emission Factor. Actual Annual Emissions') Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (pounds/year) Controlled Emissions (pounds/year) Formaldehyde 50000 0.05 g/hp-hr Manufacturer 1521.82 (PTE) 1521.82 (PTE) Acetaldehyde 75070 2.79E-03 lb/MMbtu AP -42 321.13 (PTE) 321.13 (PTE) Acrolein 107028 2.63E-03 Ib/MMbtu AP -42 302.71 (PTE) 302.71 (PTE) Benzene 71432 Other: Methanol 3.06E-03 Ib/MMbtu AP -42 352.20 (PTE) 352.20 (PTE) 8 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 10 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 5I COLORADO bcyrmsr Deter Erv.tunrnl Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP02, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP02. Signature of Legally Authorized Person (not a vendor or consultant) Date Cody Kerrigan Engineering Manager Name (please print) Title Check the appropriate box to request a copy of the: D Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $1,875, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https: / /www. colorado. gov/cdphe/apcd Form APCD-201 - Spark Ignition Engine APEN - Revision 7/2018 COLORADO 61 •Vl otrt F'.a�tl•.SEwitnnmonl Gas Venting APEN - Form APCD-211 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for gas venting only. Gas venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Qov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 1 Vi �V�"1• AIRS ID Number: 12-6 DIFFF 1001 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Outrigger DJ Operating LLC Site Name: Koki Compressor Station Site Location: Sec. 26 T8N R61W Mailing Address: 1200 17th Street, Suite 900 (Include Zip Code) Denver, CO 80202 Site Location Weld County: NAICS or SIC Code: 237120 Contact Person: Cody Kerrigan Phone Number: 720-361-2551 E -Mail Address2: ckerrigan@outriggerenergy.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-211 - Gas Venting APEN - Revision 7/2018 388689 COLORADO 1 I �! u=Fr ^: d utNfr Fn of Pull= - • M Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑✓ NEW permit OR newly -reported emission source -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name3 O Add point to existing permit O Change permit limit ❑ Transfer of ownership' O Other (describe below) OR - • APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - [I Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Compressor Blowdowns Company equipment Identification No. (optional): For existing sources, operation began on: For new, modified, or reconstructed sources, the projected start-up date is: D Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area? Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions? Is this equipment subject to Colorado Regulation No. 7, Section XVII.G? Form APCD-211 - Gas Venting APEN - Revision 7/2018 days/week weeks/year Yes Yes Yes ❑ No ❑✓ No ❑✓ No I COLORADO 2 I nod PuM�c aviro�vmarl Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit ft and AIRS ID] Section 4 - Process Equipment Information ❑ Gas/Liquid Separator ❑ Well Head Casing O Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: ❑✓ Blowdown Events # of Events/year: ❑ Other Description: Serial #: Capacity: gal/min Model: # of Pistons: Leak Rate: Scf/hr/pist 72 Volume per event: 0.0025 MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? O Yes Gas Venting Process Parameters5: Liquid Throughput Process Parameters5: Vented Gas Properties: 0 No Vent Gas Heating Value: 1 , 361 BTU/SCF Requested: 0.18 MMSCF/year Actual: -_ MMSCF/year -OR- Requested: bbl/year Actual: bbl/year Molecular Weight: 23.89 VOC (Weight %) 32.58% Benzene (Weight %) 0.11% Toluene (Weight %) 0.06% Ethylbenzene (Weight %) 0.004% Xylene (Weight %) 0.01% n -Hexane (Weight %) 0.64% 2,2,4-Trimethylpentane (Weight %) 0.0003% Additional Required Information: ❑✓ Attach a representative gas analysis (including BTEX Ft n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX Et n -Hexane, temperature, and pressure) 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-211 - Gas Venting APEN - Revision 7/2018 ;COLORADO 3 I AVIDepartrcentolPublic H.M.£nYtmeunenl Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit ;# and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.62965/-104.16590 Operator $, Stack ID No . DischargegHeigI t `' -��". = Above Ground Leve F _: Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec)' TBD TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal ❑ Downward El Other (describe): Fugitive Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑✓ Other (describe): Fugitive ❑ Upward with obstructing raincap Section 6 - Control Device Information ® Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. ❑ VRU: Pollutants Controlled: Size: Make/Model: Requested Control Efficiency: % VRU Downtime or Bypassed: % ❑ Combustion Device: Pollutants Controlled: Rating: Type: Requested Control Efficiency: Manufacturer Guaranteed Control Efficiency: Minimum Temperature: MMBtu/hr Make/Model: % Waste Gas Heat Content: Btu/scf Constant Pilot Light: ❑ Yes ❑ No Pilot burner Rating: MMBtu/hr Other: Pollutants Controlled: Description: Requested Control Efficiency: Form APCD-211 - Gas Venting APEN - Revision 7/2018 4I t` I COLORADO Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (%reduction): Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) PM SOX NO. CO VOC HAPs Other: From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions` Requested Annual Permit` Emission Limit(s) Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled >- Emissions6 (tons/year) Uncontrolled Emissions (tons/year) .. Controlled ; Emissions,....' (tons/year) PM SOX NO. CO VOC 51.28 lb/event Eng. Est. -- -- 1.84 1.84 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (pounds/year) Controlled Emissions6 (pounds/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 2,2,4- Trimethylpentane 540841 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-211 - Gas Venting APEN - Revision 7/2018 5I A_ COLOR ADO LlrT.en: Ell Public Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. Signature of Legally Authorized Person (not a vendor or consultant) Date Cody Kerrigan Engineering Manager Name (please print) Title Check the appropriate box to request a copy of the: Ei Draft permit prior to issuance 0✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-211 - Gas Venting APEN - Revision 7/2018 ©© COLOR ADO 61 •V :oRk Glycol Dehydration Unit APEN Form APCD-202 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for glycol dehydration (dehy) units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: `$'WE 6gor AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] z3'4Fi c' 008 Section 1 - Administrative Information Company Name': Outrigger DJ Operating LLC Site Name: Koki Compressor Station Site Location: Sec. 26 T8N R61 W Mailing Address: (Include Zip Code) 1200 17th Street, Suite 900 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 237120 Contact Person: Cody Kerrigan Phone Number: 720-361-2551 E -Mail Address2: ckerrigan@outriggerenergy.com ' Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 388690 V COLORADO 1 � AV Fee11R51.rt.nnm.nl Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit It and AIRS ID] Section 2 - Requested Action O NEW permit OR newly -reported emission source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 0 Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership' 0 Other (describe below) OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - El Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Ft Notes: 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: One (1) - TEG Dehydration System Company equipment Identification No. (optional): For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 0 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: Will this equipment be operated in any NAAQS nonattainment area? Is this unit located at a stationary source that is considered a Major Source of (HAP) Emissions? hours/day days/week Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 Yes Yes ❑✓ weeks/year No No {{COLORADO 2 I hiV Rca:ih EEnri,o�•nl Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: Propak Dehydrator Serial Number: TBD Model Number: 186039 Reboiler Rating: 0.683 MMBTU/hr Glycol Used: O Ethylene Glycol (EG) ❑ DiEthylene Glycol (DEG) ❑✓ TriEthylene Glycol (TEG) Glycol Pump Drive: ❑ Electric ❑✓ Gas If Gas, injection pump ratio: Pump Make and Model: Klmray 21020 PV 10.05 / 3.5 Glycol Recirculation rate (gal/min): Lean Glycol Water Content: Max: 3.5 0.51 Wt.% Requested: 3.5 # of pumps: Acfm/gpm Dehydrator Gas Throughput: Design Capacity: 25 MMSCF/day Requested5: ' 40.USCF/year Actual: -- MMSCF/year Inlet Gas: Pressure: Water Content: Wet Gas: Flash Tank: 1147.3 psig Temperature: 130 °F lb/MMSCF ✓❑ Saturated Dry gas: 5.78 lb/MMSCF Pressure: 60.3 psig Temperature: 143.5 °F O NA Cold Separator: Pressure: psig Temperature: °F ❑✓ NA Stripping Gas: (check one) O None ❑ Flash Gas ✓❑ Dry Gas O Nitrogen Flow Rate: 14 scfm Additional Required Information: ❑✓ Attach a Process Flow Diagram ❑✓ Attach GRI-GLYCaIc 4.0 Input Report £t Aggregate Report (or equivalent simulation report/test results) ❑✓ Attach the extended gas analysis (including BTEX Et n -Hexane, temperature, and pressure) 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 COLOR ADO 3 I _ ; t'Hea;�h5Enn,: °e wnm.nl ❑✓ Upward 0 Horizontal Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.62965/-104.16590 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. F (' ) Flow Rate ACEM) Velocity ; (ft/sec)' ., TBD TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) O Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/rectangle 0 Other (describe): Interior stack diameter (inches): 0 Upward with obstructing raincap Interior stack width (inches): Interior stack depth (inches): Section 6 - Control Device Information 0 Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Condenser: Used for control of: Vent emissions Type: BTEX Eliminator Make/Model: Tank Safe Maximum Temp: 160 °F Average Temp: 120 °F Requested Control Efficiency: 95 % ❑ VRU: Used for control of: Size: Requested Control Efficiency: VRU Downtime or Bypassed: Make/Model: ❑ Combustion Device: Used for control of: Still Vent emissions Rating: 1.6 MMBtu/hr Type: ECD Make/Model: Crimson Energy/CE-100 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 % Minimum Temperature: °F Waste Gas Heat Content: 1435 Btu/scf Constant Pilot Light: ❑✓ Yes 0 No Pilot Burner Rating: 0.03 MMBtu/hr Closed ❑ Loop System: Used for control of: Description: System Downtime: O Other: Used for control of: Description: Requested Control Efficiency: Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 COLORADO 4 I Naa��'Ih 6 Ena4onm.+.1 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit U and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the ncy (% reduction): Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) PM SOX NO. CO VOC ECD 95% HAPs ECD 95% Other: From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (tons/year) (tons/ ear Controlled Emissions6 (tons/year) Uncontrolled Emissions tons/ ear ( y ) Controlled Emissions (tons/ ear (tons/year) PM SOx 0.002 Ib/MMscf ProMax -- -- 0.01 0.01 NO. 0.068 Ib/MMBtu AP -42 — — 0 . 6 0. G CO 0.31 Ib/MMBtu AP -42 — — a .s. 2 • q VOC to6.0 Ib/MMscf C1i caJc. -- -- ciV, 7. 7).9 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (pounds/year) Controlled Emissions6 (pounds/year) Benzene 71432 a • (0 Ib/MMscf 611�Cutt G gcf3 64 .) 1g53 Toluene 108883 3 �� Ib/MMscf d 314 I f ) 13 6-I - ) Ethylbenzene 100414 6 •27a Ib/MMscf 2' )-0 ) 150 Xylene 1330207 O.V0 Ib/MMscf 3' 5 7 l ) 3L1 2- n -Hexane 110543 a .nA Ib/MMscf V x1331 3gy 2,2,4- Trimethylpentane 540841 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 1COLORADO 51! �;of x.•ur. _•.,,o..,,,..., Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. Signature of Legally Authorized Person (not a vendor or consultant) Date Cody Kerrigan Engineering Manager Name (print) Title Check the appropriate box to request a copy of the: L Draft permit prior to issuance ✓0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 6 I ATCOLORADO IL,,, 5Envii-nrn, Glycol Dehydration Unit APEN Form APCD-202 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for glycol dehydration (dehy) units only. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, hydrocarbon liquid loading, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: i Q ifVe` 108'4- AIRS ID Number: ! 23 / t FFF/ 0O I [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Site Name: Outrigger DJ Operating LLC Koki Compressor Station Site Location: Sec. 26 T8N R61 W Mailing Address: (Include Zip Code) 1200 17th Street, Suite 900 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 237120 Contact Person: Phone Number: E -Mail Address2: Cody Kerrigan 720-361-2551 ckerrigan@outriggerenergy.com ' Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 38861. 11��'COLORADO '�:o,�r Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑✓ NEW permit OR newly -reported emission source -OR - ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment O Change company name3 0 Add point to existing permit 0 Change permit limit ❑ Transfer of ownership' ❑ Other (describe below) - OR ▪ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ID Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: One (1) - TEG Dehydration System Company equipment Identification No. (optional): For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: ❑✓ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: Will this equipment be operated in any NAAQS nonattainment area? hours/day days/week Is this unit located at a stationary source that is considered a Major Source of (HAP) Emissions? Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 Yes Yes weeks/year No No ©© COLORADO 2 I m�� :ofPut, Na ally 5 EmIrnnlnn:l Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Dehydration Unit Equipment Information Manufacturer: Propak Dehydrator Serial Number: TBD Model Number: 186039 Reboiler Rating: 0.683 MMBTU/hr Glycol Used: O Ethylene Glycol (EG) O DiEthylene Glycol (DEG) ❑✓ TriEthylene Glycol (TEG) Glycol Pump Drive: O Electric ❑✓ Gas If Gas, injection pump ratio: Pump Make and Model: Kimray 21020 PV 10.05 / 3.5 Glycol Recirculation rate (gal/min): Max: 3.5 Lean Glycol Water Content: 0.51 Wt.% Requested: 3.5 # of pumps: Acfm/gpm Dehydrator Gas Throughput: Design Capacity: 25 MMSCF/day Requested5: Jq I %5MMSCF/year Actual: -- MMSCF/year Inlet Gas: Water Content: Wet Gas: Flash Tank: Pressure: 60.3 Cold Separator: Pressure: 1147.3 Pressure: Stripping Gas: (check one) psig lb/MMSCF psig psig o None ❑ Flash Gas ❑✓ Dry Gas O Nitrogen Flow Rate: 14 scfm Temperature: ❑✓ Saturated Temperature: Temperature: 130 °F Dry gas: 5.78 143.5 °F °F lb/MMSCF ❑ NA ❑✓ NA Additional Required Information: O Attach a Process Flow Diagram 0 Attach GRI-GLYCaIc 4.0 Input Report Et Aggregate Report (or equivalent simulation report/test results) ❑✓ Attach the extended gas analysis (including BTEX Et n -Hexane, temperature, and pressure) 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 AVIcoweADO 3 I fie.11 Ervf.tnnnl Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit tt and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.62965/-104.16590 Operator Stack ID No. Discharge Height _ Above Ground Level (feet) Temp F (�' ) Flow Rate (ACF1 M ' Velocity t/sec ) (ft/fee) TBD TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward 0 Other (describe): Indicate the stack opening and size: (check one) ❑✓ Circular ❑ Square/rectangle ❑ Other (describe): Interior stack diameter (inches): 0 Upward with obstructing raincap Interior stack width (inches): Interior stack depth (inches): Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Condenser: Used for control of: Vent emissions Type: BTEX Eliminator Make/Model: Tank Safe Maximum Temp: 160 °F Average Temp: 120 Requested Control Efficiency: 95 % O VRU: Used for control of: Size: Requested Control Efficiency: Make/Model: % VRU Downtime or Bypassed: % ❑✓ Combustion Device: Used for control of: still Vent emissions Rating: 1.6 MMBtu/hr h r Type: ECD Make/Model: Crimson Energy/CE-1 00 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 % Minimum Temperature: °F Waste Gas Heat Content: 1435 Btu/scf Constant Pilot Light: ❑✓ Yes ❑ No Pilot Burner Rating: 0.03 MMBtu/hr Closed O Loop System: Used for control of: Description: System Downtime: ❑ Other: Used for control of: Description: Requested Control Efficiency: Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 4 I ®,�COLOR ADO Mel Math ErmIro enx krYlh 5 EM1vlro ct:Ic Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 7 - Emissions Inventory Information Attach all emission calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant Description of Control Methods P Method(s) ro RequestedEfficiency Control Efficiency (% reduction in emissions) PM SO. NO. CO VOC ECD 95% HAPs ECD 95% Other: From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) PM SOX 0.002 Ib/MMscf ProMax -- — 0.01 0.01 NO. 0.068 Ib/MMBtu AP -42 — — 0. C, D. (, CO 0.31 Ib/MMBtu AP -42 - - 'a. ,'? D.% VOC 10(,,.0 Ib/MMscf 6Ii,cc, ( -- — la`q ---. 4j.°( Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract ServiceUncontrolled (CAS) Number Emission Factor Actual Annual Emissions Basis Units Source (AP -42, Mfg., etc.) ) Uncontrolled Emissions (pounds/year) Controlled Emissions6 , (pounds/year) Benzene 71432 t.$(, lb/MMscf blyc(C, 9t4 -3(J / Iig,;3 TE) Toluene 108883 3, L `( Ib/MMscf 31 c(l , IE) 13 (4 ) Ethylbenzene 100414 O .1?`)-. Ib/MMscf ' 2-q a. Q ..) 1770 Xylene 1330207 0 , `6? Ib/MMscf 3-5 "i-l4 .TE) -- 4a n -Hexane 110543 2-. 3 LI Ib/MMscf ./ ,c D-)3'7, E) _ 'zj cr5 4 2,2,4- Trimethylpentane 540841 Other: 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 COLORADO 5 1:o,ti ��h ^ ErtvYrnnm.r•.1 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 8 - Applicant Certification hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. /0/9//8 Signature of Legally Authorized Person (not a vendor or consultant) Date Cody Kerrigan Engineering Manager Name (print) Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance El Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.cotorado.gov/cdphe/apcd Form APCD-202 - Glycol Dehydration Unit APEN - Revision 7/2018 COLORADO 6 1 •T7 .« F uIMEE�.N.c�mrnl Condensate Storage Tank(s) APEN Form APCD-205 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for tanks that store condensate associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.Rov/pacific/cdphe/air-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: Ig JE(Og 4 - AIRS ID Number: 123 "!FFF' 0l0 [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name': Outrigger DJ Operating LLC Site Name: Koki Compressor Station Site Location: Sec. 26 T8N R61 W Mailing Address: (Include Zip Code) 1200 17th Street, Suite 900 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 237120 Contact Person: Phone Number: E -Mail Address2: Cody Kerrigan 720-361-2551 ckerrigan@outriggerenergy.com ' Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 388692 COLORADO 1 I A®�. mnr of RHic M1sh5FiwYo..nrr.1 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit ft and AIRS ID] Section 2 - Requested Action El NEW permit OR newly -reported emission source El Request coverage under traditional construction permit O Request coverage under a General Permit ❑ GP01 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of $312.50 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) O Change in equipment 0 Change company name3 O Change permit limit 0 Transfer of ownership' 0 Other (describe below) -OR - ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - • APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Et Notes: 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Company equipment Identification No. (optional): For existing sources, operation began on: cc devt5ccte. Six (6) - 400 bbl Slop aStorage Vessels N/A For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 Storage tank(s) located at: hours/day 7 days/week 52 weeks/year 0 Exploration a Production (EEtP) site 0 Midstream or Downstream (non E£tP) site Will this equipment be operated in any NAAQS nonattainment area? ri Yes ■ No Are Flash Emissions anticipated from these storage tanks? O Yes ■ No Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? ■ Yes ri No If "yes", identify the stock tank gas -to -oil ratio: m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 series rules? If so, submit Form APCD-105. Yes No • Ig Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions a 6 ton/yr (per storage tank)? Yes No p ■ Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 COLORADO 2 I :a[nn ronm.n I�i�F F5Erwfl Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl/year) Requested Annual Permit Limits (bbl/year) Condensate Throughput: 163,374 From what year is the actual annual amount? N/A Average API gravity of sales oil: 42 degrees 0 Internal floating roof Tank design: p Fixed roof RVP of sales oil: 10 0 External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) TBD 6 2400 TBD TBD Wells Serviced by this Storage Tank or Tank Battery6 (E6P Sites On y) API Number Name of Well Newly Reported Well - - • _ ■ ■ - ■ ■ s Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 The EaP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.62965/-104.16590 Operator Stack ID No. Discharge Height Above Ground Level (feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) ECD TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) El Upward O Horizontal D Downward O Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) El Circular Interior stack diameter (inches): TBD ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 3 I eVICOLORADO Hestiti _ EI'.Vlranln.nl Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit #, and AIRS ID] Section 6 - Control Device Information 0 Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Vapor ❑ Recovery Unit (VRU): Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: ❑ Combustion Device: Pollutants Controlled: VOC/HAPS Rating: 18 Type: ECD MMBtu/hr Make/Model: CE -300 Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: TBD Waste Gas Heat Content: 2,384 Btu/scf Constant Pilot Light: ❑✓ Yes 0 No Pilot Burner Rating: 0.05 MMBtu/hr O Closed Loop System Description of the closed loop system: O Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 - Gas/Liquids Separation Technology Information (E&tP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? 50 psig Describe the separation process between the well and the storage tanks: HLP Separator, Slop Oil Tanks Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 'COLORADO 1 H:k, Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) VOC ECD 95% NOx CO HAPs ECD 95% Other: From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor? Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Tons/year) ) Controlled Emissions (Tons/yea (Tons/year) r) Uncontrolled Emissions (Tons/year) Controlled Emissions (Tonslyear), VOC 5.312 lb/bbl Promax — — 433.92 21.70 NOx 0.068 Ib/MMBtu AP -42 — -- 0.83 0.83 CO 0.31 lb/MMBtu AP -42 — — 3.77 3.77 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service CAS (CAS) Number Emission Factor? Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg. etc) Uncontrolled Emissions (Pounds/year) Controlled Emissions8 (Pounds/year) Benzene 71432 0.024 lb/bbl Promax 3,855.37 (PTE) 192.77 (PTE) Toluene 108883 0.012 lb/bbl Promax 1,940.30 (PTE) 97.02 (PTE) Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 0.135 lb/bbl Promax 22,025.04 (PTE) 1,101.25 (PTE) 2,2,4- Trimethylpentane 540841 5 Requested values will become permit limitations. Requested limit(s) should consider future growth. 7 Attach condensate liquid laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 V l c O,rt.. O A�� 5 I_a�� Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 9 - Applicant Certification hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP01 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. /O/9/Id' Signature of Legally Authorized Person (not a vendor or consultant) Date Cody Kerrigan Engineering Manager Name (print) Title Check the appropriate box to request a copy of the: O Draft permit prior to issuance O Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $312.50, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https://www.colorado.gov/cdphe/apcd Form APCD-205 - Condensate Storage Tank(s) APEN - Revision 7/2018 ®®COLORADO fi.vll�. S Er.�lronm.r.l Hydrocarbon Liquid Loading APEN Form APCD-208 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re -submittal. This APEN is to be used for hydrocarbon liquid loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source (e.g. amine sweetening unit, glycol dehydration unit, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/cdphe/apcd. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: ig V op. AIRS ID Number: (23 /gFFFI 0 ti [Leave blank unless APCD has already assigned a permit it and AIRS ID] Section 1 - Administrative Information Company Name': Outrigger DJ Operating LLC Site Name: Koki Compressor Station Site Location: Sec. 26 T8N R61 W Mailing Address: (Include Zip Code) 1200 17th Street, Suite 900 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 237120 Contact Person: Cody Kerrigan Phone Number: 720-361-2551 E -Mail Address2: ckerrigan@outriggerenergy.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. 388693 Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 1 I m� 'COLORADO I ❑epa,r. s: oevtric livolll: - Sn•.trnmme:l Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ❑✓ NEW permit OR newly -reported emission source ✓❑ Request coverage under construction permit 0 Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of $312.50 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) O Change fuel or equipment 0 Change company name3 ❑ Change permit limit ❑ Transfer of ownership4 0 Other (describe below) -OR- ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info ft Notes: 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Truck loadout of slop condensate Company equipment Identification No. (optional): NA For existing sources, operation began on: TBD For new or reconstructed sources, the projected start-up date is: TBD Will this equipment be operated in any NAAQS nonattainment area? Yes No p • Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Yes No • NI Does this source load gasoline into transport vehicles? Yes No ■ p Is this source located at an oil and gas exploration and production site? Yes No ■ p If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Yes No • BI Does this source splash fill less than 6750 bbl of condensate per year? Yes No ■ p Does this source submerge fill less than 16308 bbl of condensate per year? Yes No • p Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 AVCOLORADO 2 I Gspartman: of Fctb Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Process Equipment Information Product Loaded: ❑ Condensate ❑ Crude Oil El Other: Slop Condensate If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded5: 24,000 bbl/year This product is loaded from tanks at this facility into: (e.g. "rail tank cars" or "tank trucks") Actual Volume Loaded: Tank Trucks bbl/year If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: 0.6 Average temperature of bulk liquid loading: 58.1 6 ° F True Vapor Pressure: 5.0032 Psia @ 60 ° F Molecular weight of displaced vapors: 66 lb/lb-mot If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: bbl/year Actual Volume Loaded: bbl/year Product Density: lb/ft3 Load Line Volume: ft3/truckload Vapor Recovery Line Volume: ft3/truckload 5 Requested values will become permit limitations. Requested limit(s) should consider future process growth. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 COLORADO 3 I ' Heailh _ En•nionmrl•.1 Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.62965/-104.16590 Operator ID No. Discharge Height Above Ground Level (feet) Temp. F(ACFM) C' ) Flow Rate . Velocity (ft/sec) TBD TBD TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Horizontal 0 Downward 0 Other (describe): Fugitive Indicate the stack opening and size: (check one) ❑ Circular Interior stack diameter (inches): ❑✓ Other (describe): Fugitive 0 Upward with obstructing raincap Section 6 - Control Device Information 0 Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. 0 Loading occurs using a vapor balance system: Requested Control Efficiency: % ❑ Combustion Device: Used for control of: Rating: Type: MMBtu/hr Make/Model: Requested Control Efficiency: % Manufacturer Guaranteed Control Efficiency: Minimum Temperature: `F Waste Gas Heat Content: Constant Pilot Light: 0 Yes 0 No Pilot Burner Rating: Btu/scf MMBtu/hr ❑ Other: Pollutants Controlled: Description: Requested Control Efficiency: Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 ®®COLOFAQO 4 I Fe11:�E�•.aYr[�nr I Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 7 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (% reduction): Pollutant Description of Control Method(s) Overall Requested Control Efficiency (% reduction in emissions) PM SOX NO. CO VOC HAPs Other: ❑ Using State Emission Factors (Required for GP07) VOC Benzene n -Hexane ❑ Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL ❑ Crude 0.104 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Pollutant Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled. Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled Emissions6 (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) PM SOx NO. CO VOC 0.20 lb/bbl ProMax — -- 2.40 2.40 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Name Chemical Abstract Service (CAS) Number - Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (pounds/year) Controlled Emissions 6 (pounds/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 0 01-} Uo ( 001 P(6 wn`„ k. L.I U > Op , 2,2,4- Trimethylpentane 540841 Other: 5 Requested values wilt become permit limitations. Requested limits) should consider future process growth. 6 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 5l COLORADO a,rtic�= hestt�_ En�n.onmeri Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP07. Q1G /o/Q//8 Signature of Legally Authorized Person (not a vendor or consultant) Date Cody Kerrigan Engineering Manager Name (print) Title Check the appropriate box to request a copy of the: ❑✓ Draft permit prior to issuance ❑✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $312.50, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-208 - Hydrocarbon Liquid Loading APEN - Revision 7/2018 COLORADO 6 I 'o � Ne:ttlt � E�:vt�ovnr�,l Produced Water Storage Tank(s) APEN - Form APCD-207 Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re -submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re -submittal will require payment for a new filing fee. This APEN is to be used for tanks that store produced water associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source (e.g. crude oil storage tanks, condensate storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200) is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website at: www.colorado.gov/pacific/cdphe/air-permits. This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: /gEtpsy- AIRS ID Number: 12.3 / cl FFr^ I 0(7 - [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 1 - Administrative Information Company Name: Outrigger DJ Operating LLC Site Name: Koki Compressor Station Site Location: Sec. 26 T8N R61 W Mailing Address: (Include Zip Code) 1200 17th Street, Suite 900 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 237120 Contact Person: Cody Kerrigan Phone Number: 720-361-2551 E -Mail Address2: ckerrigan@outriggerenergy.com 1 Use the full, legal company name registered with the Colorado Secretary of State. This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits, exemption letters, and any processing invoices will be issued by the APCD via e-mail to the address provided. Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 3/2019 397170 COLORADO 1jAY=.�� N.iI.F F Envho.unmt Permit Number: AIRS ID Number: / / [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 2 - Requested Action ✓❑ NEW permit OR newly -reported emission source ❑✓ Request coverage under traditional construction permit O Request coverage under a General Permit ❑ GP05 0 GP08 If General Permit coverage is requested, the General Permit registration fee of $312.50 must be submitted along with the APEN filing fee. -OR- ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment O Change company name3 ❑ Change permit limit 0 Transfer of ownership4 0 Other (describe below) - OR ▪ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Ft Notes: 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104) must be submitted. Section 3 - General Information General description of equipment and purpose: Two (2) - 400 bbl Produced Water Storage Tanks Company equipment Identification No. (optional): For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 Storage tank(s) located at: hours/day 7 days/week 52 ❑ Exploration Et Production (EftP) site weeks/year El Midstream or Downstream (non EftP) site Will this equipment be operated in any NAAQS nonattainment area? ✓ Yes ❑ No Are Flash Emissions anticipated from these storage tanks? ❑ Yes No I Are these storage tanks located at a commercial facility that accepts oil production wastewater for processing? ❑ Yes No ✓ Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? ■ Yes ✓ No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)• 805 series rules? If so, submit Form APCD-105. Yes No ✓ Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual emissions ≥ 6 ton/yr (per storage tank)? ❑ Yes No ✓ Form APCD-2O7 - Produced Water Storage Tank(s) APEN - Revision 3/2019 COLORADO 2 I I RAirtmen gruel %.ahhb Envleonm.M Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 4 - Storage Tank(s) Information Actual Annual Amount (bbl/year) Requested Annual Permit Limits (bbl/year) Produced Water Throughput: — 7,300,000 From what year is the actual annual amount? Tank design: 0 Fixed roof O internal floating roof O External floating roof Storage ' Tank ID # of Liquid Manifold Storage ` Vessels in Storage Tank +; Total Volume of Storage Tank (bbl) ` Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) ,! Date of First Production (month/year) TBD 2 800 TBD TBD Wells Serviced by this Storage Tank or Tank Battery b (EELP Sites Only) . =' API Number: Name of Well Newly Reported Well 5 Requested values will become permit limitations. Requested limit(s) should consider future growth. 6 The EEtP Storage Tank APEN Addendum (Form APCD-212) should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.62965/-104.16590 Operator Stack ID : No. Discharge Height Above Ground Level (feet) - Temp. (°F); Flow Rate (ACFM) Velocity (ft/sec), ECD -25 TBD TBD TBD Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Downward O Horizontal ['Other (describe): O Upward with obstructing raincap Indicate the stack opening and size: (check one) ❑✓ Circular Interior stack diameter (inches): 60 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): O Other (describe): Form APCD-2O7 - Produced Water Storage Tank(s) APEN - Revision 3/2019 COLORADO 3 a� Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 6 - Control Device Information 0 Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Pollutants Controlled: Vapor O Recovery Unit (VRU): Size: Make/Model: Requested Control Efficiency: % VRU Downtime or Bypassed (emissions vented): % ❑ Combustion Device: Pollutants Controlled: VOC/HAPs Rating: 18 Type: ECD MMBtu/hr Make/Model: CE -300 Requested Control Efficiency: 95 Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: N/A Waste Gas Heat Content: 2,384 Btu/scf Constant Pilot Light: ❑✓ Yes 0 No Pilot Burner Rating: 0.05 MMBtu/hr O Closed Loop System Description of the closed loop system: O Other: Pollutants Controlled: Description: Control Efficiency Requested: Section 7 - Gas/Liquids Separation Technology Information (E£tP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? TBD psig Describe the separation process between the well and the storage tanks: Post -flash pipeline breakout water from nearby production facilities is sent to the two (2) - 400 bbl produced water storage tanks. Form APCD-207 - Produced Water Storage Tank(s) APEN - Revision 3/2019 AV COLORADO 4 I !,ePutiic HUNT b EnrlmmoMl Benzene VOC 0.0003 Permit Number: AIRS ID Number: [Leave blank unless APCD has already assigned a permit # and AIRS ID] Section 8 - Emissions Inventory Information Attach all emissions calculations and emission factor documentation to this APEN form. If multiple emission control methods were identified in Section 6, the following table can be used to state the overall (or combined) control efficiency (96 reduction): Pollutant Description of ControlMethod(s) VOC NOx CO ECD Overall Requested Control Efficiency (% reduction in emissions) 95 HAPs ECD 95 Other: From what year is the following reported actual annual emissions data? Criteria Pollutant Emissions Inventory Emission Factor' A. ctual Annual Emissions Requested Annual Permi Emission Limit(s)5 Uncontrolled Basis lb/bbl Source (AP -42 Mfg., etc.) Tanks 4.0.9d Uncontrolled Emissions (tons/year) Controlled Emissions$ (tons/year) Uncontrolled Emissions (tons%year)" 1.18 Controlled Emissions (tons/year) „ 0.06 NOx 0.068 lb/MMBtu AP -42 0.01 0.01 CO 0.31 Ib/MMBtu AP -42 0.05 0.05 Non -Criteria Reportable Pollutant Emissions Inventory Chemical Abstract Service (CAS) Number. 71432 Emission Factor' - Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled: Emissions (pounds/year) Controlled Emissions8-: (pounds/year) Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n -Hexane 110543 2,2,4- Trimethylpentane 540841 5 Requested values will become permit limitations. Requested limit(s) should consider future growth. 7 Attach produced water laboratory analysis, stack test results, and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 8 Annual emissions fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Form APCD-207 -Produced Water Storage Tank(s) APEN - Revision 3/2019 5I AV COLORADO Dcpartmenl el Public xww� a Envlmnmenl Permit Number: AIRS ID Number: / 1 [Leave blank unless APCD has already assigned a permit It and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP05 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. y/.24/i9 Signature of Legally Authorized Person (not a vendor or consultant) Date Cody Kerrigan Engineering Manager Name (print) Title Check the appropriate box to request a copy of the: E✓ Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5) years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit registration fee of $312.50, if applicable, to: Colorado Department of Public Health and Environment .Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303) 692-3175 or (303) 692-3148 APCD Main Phone Number (303) 692-3150 Or visit the APCD website at: https: //www.colorado.gov/cdphe/apcd Form APCD-2O7 - Produced Water Storage Tank(s) APEN - Revision 3/2019 6 I AV Y. n6En471tl Hello