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Home My WebLink AboutDAQ-2024-008609 DAQE-AN102190018-24 {{$d1 }} Ted Meinhold Kinder Morgan Altamont LLC 1667 Cole Boulevard, Suite 300 Lakewood, CO 81401 erin_dunman@kindermorgan.com Dear Mr. Meinhold: Re: Approval Order: Modification to Approval Order DAQE-AN102190015-21, to Update Equipment and Emissions Project Number: N102190018 The attached Approval Order (AO) is issued pursuant to the Notice of Intent (NOI) received on December 27, 2023. Kinder Morgan Altamont LLC must comply with the requirements of this AO, all applicable state requirements (R307), and Federal Standards. The project engineer for this action is Tad Anderson, who can be contacted at (385) 306-6515 or tdanderson@utah.gov. Future correspondence on this AO should include the engineer's name as well as the DAQE number shown on the upper right-hand corner of this letter. No public comments were received on this action. Sincerely, {{$s }} Bryce C. Bird Director BCB:TA:jg cc: TriCounty Health Department EPA Region 8 195 North 1950 West • Salt Lake City, UT Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820 Telephone (801) 536-4000 • Fax (801) 536-4099 • T.D.D. (801) 536-4414 www.deq.utah.gov Printed on 100% recycled paper State of Utah SPENCER J. COX Governor DEIDRE HENDERSON Lieutenant Governor Department of Environmental Quality Kimberly D. Shelley Executive Director DIVISION OF AIR QUALITY Bryce C. Bird Director June 20, 2024 STATE OF UTAH Department of Environmental Quality Division of Air Quality {{#s=Sig_es_:signer1:signature}} {{#d1=date1_es_:signer1:date:format(date, "mmmm d, yyyy")}} {{#d2=date1_es_:signer1:date:format(date, "mmmm d, yyyy"):align(center)}} APPROVAL ORDER DAQE-AN102190018-24 Modification to Approval Order DAQE-AN102190015-21 to Update Equipment and Emissions Prepared By Tad Anderson, Engineer (385) 306-6515 tdanderson@utah.gov Issued to Kinder Morgan Altamont LLC - Bluebell Facility Issued On {{$d2 }} Issued By {{$s }} Bryce C. Bird Director Division of Air Quality June 20, 2024 TABLE OF CONTENTS TITLE/SIGNATURE PAGE ....................................................................................................... 1 GENERAL INFORMATION ...................................................................................................... 3 CONTACT/LOCATION INFORMATION ............................................................................... 3 SOURCE INFORMATION ........................................................................................................ 3 General Description ................................................................................................................ 3 NSR Classification .................................................................................................................. 3 Source Classification .............................................................................................................. 3 Applicable Federal Standards ................................................................................................. 3 Project Description.................................................................................................................. 4 SUMMARY OF EMISSIONS .................................................................................................... 4 SECTION I: GENERAL PROVISIONS .................................................................................... 5 SECTION II: PERMITTED EQUIPMENT .............................................................................. 6 SECTION II: SPECIAL PROVISIONS ..................................................................................... 8 PERMIT HISTORY ................................................................................................................... 12 ACRONYMS ............................................................................................................................... 13 DAQE-AN102190018-24 Page 3 GENERAL INFORMATION CONTACT/LOCATION INFORMATION Owner Name Source Name Kinder Morgan Altamont LLC Kinder Morgan Altamont LLC - Bluebell Facility Mailing Address Physical Address 1667 Cole Boulevard, Suite 300 Lakewood, CO 81401 Sec 20 T1S R5W Altamont, UT 84001 Source Contact UTM Coordinates Name: Erin Dunman 577,604 m Easting Phone: (303) 914-7605 4,470,289 m Northing Email: erin_dunman@kindermorgan.com Datum NAD27 UTM Zone 12 SIC code 1321 (Natural Gas Liquids) SOURCE INFORMATION General Description Kinder Morgan Altamont LLC (Kinder Morgan), Bluebell Gas Plant's functions are to dehydrate field gas and extract NGL's. Field gas enters the facility through trunk lines that combine into the main facility inlet. The inlet gas stream is directed to the slug catcher, where free water and condensate are separated from the field gas. The water and condensate are directed to the existing storage tanks before being trucked from the facility. The Bluebell Compressor Station is designed to compress, treat, and dehydrate up to 30 MMscfd of natural gas and generate up to 278 bpd of condensate. NSR Classification Minor Modification at Major Source Source Classification Located in Uinta Basin O3 NAA Duchesne County Airs Source Size: A Applicable Federal Standards NSPS (Part 60), A: General Provisions NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal Combustion Engines NSPS (Part 60), OOOOa: Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 MACT (Part 63), A: General Provisions DAQE-AN102190018-24 Page 4 MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Title V (Part 70) Major Source Project Description Kinder Morgan has requested to update the Bluebell Compressor Station (CS) as follows: -Installation of a flare (FL-1) to control emissions from existing condensate tanks CS T-211, CS T-212, CS T-213, and CS T-214 -Replacement of existing combustor (COM-2) with a flare (FL-2) to control emissions from existing condensate tanks GPP TK-870 and GPP-TK-874 -Update represented potential to emit from condensate truck loading activities Process Description The Bluebell Gas Plant's functions to dehydrate field gas and extract NGLs. Field gas enters the facility through trunk lines. The inlet gas stream is directed to the slug catcher, where free water and condensate are separated from the field gas. The water and condensate are directed to the existing storage tanks before being trucked from the facility. Field gas from the slug catcher is directed to the inlet compressors. Any liquid collected from the second and third stage inlet compressor scrubbers is directed to an intermediate 3-phase flash separator (V-405). The condensate from V-405 is routed to tanks GPP-870 and GPP-874, which are controlled with a combustor. After compression Ethylene Glycol (EG) is injected into the gas to prevent hydrates from forming prior to the gas going through a series of heat exchangers and a propane chiller to cool down the gas. EG and NGL are separated from the gas in the cold separator. The rich EG is sent to a flash tank, where free gas is separated and sent to a combustor for control. The EG is then sent to a regenerator. Water vapor from the EG regenerator is sent to TK-837, where the uncondensed vapor is controlled by a combustor. NGLs are then sent to a de-ethanizer tower, where light end hydrocarbons are removed and sent to the fuel gas system. The NGL is then sent to pressurized bullet tanks for storage prior to being trucked off site. The Bluebell Gas Plant and the Bluebell CS is equipped with a flare to manage unplanned pressure relief events, planned and unplanned maintenance activities, and plant emergency shutdowns. SUMMARY OF EMISSIONS The emissions listed below are an estimate of the total potential emissions from the source. Some rounding of emissions is possible. Criteria Pollutant Change (TPY) Total (TPY) CO2 Equivalent 0 108176.00 Carbon Monoxide 5.24 109.52 Nitrogen Oxides 1.10 132.54 Particulate Matter - PM10 0.14 3.78 Particulate Matter - PM2.5 0.14 3.78 DAQE-AN102190018-24 Page 5 Sulfur Oxides 0.01 1.44 Volatile Organic Compounds 1.48 112.25 Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr) 1,3-Butadiene (CAS #106990) 0 78 2,2,4-Trimethylpentane (CAS #540841) 0 220 Acetaldehyde (CAS #75070) 0 1838 Acrolein (CAS #107028) 0 1820 Benzene (Including Benzene From Gasoline) (CAS #71432) 0 820 Biphenyl (CAS #92524) 0 44 Ethyl Benzene (CAS #100414) 0 29 Formaldehyde (CAS #50000) 0 12580 Generic HAPs (CAS #GHAPS) 20 2020 Hexane (CAS #110543) 0 2986 Methanol (CAS #67561) 0 1146 Toluene (CAS #108883) 0 480 Xylenes (Isomers And Mixture) (CAS #1330207) 0 204 Change (TPY) Total (TPY) Total HAPs 0.01 12.13 SECTION I: GENERAL PROVISIONS I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions refer to those rules. [R307-101] I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401] I.3 Modifications to the equipment or processes approved by this AO that could affect the emissions covered by this AO must be reviewed and approved. [R307-401-1] I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by the owner/operator, shall be made available to the Director or Director's representative upon request, and the records shall include the five (5)-year period prior to the date of the request. Unless otherwise specified in this AO or in other applicable state and federal rules, records shall be kept for a minimum of five (5) years. [R307-401-8] I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators shall, to the extent practicable, maintain and operate any equipment approved under this AO, including associated air pollution control equipment, in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Director which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. All maintenance performed on equipment authorized by this AO shall be recorded. [R307-401-4] I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns. [R307-107] I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories. [R307-150] DAQE-AN102190018-24 Page 6 I.8 The owner/operator shall submit documentation of the status of installation of FL-1 and FL-2 to the Director within 18 months from the date of this AO. This AO may become invalid if construction is not commenced within 18 months from the date of this AO or if construction is discontinued for 18 months or more. To ensure proper credit when notifying the Director, send the documentation to the Director, attn.: NSR Section. [R307-401-18] SECTION II: PERMITTED EQUIPMENT II.A THE APPROVED EQUIPMENT II.A.1 Bluebell Facility Natural Gas CS and Natural Gas Process Plant (GPP) II.A.2 CS RICE-1 and RICE-2 Natural gas-fired IC engines, 4SLB Capacity: 1,150 hp (each) Controls: Oxidation Catalyst II.A.3 CS RICE-3 Natural gas-fired IC engine, 4SRB Capacity: 1,478 hp Controls: AFRC and NSCR II.A.4 CS H-1 Line Heater Capacity: 0.25 MMBtu/hr II.A.5 CS T-211 thru 214 Four (4) Field Condensate Storage Tanks Capacity: 400 bbl (each) II.A.6 CS T-951, T-952, and T-953 Three (3) Methanol Storage Tanks Capacity: T-951, 140 bbl T-952, 100 bbl T-953, 140 bbl II.A.7 CS T-943 Glycol Storage Tank Capacity: 50 bbl II.A.8 CS T-941 Lube Oil Storage Vessel Capacity: 200 bbl II.A.9 CS FL-1 (NEW) Capacity: 121 scfh (pilot) Controlling Condensate Storage Tanks; CS T-211, CS T-212, CS T-213, and CS T-214 DAQE-AN102190018-24 Page 7 II.A.10 GPP C-250 and C-251 Natural gas- fired IC engines, 4SLB Capacity: 1,340 hp (each) Controls: AFR and Oxidation Catalyst Not applicable to 40 CFR 60 Subpart JJJJ Applicable to 40 CFR 63 Subpart ZZZZ II.A.11 GPP C-252 and C-253 Natural gas-fired IC engines, 4SLB Capacity: 1,380 hp (each) Controls: AFR and Oxidation Catalyst Applicable to 40 CFR 60 Subpart JJJJ II.A.12 GPP C-258 Natural gas-fired IC engines, 4SRB Capacity: 1,900 hp Controls: NSCR Applicable to 40 CFR 60 Subpart JJJJ II.A.13 GPP C-161 and C162 Natural gas-fired IC engines, 4SLB Capacity: 691 hp (each) Controls: AFR and Oxidation Catalyst Applicable to 40 CFR 60 Subpart JJJJ II.A.14 GPP C-163 Natural gas-fired IC engine, 4SLB Capacity: 691 hp Controls: AFR and Oxidation Catalyst Applicable to 40 CFR 60 Subpart JJJJ II.A.15 GPP C-256 and C-257 Natural gas-fired IC engines, 4SRB Capacity: 400 hp (each) Controls: NSCR Applicable to 40 CFR 60 Subpart JJJJ II.A.16 GPP H-1 Natural gas-fired Process Heater Capacity: 6 MMBtu/hr Control: Ultra low NOx burner (25 ppm NOx) II.A.17 GPP Dehy-1 EG Dehydration Unit with electrical regen Capacity: 30 MMscf/day Control: Combustor II.A.18 GPP COM-1 Combustors Capacity: 121 scfh (pilot) + 735 scfh (assist) II.A.19 GPP FL-2 (NEW) Flare Capacity: 121 scfh (pilot) DAQE-AN102190018-24 Page 8 II.A.20 GPP TK-870 and TK-874 Condensate Storage Tanks Capacity: 400 bbl (each) Control: Flare II.A.21 GPP TK-880 Used Oil Tank Capacity: 400 bbl II.A.22 GPP TK-872 Methanol Storage Tank Capacity: 8,820 gallons II.A.23 GPP TK-837 BTEX Water K.O. Tank Capacity: 100 bbl Control: Combustor II.A.24 Miscellaneous Tanks Tank capacities: no greater than 400 bbl (each). Material stored: lube oil, used lube oil, auxiliary water storage, ultra-fab H2S scavenger, and used ultra-fab H2S scavenger II.A.25 FUG Fugitive Emissions Gas Processing Plant applicable to 40 CFR 60 Subpart OOOOa II.A.26 GPP TL Gas Processing Plant Condensate Truck Loading Control: Vapor Capture Line II.A.27 FL-1001 Process/Emergency Flare Capacity: 50MMscfd Servicing both CS and GPP SECTION II: SPECIAL PROVISIONS II.B REQUIREMENTS AND LIMITATIONS II.B.1 Facility Wide Requirements II.B.1.a Visible emissions from the following emission points shall not exceed the following values: A. All-natural gas operated equipment and tanks - 10% opacity. B. All other points - 20% opacity. Opacity observations of emissions from stationary sources shall be conducted according to 40 CFR 60, Appendix A, Method 9. [R307-401-8] DAQE-AN102190018-24 Page 9 II.B.1.b The following production limits shall not be exceeded: 30 million standard dry cubic feet of processed natural gas per day. To determine compliance with a rolling 12-month total, the owner/operator shall calculate a new 12-month total by the twentieth day of each month using data from the previous 12 months. Records of production shall be kept for all periods when the plant is in operation. Production shall be determined by gas flow meters for natural gas and hours of operation. The records of processing and production shall be kept on a daily basis. Hours of operation shall be determined by supervisor monitoring and maintaining of an operations log. [R307-401-8] II.B.1.c All emissions from the Condensate Storage Tanks (CS T-211, CS T-212, CS T-213, CS T-214, GPP TK-870, and 874) and Dehydration unit (GPP Dehy-01) must be routed to either Combustor or flares (CS FL-1, GPP FL-2, or GPP COM-1). [R307-401-8] II.B.2 Engines Testing Requirements II.B.2.a Source: CS RICE-1 and CS RICE-2 Pollutant lb/hr NOX 3.8 (each) CO 0.31(each) Source: CS RICE-3 Pollutant lb/hr NOX 1.3 CO 0.55 Source: GPP C-250 and C-251 Pollutant lb/hr NOX 4.43 (each) CO 1.68 (each) VOC 2.07 (each) Source: GPP C-252 and C-253 Pollutant lb/hr NOX 2.13 (each) CO 2.44 (each) VOC 2.13 (each) Source: GPP C-161, C-162, and C-163 Pollutant lb/hr NOX 0.76 (each) CO 1.24 (each) VOC 1.07 (each) Source: GPP C-258 Pollutant lb/hr NOX 2.09 CO 3.35 VOC 2.09 [40 CFR 60 Subpart JJJJ, R307-401-8] DAQE-AN102190018-24 Page 10 II.B.2.b Stack testing to show compliance with the emission limitations stated in the above condition shall be performed as specified below: A. Engine Testing Requirements Emitting Units CS RICE-1 thru 3, GPP C-250, C-251, C-252, C-253, C-161, and C-162 Pollutant Status Frequency NOx ** @ CO ** @ VOC ** @ Emitting Unit GPP C-258 and C-163 Pollutant Status Frequency NOx ** @ CO ** @ VOC ** @ B. Testing Status ** Initial compliance testing already completed. @ Emissions shall be tested every three (3) years or annually, if a portable testing analyzer is used. C. Notification The Director shall be notified at least 30 days prior to conducting any required emission testing. A source test protocol shall be submitted to DAQ when the testing notification is submitted to the Director. The source test protocol shall be approved by the Director prior to performing the test(s). The source test protocol shall outline the proposed test methodologies, stack to be tested, and procedures to be used. A pretest conference shall be held, if directed by the Director. D. Sample Location The emission point shall be designed to conform to the requirements of 40 CFR 60, Appendix A, Method 1, or other EPA testing methods acceptable to the Director. An Occupational Safety and Health Administration (OSHA) or Mine Safety and Health Administration (MSHA) approved access shall be provided to the test location. E. Volumetric Flow Rate 40 CFR 60, Appendix A, Method 2, Method 19 or other EPA testing methods acceptable to the Director. F. Nitrogen Oxides (NOx) 40 CFR 60, Appendix A, Method 7, 7A, 7B, 7C, 7D or 7E, or other EPA testing methods acceptable to the Director. G. Carbon Monoxide (CO) 40 CFR 60, Appendix A, Method 10, or other EPA testing methods acceptable to the Director. H. Volatile Organic Carbon (VOC) 40 CFR 60, Appendix A, Method 18, 25, 25A, 40 CFR 63 Appendix A Method 320 or other EPA-approved testing method, as acceptable to the Director. I. Calculations To determine mass emission rates (lb/hr, etc.) the pollutant concentration as determined by the appropriate methods above shall be multiplied by the volumetric flow rate and any necessary conversion factors determined by the Director, to give the results in the specified units of the emission limitation. DAQE-AN102190018-24 Page 11 J. New Source Operation For a new source/emission point, the combustion rate during all compliance testing shall be no less than 90% of the capacity listed in Section II.A. If the maximum AO allowable combustion rate has not been achieved at the time of the test, the following procedure shall be followed: 1) Testing shall be at no less than 90% of the combustion rate achieved to date. 2) If the test is passed, the new maximum allowable combustion rate shall be 110% of the tested achieved rate, but not more than the maximum allowable combustion rate. This new allowable maximum combustion rate shall remain in effect until successfully tested at a higher rate. 3) The owner/operator shall request a higher combustion rate when necessary. Testing at no less than 90% of the higher rate shall be conducted. A new maximum combustion rate (110% of the new rate) will then be allowed if the test is successful. This process may be repeated until the maximum AO combustion rate is achieved. K. Existing Source Operation For an existing source/emission point, the combustion rate during all compliance testing shall be no less than 90% of the maximum combustion rate achieved in the previous three (3) years. [40 CFR 60 Subpart JJJJ, R307-401-8] II.B.3 Storage Tank (Storage Vessel) Requirements II.B.3.a The owner/operator shall not produce more than 101,191 barrels (1 barrel = 42 gallons) of condensate per rolling 12-month period from the Bluebell Compressor Station. [R307-401-8] II.B.3.a.1 The owner/operator shall: A. Determine condensate production with process flow meters and/or sales records. B. Record condensate production on a daily basis. C. Calculate a new 12-month total by the 20th day of each month using data from the previous 12 months. D. Keep the production records for all periods the plant is in operation. [R307-401-8] II.B.3.b At all times after startup of production, the owner/operator shall route all gases, vapors, and fumes from the condensate storage tanks at the gas plant to the operating combustor/flare. [R307-401-8] II.B.3.c The owner/operator shall keep the storage tank thief hatches and other tank openings closed and sealed, except during tank unloading or other maintenance activities. [R307-401-8] II.B.4 Monitoring Requirements of Fugitive Emissions (Leak Detection and Repair) II.B.4.a The Bluebell Gas Processing Plant is subject to the LDAR requirements in 40 CFR 60 Subpart OOOOa. [40 CFR 60 Subpart OOOOa] DAQE-AN102190018-24 Page 12 II.B.5 Truck Loading Requirements II.B.5.a The owner/operator shall load the tanker trucks on site by the use of submerged loading. [R307-401-8] II.B.5.b The owner/operator shall connect a vapor capture line to the operating combustor for use during on-site condensate truck loading operations at the Gas Processing Plant. The vapor capture line shall be used at all times during loading operations. [R307-401-8] II.B.6 Combustor and Flare Requirements II.B.6.a Each combustor and flare shall operate with a continuous pilot flame and be equipped with an auto-igniter. [R307-401-8] II.B.6.a.1 Records shall be kept that demonstrate that each combustor and flare operate with a continuous pilot flame. The permittee shall maintain records demonstrating the date of installation and manufacturer specifications for each auto-igniter. [R307-401-8] II.B.6.b Each combustor and flare shall operate with no visible emissions. [R307-401-8] II.B.6.b.1 Visual determination of emissions from each combustor and flare shall be conducted according to 40 CFR 60, Appendix A, Method 22. [R307-401-8] II.B.6.b.2 Visible emission determination shall be conducted on each combustor and flare once each month while the combustor and flare are operating. The determination period shall be 15 minutes. The observer shall be trained and knowledgeable with respect to the general procedures for determining the presence of visible emissions as specified in Method 22, Section 2.3. [R307-401-8] PERMIT HISTORY This Approval Order shall supersede (if a modification) or will be based on the following documents: Supersedes AO DAQE-AN102190015-21dated June 7, 2021 Is Derived From NOI dated December 27, 2023 DAQE-AN102190018-24 Page 13 ACRONYMS The following lists commonly used acronyms and associated translations as they apply to this document: 40 CFR Title 40 of the Code of Federal Regulations AO Approval Order BACT Best Available Control Technology CAA Clean Air Act CAAA Clean Air Act Amendments CDS Classification Data System (used by Environmental Protection Agency to classify sources by size/type) CEM Continuous emissions monitor CEMS Continuous emissions monitoring system CFR Code of Federal Regulations CMS Continuous monitoring system CO Carbon monoxide CO2 Carbon Dioxide CO2e Carbon Dioxide Equivalent - Title 40 of the Code of Federal Regulations Part 98, Subpart A, Table A-1 COM Continuous opacity monitor DAQ/UDAQ Division of Air Quality DAQE This is a document tracking code for internal Division of Air Quality use EPA Environmental Protection Agency FDCP Fugitive dust control plan GHG Greenhouse Gas(es) - Title 40 of the Code of Federal Regulations 52.21 (b)(49)(i) GWP Global Warming Potential - Title 40 of the Code of Federal Regulations Part 86.1818- 12(a) HAP or HAPs Hazardous air pollutant(s) ITA Intent to Approve LB/YR Pounds per year MACT Maximum Achievable Control Technology MMBTU Million British Thermal Units NAA Nonattainment Area NAAQS National Ambient Air Quality Standards NESHAP National Emission Standards for Hazardous Air Pollutants NOI Notice of Intent NOx Oxides of nitrogen NSPS New Source Performance Standard NSR New Source Review PM10 Particulate matter less than 10 microns in size PM2.5 Particulate matter less than 2.5 microns in size PSD Prevention of Significant Deterioration PTE Potential to Emit R307 Rules Series 307 R307-401 Rules Series 307 - Section 401 SO2 Sulfur dioxide Title IV Title IV of the Clean Air Act Title V Title V of the Clean Air Act TPY Tons per year UAC Utah Administrative Code VOC Volatile organic compounds DAQE-IN102190018-24 May 9, 2024 Ted Meinhold Kinder Morgan Altamont LLC 1667 Cole Boulevard, Suite 300 Lakewood, CO 81401 erin_dunman@kindermorgan.com Dear Mr. Meinhold: Re: Intent to Approve: Modification to Approval Order DAQE-AN102190015-21, to Update Equipment and Emissions Project Number: N102190018 The attached document is the Intent to Approve (ITA) for the above-referenced project. The ITA is subject to public review. Any comments received shall be considered before an Approval Order (AO) is issued. The Division of Air Quality is authorized to charge a fee for reimbursement of the actual costs incurred in the issuance of an AO. An invoice will follow upon issuance of the final AO. Future correspondence on this ITA should include the engineer's name, Tad Anderson, as well as the DAQE number as shown on the upper right-hand corner of this letter. Tad Anderson, can be reached at (385) 306-6515 or tdanderson@utah.gov, if you have any questions. Sincerely, {{$s }} Jon L. Black, Manager New Source Review Section JLB:TA:jg cc: TriCounty Health Department EPA Region 8 195 North 1950 West • Salt Lake City, UT Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820 Telephone (801) 536-4000 • Fax (801) 536-4099 • T.D.D. (801) 536-4414 www.deq.utah.gov Printed on 100% recycled paper State of Utah SPENCER J. COX Governor DEIDRE HENDERSON Lieutenant Governor Department of Environmental Quality Kimberly D. Shelley Executive Director DIVISION OF AIR QUALITY Bryce C. Bird Director * ) ' & — 4 E v A ? A C @ @ w @ H ˜ STATE OF UTAH Department of Environmental Quality Division of Air Quality INTENT TO APPROVE DAQE-IN102190018-24 Modification to Approval Order DAQE-AN102190015-21 to Update Equipment and Emissions Prepared By Tad Anderson, Engineer (385) 306-6515 tdanderson@utah.gov Issued to Kinder Morgan Altamont LLC - Bluebell Facility Issued On May 9, 2024 {{$s }} New Source Review Section Manager Jon L. Black {{#s=Sig_es_:signer1:signature}} * ) ' & — 4 E v A ? A C @ @ w @ H ˜ TABLE OF CONTENTS TITLE/SIGNATURE PAGE ....................................................................................................... 1 GENERAL INFORMATION ...................................................................................................... 3 CONTACT/LOCATION INFORMATION ............................................................................... 3 SOURCE INFORMATION ........................................................................................................ 3 General Description ................................................................................................................ 3 NSR Classification .................................................................................................................. 3 Source Classification .............................................................................................................. 3 Applicable Federal Standards ................................................................................................. 3 Project Description.................................................................................................................. 4 SUMMARY OF EMISSIONS .................................................................................................... 4 PUBLIC NOTICE STATEMENT............................................................................................... 5 SECTION I: GENERAL PROVISIONS .................................................................................... 5 SECTION II: PERMITTED EQUIPMENT .............................................................................. 6 SECTION II: SPECIAL PROVISIONS ..................................................................................... 9 PERMIT HISTORY ................................................................................................................... 13 ACRONYMS ............................................................................................................................... 14 DAQE-IN102190018-24 Page 3 GENERAL INFORMATION CONTACT/LOCATION INFORMATION Owner Name Source Name Kinder Morgan Altamont LLC Kinder Morgan Altamont LLC - Bluebell Facility Mailing Address Physical Address 1667 Cole Boulevard, Suite 300 Sec 20 T1S R5W Lakewood, CO 81401 Altamont, UT 84001 Source Contact UTM Coordinates Name: Erin Dunman 577,604 m Easting Phone: (303) 914-7605 4,470,289 m Northing Email: erin_dunman@kindermorgan.com Datum NAD27 UTM Zone 12 SIC code 1321 (Natural Gas Liquids) SOURCE INFORMATION General Description Kinder Morgan Altamont LLC (Kinder Morgan), Bluebell Gas Plant's functions are to dehydrate field gas and extract NGL's. Field gas enters the facility through trunk lines that combine into the main facility inlet. The inlet gas stream is directed to the slug catcher, where free water and condensate are separated from the field gas. The water and condensate are directed to the existing storage tanks before being trucked from the facility. The Bluebell Compressor Station is designed to compress, treat, and dehydrate up to 30 MMscfd of natural gas and generate up to 278 bpd of condensate. NSR Classification Minor Modification at Major Source Source Classification Located in Uinta Basin O3 NAA Duchesne County Airs Source Size: A Applicable Federal Standards NSPS (Part 60), A: General Provisions NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal Combustion Engines NSPS (Part 60), OOOOa: Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 MACT (Part 63), A: General Provisions MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for DAQE-IN102190018-24 Page 4 Stationary Reciprocating Internal Combustion Engines Title V (Part 70) Major Source Project Description Kinder Morgan has requested to update the Bluebell Compressor Station (CS) as follows: -Installation of a flare (FL-1) to control emissions from existing condensate tanks CS T-211, CS T-212, CS T-213, and CS T-214 -Replacement of the existing combustor (COM-2) with a flare (FL-2) to control emissions from existing condensate tanks Gas Processing Plant (GPP) TK-870 and GPP-TK-874 -Update represented potential to emit from condensate truck loading activities Process Description The Bluebell Gas Plant's functions are to dehydrate field gas and extract NGLs. Field gas enters the facility through trunk lines. The inlet gas stream is directed to the slug catcher, where free water and condensate are separated from the field gas. The water and condensate are directed to the existing storage tanks before being trucked from the facility. Field gas from the slug catcher is directed to the inlet compressors. Any liquid collected from the second and third stage inlet compressor scrubbers is directed to an intermediate 3-phase flash separator (V-405). The condensate from V-405 is routed to tanks GPP-870 and GPP-874, which are controlled with a combustor. After compression Ethylene Glycol (EG) is injected into the gas to prevent hydrates from forming prior to the gas going through a series of heat exchangers and a propane chiller to cool down the gas. EG and NGL are separated from the gas in the cold separator. The rich EG is sent to a flash tank, where free gas is separated and sent to a combustor for control. The EG is then sent to a regenerator. Water vapor from the EG regenerator is sent to TK-837, where the uncondensed vapor is controlled by a combustor. NGLs are then sent to a de-ethanizer tower, where light-end hydrocarbons are removed and sent to the fuel gas system. The NGL is then sent to pressurized bullet tanks for storage prior to being trucked off site. The Bluebell Gas Plant and the Bluebell CS are equipped with a flare to manage unplanned pressure relief events, planned and unplanned maintenance activities, and plant emergency shutdowns. SUMMARY OF EMISSIONS The emissions listed below are an estimate of the total potential emissions from the source. Some rounding of emissions is possible. Criteria Pollutant Change (TPY) Total (TPY) CO2 Equivalent 0 108176.00 Carbon Monoxide 5.24 109.52 Nitrogen Oxides 1.10 132.54 Particulate Matter - PM10 0.14 3.78 Particulate Matter - PM2.5 0.14 3.78 Sulfur Oxides 0.01 1.44 Volatile Organic Compounds 1.48 112.25 DAQE-IN102190018-24 Page 5 Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr) 1,3-Butadiene (CAS #106990) 0 78 2,2,4-Trimethylpentane (CAS #540841) 0 220 Acetaldehyde (CAS #75070) 0 1838 Acrolein (CAS #107028) 0 1820 Benzene (Including Benzene from Gasoline) (CAS #71432) 0 820 Biphenyl (CAS #92524) 0 44 Ethyl Benzene (CAS #100414) 0 29 Formaldehyde (CAS #50000) 0 12580 Generic HAPs (CAS #GHAPS) 20 2020 Hexane (CAS #110543) 0 2986 Methanol (CAS #67561) 0 1146 Toluene (CAS #108883) 0 480 Xylenes (Isomers and Mixture) (CAS #1330207) 0 204 Change (TPY) Total (TPY) Total HAPs 0.01 12.13 PUBLIC NOTICE STATEMENT The NOI for the above-referenced project has been evaluated and has been found to be consistent with the requirements of UAC R307. Air pollution producing sources and/or their air control facilities may not be constructed, installed, established, or modified prior to the issuance of an AO by the Director. A 30-day public comment period will be held in accordance with UAC R307-401-7. A notification of the intent to approve will be published in the Vernal Express on May 15, 2024. During the public comment period the proposal and the evaluation of its impact on air quality will be available for the public to review and provide comment. If anyone so requests a public hearing within 15 days of publication, it will be held in accordance with UAC R307-401-7. The hearing will be held as close as practicable to the location of the source. Any comments received during the public comment period and the hearing will be evaluated. The proposed conditions of the AO may be changed as a result of the comments received. SECTION I: GENERAL PROVISIONS The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the AO. I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions refer to those rules. [R307-101] I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401] I.3 Modifications to the equipment or processes approved by this AO that could affect the emissions covered by this AO must be reviewed and approved. [R307-401-1] DAQE-IN102190018-24 Page 6 I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by the owner/operator, shall be made available to the Director or Director's representative upon request, and the records shall include the five (5)-year period prior to the date of the request. Unless otherwise specified in this AO or in other applicable state and federal rules, records shall be kept for a minimum of five (5) years. [R307-401-8] I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators shall, to the extent practicable, maintain and operate any equipment approved under this AO, including associated air pollution control equipment, in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Director which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. All maintenance performed on equipment authorized by this AO shall be recorded. [R307-401-4] I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns. [R307-107] I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories. [R307-150] I.8 The owner/operator shall submit documentation of the status of installation of FL-1 and FL-2 to the Director within 18 months from the date of this AO. This AO may become invalid if construction is not commenced within 18 months from the date of this AO or if construction is discontinued for 18 months or more. To ensure proper credit when notifying the Director, send the documentation to the Director, attn.: NSR Section. [R307-401-18] SECTION II: PERMITTED EQUIPMENT The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the AO. II.A THE APPROVED EQUIPMENT II.A.1 Bluebell Facility Natural Gas CS and Natural GPP II.A.2 CS RICE-1 and RICE-2 Natural gas fired IC engines, 4SLB Capacity: 1,150 hp (each) Controls: Oxidation Catalyst II.A.3 CS RICE-3 Natural gas fired IC engine, 4SRB Capacity: 1,478 hp Controls: AFRC and NSCR II.A.4 CS H-1 Line Heater Capacity: 0.25 MMBtu/hr DAQE-IN102190018-24 Page 7 II.A.5 CS T-211 thru 214 Four (4) Field Condensate Storage Tanks Capacity: 400 bbl (each) II.A.6 CS T-951, T-952, and T-953 Three (3) Methanol Storage Tanks Capacity: T-951, 140 bbl T-952, 100 bbl T-953, 140 bbl II.A.7 CS T-943 Glycol Storage Tank Capacity: 50 bbl II.A.8 CS T-941 Lube Oil Storage Vessel Capacity:200 bbl II.A.9 CS FL-1 (NEW) Capacity: 121 scfh (pilot) Controlling Condensate Storage Tanks; CS T-211, CS T-212, CS T-213, and CS T-214 II.A.10 GPP C-250 and C-251 Natural gas-fired IC engines, 4SLB Capacity: 1,340 hp (each) Controls: AFR and Oxidation Catalyst Not applicable to 40 CFR 60 Subpart JJJJ Applicable to 40 CFR 63, Subpart ZZZZ II.A.11 GPP C-252 and C-253 Natural gas-fired IC engines, 4SLB Capacity: 1,380 hp (each) Controls: AFR and Oxidation Catalyst Applicable to 40 CFR 60 Subpart JJJJ II.A.12 GPP C-258 Natural gas-fired IC engines, 4SRB Capacity: 1,900 hp Controls: NSCR Applicable to 40 CFR 60 Subpart JJJJ II.A.13 GPP C-161 and C162 Natural gas-fired IC engines, 4SLB Capacity: 691 hp (each) Controls: AFR and Oxidation Catalyst Applicable to 40 CFR 60 Subpart JJJJ II.A.14 GPP C-163 Natural gas-fired IC engine, 4SLB Capacity: 691 hp Controls: AFR and Oxidation Catalyst Applicable to 40 CFR 60 Subpart JJJJ DAQE-IN102190018-24 Page 8 II.A.15 GPP C-256 and C-257 Natural gas-fired IC engines, 4SRB Capacity: 400 hp (each) Controls: NSCR Applicable to 40 CFR 60 Subpart JJJJ II.A.16 GPP H-1 Natural gas-fired Process Heater Capacity: 6 MMBtu/hr Control: Ultra-low NOx burner (25 ppm NOx) II.A.17 GPP Dehy-1 EG Dehydration Unit with electrical regen Capacity: 30 MMscf/day Control: Combustor II.A.18 GPP COM-1 Combustors Capacity: 121 scfh (pilot) + 735 scfh (assist) II.A.19 GPP FL-2 (NEW) Flare Capacity: 121 scfh (pilot) II.A.20 GPP TK-870 and TK-874 Condensate Storage Tanks Capacity: 400 bbl (each) Control: Flare II.A.21 GPP TK-880 Used Oil Tank Capacity: 400 bbl II.A.22 GPP TK-872 Methanol Storage Tank Capacity: 8,820 gallons II.A.23 GPP TK-837 BTEX Water K.O. Tank Capacity: 100 bbl Control: Combustor II.A.24 Miscellaneous Tanks Tank capacities: no greater than 400 bbl (each). Material stored: lube oil, used lube oil, auxiliary water storage, ultra-fab H2S scavenger, and used ultra-fab H2S scavenger II.A.25 FUG Fugitive Emissions GPP applicable to 40 CFR 60 Subpart OOOOa II.A.26 GPP TL GPP Condensate Truck Loading Control: Vapor Capture Line DAQE-IN102190018-24 Page 9 II.A.27 FL-1001 Process/Emergency Flare Capacity: 50MMscfd Servicing both CS and GPP SECTION II: SPECIAL PROVISIONS The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the AO. II.B REQUIREMENTS AND LIMITATIONS II.B.1 Facility Wide Requirements II.B.1.a Visible emissions from the following emission points shall not exceed the following values: A. All-natural gas operated equipment and tanks - 10% opacity. B. All other points - 20% opacity Opacity observations of emissions from stationary sources shall be conducted according to 40 CFR 60, Appendix A, Method 9. [R307-401-8] II.B.1.b The following production limits shall not be exceeded: 30 million standard dry cubic feet of processed natural gas per day To determine compliance with a rolling 12-month total, the owner/operator shall calculate a new 12-month total by the twentieth day of each month using data from the previous 12 months. Records of production shall be kept for all periods when the plant is in operation. Production shall be determined by gas flow meters for natural gas and the hours of operation. Records of processing and production shall be kept on a daily basis. Hours of operation shall be determined by supervisor monitoring and maintaining of an operations log. [R307-401-8] II.B.1.c All emissions from the Condensate Storage Tanks (CS T-211, CS T-212, CS T-213, CS T-214, GPP TK-870, and 874) and Dehydration unit (GPP Dehy-01) must be routed to either Combustor or flares (CS FL-1, GPP FL-2, or GPP COM-1). [R307-401-8] DAQE-IN102190018-24 Page 10 II.B.2 Engines Testing Requirements II.B.2.a Source: CS RICE-1 and CS RICE-2 Pollutant lb/hr NOX 3.8 (each) CO 0.31(each) Source: CS RICE-3 Pollutant lb/hr NOX 1.3 CO 0.55 Source: GPP C-250 and C-251 Pollutant lb/hr NOX 4.43 (each) CO 1.68 (each) VOC 2.07 (each) Source: GPP C-252 and C-253 Pollutant lb/hr NOX 2.13 (each) CO 2.44 (each) VOC 2.13 (each) Source: GPP C-161, C-162 and C-163 Pollutant lb/hr NOX 0.76 (each) CO 1.24 (each) VOC 1.07 (each) Source: GPP C-258 Pollutant lb/hr NOX 2.09 CO 3.35 VOC 2.09 [40 CFR 60 Subpart JJJJ, R307-401-8] DAQE-IN102190018-24 Page 11 II.B.2.b Stack testing to show compliance with the emission limitations stated in the above condition shall be performed as specified below: A. Engine Testing Requirements Emitting Units CS RICE-1 thru 3, GPP C-250 C-251, C-252, C-253, C-161, and C-162 Pollutant Status Frequency NOx ** @ CO ** @ VOC ** @ Emitting Unit GPP C-258 and C-163 Pollutant Status Frequency NOx ** @ CO ** @ VOC ** @ B. Testing Status ** Initial compliance testing already completed. @ Emissions shall be tested every three (3) years or annually, if a portable testing analyzer is used. C. Notification The Director shall be notified at least 30 days prior to conducting any required emission testing. A source test protocol shall be submitted to DAQ when the testing notification is submitted to the Director. The source test protocol shall be approved by the Director prior to performing the test(s). The source test protocol shall outline the proposed test methodologies, stacks to be tested, and procedures to be used. A pretest conference shall be held, if directed by the Director. D. Sample Location The emission point shall be designed to conform to the requirements of 40 CFR 60, Appendix A, Method 1, or other EPA testing methods acceptable to the Director. An Occupational Safety and Health Administration (OSHA) or Mine Safety and Health Administration (MSHA) approved access shall be provided to the test location. E. Volumetric Flow Rate 40 CFR 60, Appendix A, Method 2, Method 19, or other EPA testing methods acceptable to the Director. F. Nitrogen Oxides (NOx) 40 CFR 60, Appendix A, Method 7, 7A, 7B, 7C, 7D or 7E, or other EPA testing methods acceptable to the Director. G. Carbon Monoxide (CO) 40 CFR 60, Appendix A, Method 10, or other EPA testing methods acceptable to the Director. H. Volatile Organic Carbon (VOC) 40 CFR 60, Appendix A, Method 18, 25, 25A, 40 CFR 63, Appendix A, Method 320, or other EPA-approved testing method, as acceptable to the Director. I. Calculations To determine mass emission rates (lb/hr, etc.), the pollutant concentration as determined by the appropriate methods above shall be multiplied by the volumetric flow rate and any necessary conversion factors determined by the Director, to give the results in the specified units of the emission limitation. DAQE-IN102190018-24 Page 12 J. New Source Operation For a new source/emission point, the combustion rate during all compliance testing shall be no less than 90% of the capacity listed in Section II.A. If the maximum AO allowable combustion rate has not been achieved at the time of the test, the following procedure shall be followed: 1) Testing shall be at no less than 90% of the combustion rate achieved to date. 2) If the test is passed, the new maximum allowable combustion rate shall be 110% of the tested achieved rate, but not more than the maximum allowable combustion rate. This new allowable maximum combustion rate shall remain in effect until successfully tested at a higher rate. 3) The owner/operator shall request a higher combustion rate when necessary. Testing at no less than 90% of the higher rate shall be conducted. A new maximum combustion rate (110% of the new rate) will then be allowed if the test is successful. This process may be repeated until the maximum AO combustion rate is achieved. K. Existing Source Operation For an existing source/emission point, the combustion rate during all compliance testing shall be no less than 90% of the maximum combustion rate achieved in the previous three (3) years. [40 CFR 60 Subpart JJJJ, R307-401-8] II.B.3 Storage Tank (Storage Vessel) Requirements II.B.3.a The owner/operator shall not produce more than 101,191 barrels (1 barrel = 42 gallons) of condensate per rolling 12-month period from the Bluebell CS. [R307-401-8] II.B.3.a.1 The owner/operator shall: A. Determine condensate production with process flow meters and/or sales records. B. Record condensate production on a daily basis. C. Calculate a new 12-month total by the 20th day of each month using data from the previous 12 months. D. Keep the production records for all periods the plant is in operation. [R307-401-8] II.B.3.b At all times after startup of production, the owner/operator shall route all gases, vapors, and fumes from the condensate storage tanks at the gas plant to the operating combustor/flare. [R307-401-8] II.B.3.c The owner/operator shall keep the storage tank thief hatches and other tank openings closed and sealed except during tank unloading or other maintenance activities. [R307-401-8] DAQE-IN102190018-24 Page 13 II.B.4 Monitoring Requirements of Fugitive Emissions (Leak Detection and Repair) II.B.4.a The Bluebell GPP is subject to the LDAR requirements in 40 CFR 60 Subpart OOOOa. [40 CFR 60 Subpart OOOOa] II.B.5 Truck Loading Requirements II.B.5.a The owner/operator shall load the tanker trucks on site by the use of submerged loading. [R307-401-8] II.B.5.b The owner/operator shall connect a vapor capture line to the operating combustor for use during on-site condensate truck loading operations at the GPP. The vapor capture line shall be used at all times during loading operations. [R307-401-8] II.B.6 Combustor and Flare Requirements II.B.6.a Each combustor and flare shall operate with a continuous pilot flame and be equipped with an auto-igniter. [R307-401-8] II.B.6.a.1 Records shall be kept that demonstrate that each combustor and flare operate with a continuous pilot flame. The permittee shall maintain records demonstrating the date of installation and manufacturer specifications for each auto-igniter. [R307-401-8] II.B.6.b Each combustor and flare shall operate with no visible emissions. [R307-401-8] II.B.6.b.1 Visual determination of emissions from each combustor and flare shall be conducted according to 40 CFR 60, Appendix A, Method 22. [R307-401-8] II.B.6.b.2 Visible emission determination shall be conducted on each combustor and flare once each month, while the combustor and flare are operating. The determination period shall be 15 minutes. The observer shall be trained and knowledgeable with respect to the general procedures for determining the presence of visible emissions as specified in Method 22, Section 2.3. [R307-401-8] PERMIT HISTORY This Approval Order shall supersede (if a modification) or will be based on the following documents: Supersedes AO DAQE-AN102190015-21 dated June 7, 2021 Is Derived From NOI dated December 27, 2023 DAQE-IN102190018-24 Page 14 ACRONYMS The following lists commonly used acronyms and associated translations as they apply to this document: 40 CFR Title 40 of the Code of Federal Regulations AO Approval Order BACT Best Available Control Technology CAA Clean Air Act CAAA Clean Air Act Amendments CDS Classification Data System (used by Environmental Protection Agency to classify sources by size/type) CEM Continuous emissions monitor CEMS Continuous emissions monitoring system CFR Code of Federal Regulations CMS Continuous monitoring system CO Carbon monoxide CO2 Carbon Dioxide CO2e Carbon Dioxide Equivalent - Title 40 of the Code of Federal Regulations Part 98, Subpart A, Table A-1 COM Continuous opacity monitor DAQ/UDAQ Division of Air Quality DAQE This is a document tracking code for internal Division of Air Quality use EPA Environmental Protection Agency FDCP Fugitive dust control plan GHG Greenhouse Gas(es) - Title 40 of the Code of Federal Regulations 52.21 (b)(49)(i) GWP Global Warming Potential - Title 40 of the Code of Federal Regulations Part 86.1818- 12(a) HAP or HAPs Hazardous air pollutant(s) ITA Intent to Approve LB/YR Pounds per year MACT Maximum Achievable Control Technology MMBTU Million British Thermal Units NAA Nonattainment Area NAAQS National Ambient Air Quality Standards NESHAP National Emission Standards for Hazardous Air Pollutants NOI Notice of Intent NOx Oxides of nitrogen NSPS New Source Performance Standard NSR New Source Review PM10 Particulate matter less than 10 microns in size PM2.5 Particulate matter less than 2.5 microns in size PSD Prevention of Significant Deterioration PTE Potential to Emit R307 Rules Series 307 R307-401 Rules Series 307 - Section 401 SO2 Sulfur dioxide Title IV Title IV of the Clean Air Act Title V Title V of the Clean Air Act TPY Tons per year UAC Utah Administrative Code VOC Volatile organic compounds DAQE-NN102190018-24 May 9, 2024 Vernal Express Legal Advertising Dept. 60 East 100 North Vernal, UT 840782122 RE: Legal Notice of Intent to Approve This letter will confirm the authorization to publish the attached NOTICE in the Vernal Express (Account Number: 2307) on May 15, 2024. Please mail the invoice and affidavit of publication to the Utah State Department of Environmental Quality, Division of Air Quality, P.O. Box 144820, Salt Lake City, Utah 84114-4820. If you have any questions, contact Jeree Greenwood, who may be reached at (385) 306-6514. Sincerely, {{$s }} Jeree Greenwood Office Technician Enclosure cc: Uintah Basin Association of Governments cc: Duchesne County 195 North 1950 West • Salt Lake City, UT Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820 Telephone (801) 536-4000 • Fax (801) 536-4099 • T.D.D. (801) 903-3978 www.deq.utah.gov Printed on 100% recycled paper State of Utah SPENCER J. COX Governor DEIDRE HENDERSON Lieutenant Governor Department of Environmental Quality Kimberly D. Shelley Executive Director DIVISION OF AIR QUALITY Bryce C. Bird Director DAQE-NN102190018-24 Page 2 NOTICE A Notice of Intent for the following project submitted in accordance with R307-401-1, Utah Administrative Code (UAC), has been received for consideration by the Director: Company Name: Kinder Morgan Altamont LLC Location: Kinder Morgan Altamont LLC - Bluebell Facility – Sec 20 T1S R5W, Altamont, UT Project Description: The Kinder Morgan Bluebell Gas Plant dehydrates field gas and extracts NGL's. Kinder Morgan has requested to update the Bluebell Compressor Station for the installation of a flare to control emissions from existing condensate tanks and replace an existing combustor with a flare. This modification will update the Potential to Emit emissions to current operations. The completed engineering evaluation and air quality impact analysis showed the proposed project meets the requirements of federal air quality regulations and the State air quality rules. The Director intends to issue an Approval Order pending a 30-day public comment period. The project proposal, estimate of the effect on local air quality and draft Approval Order are available for public inspection and comment at the Utah Division of Air Quality, 195 North 1950 West, Salt Lake City, UT 84116. Written comments received by the Division at this same address on or before June 14, 2024 will be considered in making the final decision on the approval/disapproval of the proposed project. Email comments will also be accepted at tdanderson@utah.gov. If anyone so requests to the Director in writing within 15 days of publication of this notice, a hearing will be held in accordance with R307-401-7, UAC. Under Section 19-1-301.5, a person who wishes to challenge a Permit Order may only raise an issue or argument during an adjudicatory proceeding that was raised during the public comment period and was supported with sufficient information or documentation to enable the Director to fully consider the substance and significance of the issue. Date of Notice: May 15, 2024 {{#s=Sig_es_:signer1:signature}} Vernal Express Publication Name: Vernal Express Publication URL: ubmedia.biz Publication City and State: Vernal, UT Publication County: Uintah Notice Popular Keyword Category: Notice Keywords: kinder Notice Authentication Number: 202405150950049942632 3429962642 Notice URL: Back Notice Publish Date: Wednesday, May 15, 2024 Notice Content NOTICE A Notice of Intent for the following project submitted in accordance with R307-401-1, Utah Administrative Code (UAC), has been received for consideration by the Director: Company Name: Location: Kinder Morgan Altamont LLC Kinder Morgan Altamont LLC - Bluebell Facility - Sec 20 T1S R5W, Altamont, UT Project Description: The Kinder Morgan Bluebell Gas Plant dehydrates field gas and extracts NGL's. Kinder Morgan has requested to update the Bluebell Compressor Station for the installation of a flare to control emissions from existing condensate tanks and replace an existing combustor with a flare. This modification will update the Potential to Emit emissions to current operations. The completed engineering evaluation and air quality impact analysis showed the proposed project meets the requirements of federal air quality regulations and the State air quality rules. The Director intends to issue an Approval Order pending a 30-day public comment period. The project proposal, estimate of the effect on local air quality and draft Approval Order are available for public inspection and comment at the Utah Division of Air Quality, 195 North 1950 West, Salt Lake City, UT 84116. Written comments received by the Division at this same address on or before June 14, 2024 will be considered in making the final decision on the approval/disapproval of the proposed project. Email comments will also be accepted at tdanderson@utah.gov. If anyone so requests to the Director in writing within 15 days of publication of this notice, a hearing will be held in accordance with R307-401-7, UAC. Under Section 19-1-301.5, a person who wishes to challenge a Permit Order may only raise an issue or argument during an adjudicatory proceeding that was raised during the public comment period and was supported with sufficient information or documentation to enable the Director to fully consider the substance and significance of the issue. Date of Notice: May 15, 2024 Back 5/15/24, 8:50 AM utahlegals.com/(S(pkwarievrknqy4esrvi4lz0u))/DetailsPrint.aspx?SID=pkwarievrknqy4esrvi4lz0u&ID=184959 https://www.utahlegals.com/(S(pkwarievrknqy4esrvi4lz0u))/DetailsPrint.aspx?SID=pkwarievrknqy4esrvi4lz0u&ID=184959 1/1 DAQE- RN102190018 March 15, 2024 Ted Meinhold Kinder Morgan Altamont LLC 1667 Cole Blvd, Suite 300 Lakewood, CO 81401 erin_dunman@kindermorgan.com Dear Ted Meinhold, Re: Engineer Review: Modification to Approval Order DAQE-AN102190015-21, to Update Equipment and Emissions Project Number: N102190018 Please review and sign this letter and attached Engineer Review (ER) within 10 business days. For this document to be considered as the application for a Title V administrative amendment, a Title V Responsible Official must sign the next page. Please contact Tad Anderson at (385) 306-6515 if you have any questions or concerns about the ER. If you accept the contents of this ER, please email this signed cover letter to Tad Anderson at tdanderson@utah.gov. After receipt of the signed cover letter, the DAQ will prepare an Intent to Approve (ITA) for a 30-day public comment period. When the public comment period ends, the DAQ will consider any comments received and will issue the Approval Order. If you do not respond to this letter within 10 business days, the project will move forward without your approval. If you have concerns that we cannot resolve, the DAQ Director may issue an Order prohibiting construction. Approval Signature _____________________________________________________________ (Signature & Date) 195 North 1950 West • Salt Lake City, UT Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820 Telephone (801) 536-4000 • Fax (801) 536-4099 • T.D.D. (801) 903-3978 www.deq.utah.gov Printed on 100% recycled paper Department of Environmental Quality Kimberly D. Shelley Executive Director DIVISION OF AIR QUALITY Bryce C. Bird Director State of Utah SPENCER J. COX Governor DEIDRE HENDERSON Lieutenant Governor Engineer Review N102190018: Kinder Morgan Altamont LLC - Bluebell Facility March 15, 2024 Page 1 OPTIONAL: In order for this Engineer Review and associated Approval Order conditions to be considered as an application to administratively amend your Title V Permit, the Responsible Official, as defined in R307-415-3, must sign the statement below. THIS IS STRICTLY OPTIONAL. If you do not want the Engineer Review to be considered as an application to administratively amend your Operating Permit only the approval signature above is required. Failure to have the Responsible Official sign below will not delay the Approval Order, but will require submittal of a separate Operating Permit Application to revise the Title V permit in accordance with R307-415-5a through 5e and R307-415-7a through 7i. A guidance document: Title V Operating Permit Application Due Dates clarifies the required due dates for Title V operating permit applications and can be viewed at: https://deq.utah.gov/air-quality/permitting-guidance-and-guidelines-air-quality “Based on information and belief formed after reasonable inquiry, I certify that the statements and information provided for this Approval Order are true, accurate and complete and request that this Approval Order be considered as an application to administratively amend the Operating Permit.” Responsible Official _________________________________________________ (Signature & Date) Print Name of Responsible Official _____________________________________ Engineer Review N102190018: Kinder Morgan Altamont LLC - Bluebell Facility March 15, 2024 Page 2 UTAH DIVISION OF AIR QUALITY ENGINEER REVIEW SOURCE INFORMATION Project Number N102190018 Owner Name Kinder Morgan Altamont LLC Mailing Address 1001 Louisiana Street, Suite 1000 Houston, TX, 77002 Source Name Kinder Morgan Altamont LLC - Bluebell Facility Source Location Sec 20 T1S R5W Altamont, UT 84001 UTM Projection 577,604 m Easting, 4,470,289 m Northing UTM Datum NAD27 UTM Zone UTM Zone 12 SIC Code 1321 (Natural Gas Liquids) Source Contact Erin Dunman Phone Number (303) 914-7605 Email erin_dunman@kindermorgan.com Billing Contact Erin Dunman Phone Number 303-914-7605 Email erin_dunman@kindermorgan.com Project Engineer Tad Anderson, Engineer Phone Number (385) 306-6515 Email tdanderson@utah.gov Notice of Intent (NOI) Submitted December 27, 2023 Date of Accepted Application February 20, 2024 Engineer Review N102190018: Kinder Morgan Altamont LLC - Bluebell Facility March 15, 2024 Page 3 SOURCE DESCRIPTION General Description Kinder Morgan Altamont, LLC (Kinder Morgan), Bluebell Gas Plant's functions to dehydrate field gas and extract NGL's. Field gas enters the facility through trunk lines that combine into the main facility inlet. The inlet gas stream is directed to the slug catcher where free water and condensate are separated from the field gas. The water and condensate are directed to the existing storage tanks before being trucked from the facility. The Bluebell Compressor Station is designed to compress, treat, and dehydrate up to 30 MMscfd of natural gas and generate up to 278 bpd of condensate. NSR Classification: Minor Modification at Major Source Source Classification Located in, Uinta Basin O3 NAA, Duchesne County Airs Source Size: A Applicable Federal Standards NSPS (Part 60), A: General Provisions NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal Combustion Engines NSPS (Part 60), OOOOa: Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015 MACT (Part 63), A: General Provisions MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Title V (Part 70) Major Source Project Proposal Modification to Approval Order DAQE-AN102190015-21, to Update Equipment and Emissions Project Description Kinder Morgan has requested to update the Bluebell Compressor Station (CS) as follows: -Installation of a flare (FL-1) to control emissions from existing condensate tanks CS T-211, CS T-212, CS T-213, and CS T-214 -Replacement of existing combustor (COM-2) with a flare (FL-2) to control emissions from existing condensate tanks GPP TK-870 and GPP-TK-874 -Update represented potential to emit from condensate truck loading activities Process Description The Bluebell Gas Plant's functions to dehydrate field gas and extract NGL's. Field gas enters the facility through trunk lines. The inlet gas stream is directed to the slug catcher where free water and condensate are separated from the field gas. The water and condensate are directed to the existing storage tanks before being trucked from the facility. Field gas from the slug catcher is directed to the inlet compressors. Any liquid collected from the second and third stage inlet compressor scrubbers is directed to an intermediate 3-phase flash Engineer Review N102190018: Kinder Morgan Altamont LLC - Bluebell Facility March 15, 2024 Page 4 separator V-405. The condensate from V-405 is routed to tanks GPP-870 and GPP-874, which are controlled with a combustor. After compression Ethylene Glycol (EG) is injected into the gas to prevent hydrates from forming prior to the gas going through a series of heat exchangers and a propane chiller to cool down the gas. EG and NGL are separated from the gas in the cold separator. The rich EG is sent to a flash tank where free gas is separated and sent to a combustor for control. The EG is then sent to a regenerator. Water vapor from the EG regenerator is sent to TK-837 where the uncondensed vapor is controlled by a combustor. NGLs are then sent to a de-ethanizer tower where light end hydrocarbons are removed and sent to the fuel gas system. The NGL is then sent to pressurized bullet tanks for storage prior to being trucked off site. The Bluebell Gas Plant and the Bluebell CS is equipped with a flare to manage unplanned pressure relief events, planned and unplanned maintenance activities, and plant emergency shutdowns. EMISSION IMPACT ANALYSIS Modeling is not required as per R307-410-4 and R307-410-5. [Last updated January 19, 2024] Engineer Review N102190018: Kinder Morgan Altamont LLC - Bluebell Facility March 15, 2024 Page 5 SUMMARY OF EMISSIONS The emissions listed below are an estimate of the total potential emissions from the source. Some rounding of emissions is possible. Criteria Pollutant Change (TPY) Total (TPY) CO2 Equivalent 0 108176.00 Carbon Monoxide 5.24 109.52 Nitrogen Oxides 1.10 132.54 Particulate Matter - PM10 0.14 3.78 Particulate Matter - PM2.5 0.14 3.78 Sulfur Oxides 0.01 1.44 Volatile Organic Compounds 1.48 112.25 Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr) 1,3-Butadiene (CAS #106990) 0 78 2,2,4-Trimethylpentane (CAS #540841) 0 220 Acetaldehyde (CAS #75070) 0 1838 Acrolein (CAS #107028) 0 1820 Benzene (Including Benzene From Gasoline) (CAS #71432) 0 820 Biphenyl (CAS #92524) 0 44 Ethyl Benzene (CAS #100414) 0 29 Formaldehyde (CAS #50000) 0 12580 Generic HAPs (CAS #GHAPS) 20 2020 Hexane (CAS #110543) 0 2986 Methanol (CAS #67561) 0 1146 Toluene (CAS #108883) 0 480 Xylenes (Isomers And Mixture) (CAS #1330207) 0 204 Change (TPY) Total (TPY) Total HAPs 0.01 12.13 Note: Change in emissions indicates the difference between previous AO and proposed modification. Engineer Review N102190018: Kinder Morgan Altamont LLC - Bluebell Facility March 15, 2024 Page 6 Review of BACT for New/Modified Emission Units 1. BACT review regarding BACT A BACT analysis was conducted and reviewed VOCs from liquid storage tanks and tank truck loading operations. The equipment reviewed included the three (3) existing condensate storage tanks and existing pit tank on the compressor station side of the facility, the two (2) existing condensate tanks on the gas plant side of the facility, and truck loading operations. The VOC emissions from condensate storage tanks and tank truck loading operations include capture and control. BACT for the condensate tanks operations using a tanker truck is the use of bottom filling or submerged fill pipe techniques. BACT to control VOC emissions from the liquid storage tanks and tank truck loading operations is the capture of emissions and routing to a flare or combustor. [Last updated March 7, 2024] SECTION I: GENERAL PROVISIONS The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the AO. (New or Modified conditions are indicated as “New” in the Outline Label): I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions refer to those rules. [R307-101] I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401] I.3 Modifications to the equipment or processes approved by this AO that could affect the emissions covered by this AO must be reviewed and approved. [R307-401-1] I.4 All records referenced in this AO or in other applicable rules, which are required to be kept by the owner/operator, shall be made available to the Director or Director's representative upon request, and the records shall include the five (5)-year period prior to the date of the request. Unless otherwise specified in this AO or in other applicable state and federal rules, records shall be kept for a minimum of five (5) years. [R307-401-8] I.5 At all times, including periods of startup, shutdown, and malfunction, owners and operators shall, to the extent practicable, maintain and operate any equipment approved under this AO, including associated air pollution control equipment, in a manner consistent with good air pollution control practice for minimizing emissions. Determination of whether acceptable operating and maintenance procedures are being used will be based on information available to the Director which may include, but is not limited to, monitoring results, opacity observations, review of operating and maintenance procedures, and inspection of the source. All maintenance performed on equipment authorized by this AO shall be recorded. [R307- 401-4] Engineer Review N102190018: Kinder Morgan Altamont LLC - Bluebell Facility March 15, 2024 Page 7 I.6 The owner/operator shall comply with UAC R307-107. General Requirements: Breakdowns. [R307-107] I.7 The owner/operator shall comply with UAC R307-150 Series. Emission Inventories. [R307- 150] I.8 The owner/operator shall submit documentation of the status of installation of FL-1 and FL-2 to the Director within 18 months from the date of this AO. This AO may become invalid if construction is not commenced within 18 months from the date of this AO or if construction is discontinued for 18 months or more. To ensure proper credit when notifying the Director, send the documentation to the Director, attn.: NSR Section. [R307-401-18] SECTION II: PERMITTED EQUIPMENT The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the AO. (New or Modified conditions are indicated as “New” in the Outline Label): II.A THE APPROVED EQUIPMENT II.A.1 Bluebell Facility Natural Gas Compressor Station (CS) and Natural Gas Process Plant (GPP) II.A.2 CS RICE-1 and RICE-2 Natural gas fired IC engines, 4SLB Capacity: 1,150 hp (each) Controls: Oxidation Catalyst II.A.3 CS RICE-3 Natural gas fired IC engine, 4SRB Capacity: 1,478 hp Controls: AFRC and NSCR II.A.4 CS H-1 Line Heater Capacity: 0.25 MMBtu/hr II.A.5 CS T-211 thru 214 Four (4) Field Condensate Storage Tanks Capacity: 400 bbl (each) II.A.6 CS T-951, T-952 and T-953 Three (3) Methanol Storage Tanks Capacity: T-951, 140 bbl T-952, 100 bbl T-953, 140 bbl II.A.7 CS T-943 Glycol Storage Tank Capacity: 50 bbl II.A.8 CS T-941 Lube Oil Storage Vessel Capacity: 200 bbl Engineer Review N102190018: Kinder Morgan Altamont LLC - Bluebell Facility March 15, 2024 Page 8 II.A.9 NEW CS FL-1 (NEW) Capacity: 121 scfh (pilot) Controlling Condensate Storage Tanks; CS T-211, CS T-212, CS T-213, and CS T-214 II.A.10 GPP C-250 and C-251 Natural gas fired IC engines, 4SLB Capacity: 1,340 hp (each) Controls: AFR and Oxidation Catalyst Not applicable to 40 CFR 60 Subpart JJJJ Applicable to 40 CFR 63 Subpart ZZZZ II.A.11 GPP C-252 and C-253 Natural gas fired IC engines, 4SLB Capacity: 1,380 hp (each) Controls: AFR and Oxidation Catalyst Applicable to 40 CFR 60 Subpart JJJJ II.A.12 GPP C-258 Natural gas-fired IC engines, 4SRB Capacity: 1,900 hp Controls: NSCR Applicable to 40 CFR 60 Subpart JJJJ II.A.13 GPP C-161 and C162 Natural gas fired IC engines, 4SLB Capacity: 691 hp (each) Controls: AFR and Oxidation Catalyst Applicable to 40 CFR 60 Subpart JJJJ II.A.14 GPP C-163 Natural gas fired IC engine, 4SLB Capacity: 691 hp Controls: AFR and Oxidation Catalyst Applicable to 40 CFR 60 Subpart JJJJ II.A.15 GPP C-256 and C-257 Natural gas fired IC engines, 4SRB Capacity: 400 hp (each) Controls: NSCR Applicable to 40 CFR 60 Subpart JJJJ II.A.16 GPP H-1 Natural gas fired Process Heater Capacity: 6 MMBtu/hr Control: Ultra low NOx burner (25 ppm NOx) II.A.17 GPP Dehy-1 EG Dehydration Unit with electrical regen Capacity: 30 MMscf/day Control: Combustor II.A.18 GPP COM-1 Combustors Capacity: 121 scfh (pilot)+735 scfh (assist) II.A.19 GPP FL-2 (NEW) Flare Capacity: 121 scfh (pilot) Engineer Review N102190018: Kinder Morgan Altamont LLC - Bluebell Facility March 15, 2024 Page 9 II.A.20 GPP TK-870 and TK-874 Condensate Storage Tanks Capacity: 400 bbl (each) Control: Flare II.A.21 GPP TK-880 Used Oil Tank Capacity: 400 bbl II.A.22 GPP TK-872 Methanol Storage Tank Capacity: 8,820 gallons II.A.23 GPP TK-837 BTEX Water K.O. Tank Capacity: 100 bbl Control: Combustor II.A.24 Miscellaneous Tanks Tank capacities: no greater than 400 bbl (each) Materiel stored: lube oil, used lube oil, auxiliary water storage, ultra-fab H2S scavenger and used ultra-fab H2S scavenger II.A.25 FUG Fugitive Emissions Gas Processing Plant applicable to 40 CFR 60 Subpart OOOOa II.A.26 GPP TL Gas Processing Plant Condensate Truck Loading Control: Vapor Capture Line II.A.27 FL-1001 Process/Emergency Flare Capacity: 50MMscfd Servicing both CS and GPP SECTION II: SPECIAL PROVISIONS The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the AO. (New or Modified conditions are indicated as “New” in the Outline Label): II.B REQUIREMENTS AND LIMITATIONS II.B.1 Facility Wide Requirements II.B.1.a Visible emissions from the following emission points shall not exceed the following values: A. All natural gas operated equipment and tanks - 10% opacity B. All other points - 20% opacity Opacity observations of emissions from stationary sources shall be conducted according to 40 CFR 60, Appendix A, Method 9. [R307-401-8] Engineer Review N102190018: Kinder Morgan Altamont LLC - Bluebell Facility March 15, 2024 Page 10 II.B.1.b The following production limits shall not be exceeded: 30 million standard dry cubic feet of processed natural gas per day To determine compliance with a rolling 12-month total, the owner/operator shall calculate a new 12-month total by the twentieth day of each month using data from the previous 12 months. Records of production shall be kept for all periods when the plant is in operation. Production shall be determined by gas flow meters for natural gas and hours of operation. The records of processing and production shall be kept on a daily basis. Hours of operation shall be determined by supervisor monitoring and maintaining of an operations log. [R307-401-8] II.B.1.c NEW All emissions from the Condensate Storage Tanks (CS T-211, CS T-212, CS T-213, CS T- 214, GPP TK-870, and 874) and Dehydration unit (GPP Dehy-01) must be routed to either Combustor or flares (CS FL-1, GPP FL-2 or GPP COM-1). [R307-401-8] II.B.2 Engines Testing Requirements II.B.2.b NEW Stack testing to show compliance with the emission limitations stated in the above condition shall be performed as specified below: A. Engine Testing Requirements Emitting Units CS RICE-1 thru 3, GPP C-250 C-251, C-252, C-253, C-161, and C-162 Pollutant Status Frequency NOx ** @ CO ** @ VOC ** @ Emitting Unit GPP C-258 and C-163 Pollutant Status Frequency NOx ** @ CO ** @ VOC ** @ B. Testing Status ** Initial compliance testing already completed. @ Emissions shall be tested every three years or annually, if a portable testing analyzer is used. C. Notification The Director shall be notified at least 30 days prior to conducting any required emission testing. A source test protocol shall be submitted to DAQ when the testing notification is submitted to the Director. The source test protocol shall be approved by the Director prior to performing the test(s). The source test protocol shall outline the proposed test methodologies, stack to be tested, and procedures to be used. A pretest conference shall be held, if directed by the Director. D. Sample Location Engineer Review N102190018: Kinder Morgan Altamont LLC - Bluebell Facility March 15, 2024 Page 11 The emission point shall be designed to conform to the requirements of 40 CFR 60, Appendix A, Method 1, or other EPA testing methods acceptable to the Director. An Occupational Safety and Health Administration (OSHA) or Mine Safety and Health Administration (MSHA) approved access shall be provided to the test location. E. Volumetric Flow Rate 40 CFR 60, Appendix A, Method 2, Method 19 or other EPA testing methods acceptable to the Director. F. Nitrogen Oxides (NOx) 40 CFR 60, Appendix A, Method 7, 7A, 7B, 7C, 7D or 7E, or other EPA testing methods acceptable to the Director. G. Carbon Monoxide (CO) 40 CFR 60, Appendix A, Method 10, or other EPA testing methods acceptable to the Director. H. Volatile Organic Carbon (VOC) 40 CFR 60, Appendix A, Method 18, 25, 25A, 40 CFR 63 Appendix A Method 320 or other EPA-approved testing method, as acceptable to the Director. I. Calculations To determine mass emission rates (lb/hr, etc.) the pollutant concentration as determined by the appropriate methods above shall be multiplied by the volumetric flow rate and any necessary conversion factors determined by the Director, to give the results in the specified units of the emission limitation. J. New Source Operation For a new source/emission point, the combustion rate during all compliance testing shall be no less than 90% of the capacity listed in Section II.A. If the maximum AO allowable combustion rate has not been achieved at the time of the test, the following procedure shall be followed: 1) Testing shall be at no less than 90% of the combustion rate achieved to date. 2) If the test is passed, the new maximum allowable combustion rate shall be 110% of the tested achieved rate, but not more than the maximum allowable combustion rate. This new allowable maximum combustion rate shall remain in effect until successfully tested at a higher rate. 3) The owner/operator shall request a higher combustion rate when necessary. Testing at no less than 90% of the higher rate shall be conducted. A new maximum combustion rate (110% of the new rate) will then be allowed if the test is successful. This process may be repeated until the maximum AO combustion rate is achieved. K. Existing Source Operation For an existing source/emission point, the combustion rate during all compliance testing shall be no less than 90% of the maximum combustion rate achieved in the previous three (3) years. [40 CFR 60 Subpart JJJJ, R307-401-8] II.B.3 Storage Tank (Storage Vessel) Requirements Engineer Review N102190018: Kinder Morgan Altamont LLC - Bluebell Facility March 15, 2024 Page 12 II.B.3.a The owner/operator shall not produce more than 101,191 barrels (1 barrel = 42 gallons) of condensate per rolling 12-month period from the Bluebell Compressor Station. [R307-401-8] II.B.3.a.1 The owner/operator shall: A. Determine condensate production with process flow meters and/or sales records. B. Record condensate production on a daily basis. C. Calculate a new 12-month total by the 20th day of each month using data from the previous 12 months. D. Keep the production records for all periods the plant is in operation. [R307-401-8] II.B.3.b NEW At all times after startup of production, the owner/operator shall route all gases, vapors, and fumes from the condensate storage tanks at the gas plant to the operating combustor/flare. [R307-401-8] II.B.3.c The owner/operator shall keep the storage tank thief hatches and other tank openings closed and sealed except during tank unloading or other maintenance activities. [R307-401-8] II.B.4 Monitoring Requirements of Fugitive Emissions (Leak Detection and Repair) II.B.4.a The Bluebell Gas Processing Plant is subject to the LDAR requirements in 40 CFR 60 Subpart OOOOa. [40 CFR 60 Subpart OOOOa] II.B.5 Truck Loading Requirements II.B.5.a The owner/operator shall load the tanker trucks on site by the use of submerged loading. [R307-401-8] II.B.5.b The owner/operator shall connect a vapor capture line to the operating combustor for use during on-site condensate truck loading operations at the Gas Processing Plant. The vapor capture line shall be used at all times during loading operations. [R307-401-8] II.B.6 Combustor and Flare Requirements II.B.6.a Each combustor and flare shall operate with a continuous pilot flame and be equipped with an auto-igniter. [R307-401-8] II.B.6.a.1 NEW Records shall be kept that demonstrate that each combustor and flare operate with a continuous pilot flame. The permittee shall maintain records demonstrating the date of installation and Manufacturer specifications for each auto-igniter. [R307-401-8] II.B.6.b Each combustor and flare shall operate with no visible emissions. [R307-401-8] II.B.6.b.1 Visual determination of emissions from each combustor and flare shall be conducted according to 40 CFR 60, Appendix A, Method 22. [R307-401-8] Engineer Review N102190018: Kinder Morgan Altamont LLC - Bluebell Facility March 15, 2024 Page 13 II.B.6.b.2 NEW Visible emission determination shall be conducted on each combustor and flare once each month, while the combustor and flare are operating. The determination period shall be 15 minutes. The observer shall be trained and knowledgeable with respect to the general procedures for determining the presence of visible emissions as specified in Method 22, Section 2.3. [R307-401-8] Engineer Review N102190018: Kinder Morgan Altamont LLC - Bluebell Facility March 15, 2024 Page 14 PERMIT HISTORY When issued, the approval order shall supersede (if a modification) or will be based on the following documents: Is Derived From NOI dated December 20, 2023 Supersedes DAQE-AN102190015-21 dated June 7, 2021 REVIEWER COMMENTS 1. Comment regarding Emission Estimates: The emissions from this modification involved the use of Promax model to determine the emissions (flashing losses, standing losses, and working losses) coming from the operation of the condensate storage tanks. The emissions from the condensate storage tanks are being routed to either a flare or combustor with a destruction efficiency of 98%. The truck loading emissions from the condensate tanks used emissions factors from AP-42 Table 5.2-1 with these emissions being routed to a flare. The flare/combustor emissions from the condensate tanks and truck loading used AP-42, Chapter 13, section 5, Tables 13.5 along with the emissions being controlled with a 98% destruction efficiency. [Last updated March 7, 2024] 2. Comment regarding Project Type: This project is being conducted as a permit modification, UAC R307-401-5. Since this permit action involves an emission increase, this action must be conducted as a modification. A BACT analysis was conducted on the condensate operation operations (condensate tanks working and breathing operations, and condensate truck loading). [Last updated February 21, 2024] 3. Comment regarding Flare Operations: In July 2023, Kinder Morgan conducted an environmental self-audit at the Bluebell Facility that included on-site measurements of condensate tank emissions. Tanks included in the measurement study were CS T-211 through T-214, GPP TK-870, and GPP TK-874. Kinder Morgan performed an analysis and review of these measurements and determined the resulting VOC emissions exceed the currently permitted emission rates. Kinder Morgan notified Utah Department of Environmental Quality (UDAQ) on August 2, 2023, a flare was installed and began operation on September 7, 2023, to control emissions from condensate tanks CS T-211 through CS T-214 as a Reduction of Air Pollutants UAC R307-401-12. Kinder Morgan also replaced the existing combustor (COM-2) with a flare (FL-2) to control emissions from condensate tanks GPP TK-870 and GPP TK-874 as a Replacement in kind UAC R307-401-11. [Last updated February 21, 2024] 4. Comment regarding Updated Emission Factors: During the environmental self-audit, it was determined that the VOC emissions from the condensate operations (condensate tanks working and breathing operations, and condensate truck loading) were underestimated. Kinder Morgan has requested to update the emissions associated with the condensate operations. The updated emissions for the entire project (updated emissions and addition of a Flare (F-1)) are as follows; +1.10 TPY of NOX, +5.24 TPY of CO, +1.48 TPY of VOC, +0.01 TPY of SO2, +0.14 TPY of PM10/PM2.5, +0.01 TPY of Single HAP, +0.06 TPY of combined HAPs, Engineer Review N102190018: Kinder Morgan Altamont LLC - Bluebell Facility March 15, 2024 Page 15 and +1,895 TPY of CO2e. The updated emissions increase does not change any classification or require an impact analysis by the source. [Last updated February 21, 2024] 5. Comment regarding Nonattainment Area: Kinder Morgan, Bluebell facility is in the Uintah Basin Ozone Marginal Nonattainment Area. The Kinder Morgan, Bluebell facility is classified as a major source and all emissions increase are below significant emissions levels (40 CFR 51.165(a)(1) (x)) so this increase is classified as a minor modification at a major source. [Last updated March 7, 2024] 6. Comment regarding Federal Requirement : The Kinder Morgan, Bluebell facility is a natural gas processing plant, as defined in §60.5430a, and commenced construction after September 8, 2015. This makes the Bluebell facility subject 40 CFR OOOOa, 60.5400a through 50.5402a (Equipment Leaks at Onshore Natural Gas Processing Plants) apply to all associated equipment located at the gas plant. [Last updated February 21, 2024] 7. Comment regarding Combination of the CS and GPP Site : Kinder Morgan has constructed the GPP on the north fence line of the CS. The Kinder Morgan Bluebell GPP meets the requirements of constructing adjacent to the CS and is owned and operated by the same company. Both facilities (GPP and CS) operate independently, but both facilities have the same first two digits SIC code. The combination of the two facilities classifies the Kinder Morgan Bluebell Facility as a major source requiring a Title V permit. This facility has two different independent operations at the facility. The Standard Industrial Classification Codes that are used for the permit is SICC 1321 (gas plant) and 1311 (compressor station). [Last updated March 7, 2024] Engineer Review N102190018: Kinder Morgan Altamont LLC - Bluebell Facility March 15, 2024 Page 16 ACRONYMS The following lists commonly used acronyms and associated translations as they apply to this document: 40 CFR Title 40 of the Code of Federal Regulations AO Approval Order BACT Best Available Control Technology CAA Clean Air Act CAAA Clean Air Act Amendments CDS Classification Data System (used by EPA to classify sources by size/type) CEM Continuous emissions monitor CEMS Continuous emissions monitoring system CFR Code of Federal Regulations CMS Continuous monitoring system CO Carbon monoxide CO2 Carbon Dioxide CO2e Carbon Dioxide Equivalent - 40 CFR Part 98, Subpart A, Table A-1 COM Continuous opacity monitor DAQ/UDAQ Division of Air Quality DAQE This is a document tracking code for internal UDAQ use EPA Environmental Protection Agency FDCP Fugitive dust control plan GHG Greenhouse Gas(es) - 40 CFR 52.21 (b)(49)(i) GWP Global Warming Potential - 40 CFR Part 86.1818-12(a) HAP or HAPs Hazardous air pollutant(s) ITA Intent to Approve LB/HR Pounds per hour LB/YR Pounds per year MACT Maximum Achievable Control Technology MMBTU Million British Thermal Units NAA Nonattainment Area NAAQS National Ambient Air Quality Standards NESHAP National Emission Standards for Hazardous Air Pollutants NOI Notice of Intent NOx Oxides of nitrogen NSPS New Source Performance Standard NSR New Source Review PM10 Particulate matter less than 10 microns in size PM2.5 Particulate matter less than 2.5 microns in size PSD Prevention of Significant Deterioration PTE Potential to Emit R307 Rules Series 307 R307-401 Rules Series 307 - Section 401 SO2 Sulfur dioxide Title IV Title IV of the Clean Air Act Title V Title V of the Clean Air Act TPY Tons per year UAC Utah Administrative Code VOC Volatile organic compounds DAQE-MN102190018-24 M E M O R A N D U M TO: Tad Anderson, NSR Engineer FROM: Jason Krebs, Air Quality Modeler DATE: April 9, 2024 SUBJECT: Modeling Analysis Review for the Notice of Intent for Kinder Morgan Altamont, LLC – Bluebell Facility, Duchesne County, Utah _____________________________________________________________________________________ This is not a Major Prevention of Significant Deterioration (PSD) Source. I. OBJECTIVE Kinder Morgan Altamont, LLC (Applicant) is seeking an approval order for their Bluebell Facility located in Duchesne County, Utah. The applicant requests to add two unpermitted flares to its Approval Order. One of the flares has replaced an existing combustor, and controls emissions from existing condensate storage tanks. The other flare controls emissions from another set of condensate storage tanks. This report, prepared by the Staff of the New Source Review Section (NSR), contains a review of the air quality impact analysis (AQIA) including the information, data, assumptions and modeling results used to determine if the facility will be in compliance with applicable State and Federal concentration standards. II. APPLICABLE RULE(S) Utah Air Quality Rules: R307-401-6 Condition for Issuing an Approval Order R307-410-3 Use of Dispersion Models R307-410-4 Modeling of Criteria Pollutants in Attainment Areas III. MODELING METHODOLOGY A. Applicability Emissions from the facility include PM10, NOx, CO, SO2, and HAPs. This modeling is part of a modified approval order. The emission rates for NOx triggered the requirement to model under R307-410. Modeling was performed by the UDAQ. 195 North 1950 West • Salt Lake City, UT Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820 Telephone (801) 536-4000 • Fax (801) 536-4099 • T.D.D. (801) 903-3978 www.deq.utah.gov Printed on 100% recycled paper State of Utah SPENCER J. COX Governor DEIDRE HENDERSON Lieutenant Governor Department of Environmental Quality Kimberly D. Shelley Executive Director DIVISION OF AIR QUALITY Bryce C. Bird Director TA DAQE- MN102190018-24 Page 2 B. Assumptions 1. Topography/Terrain The Plant is at an elevation 5630 feet with terrain features that have an affect on concentration predictions. a. Zone: 12 b. Approximate Location: UTM (NAD83): 577604 meters East 4470289 meters North 2. Urban or Rural Area Designation After a review of the appropriate 7.5 minute quadrangles, it was concluded the area is “rural” for air modeling purposes. 3. Ambient Air It was determined the Plant boundary used in the AQIA meets the State’s definition of ambient air. 4. Building Downwash The source was modeled with the AERMOD model. All structures at the plant were used in the model to account for their influence on downwash. 5. Meteorology Five (5) years of off-site surface and upper air data were used in the analysis consisting of the following: Surface – Vernal Airport UT NWS: 2016-2020 Upper Air – Grand Junction, CO NWS: 2016-2020 6. Background The background concentrations were based on concentrations measured in Roosevelt, Utah. 7. Receptor and Terrain Elevations The modeling domain used by the Applicant consisted of receptors including property boundary receptors. This area of the state contains mountainous terrain and the modeling domain has simple and complex terrain features in the near and far fields. Therefore, receptor points representing actual terrain elevations from the area were used in the analysis. DAQE- MN102190018-24 Page 3 8. Model and Options The State-accepted AERMOD model was used to predict air pollutant concentrations under a simple/complex terrain/wake effect situation. In quantifying concentrations, the regulatory default option was selected. 9. Air Pollutant Emission Rates Kinder Morgan Altamont LLC – Bluebell Facility Source UTM Coordinates Modeled Emission Rates Easting Northing Nox (m) (m) (lb/hr) (tons/yr) hrs/year RICE_1 577721 4470562 3.80 16.65 8760 RICE_2 577721 4470576 3.80 16.65 8760 RICE_3 577721 4470548 1.30 5.70 8760 H_1 577690 4470582 0.53 2.34 8760 C_250 577764 4470575 4.43 19.40 8760 C_251 577763 4470587 4.43 19.40 8760 C_252 577759 4470602 2.13 9.33 8760 C_253 577759 4470615 2.13 9.33 8760 C_161 577734 4470650 0.76 3.33 8760 C_162 577734 4470661 0.76 3.33 8760 C_256 577761 4470630 0.82 3.60 8760 C_257 577761 4470642 0.82 3.60 8760 COM_1 577694 4470610 0.13 0.57 8760 COM_2 577754 4470737 0.01 0.04 8760 FL_1001 577789 4470714 1.04 4.55 8760 C163 577777 4470664 0.76 3.34 8760 C258 577773 4470554 2.09 9.17 8760 FL1 577759 4470736 0.22 0.97 8760 FL2 577682 4470523 0.22 0.97 8760 Total 30.20 132.28 Kinder Morgan Altamont LLC – Compressor Stations East, West, and South Source UTM Coordinates Modeled Emission Rates Easting Northing Nox (m) (m) (lb/hr) (tons/yr) hrs/year CUMUL1 564020 4467280 78.19 342.48 8760 CUMUL2 551427 4463055 74.10 324.54 8760 CUMUL3 548123 4457879 93.45 409.33 8760 DAQE- MN102190018-24 Page 4 Total 245.74 1076.36 10. Source Location and Parameters Source Type Source Parameters Elev, Ht Temp Flow Dia (ft) (m) (ft) (K) (m/s) (ft) RICE_1 POINT 5629.0 8.6 28.1 666 36.95 0.31 RICE_2 POINT 5630.3 8.6 28.1 680 37.80 0.31 RICE_3 POINT 5627.5 8.6 28.1 806 57.38 0.31 H_1 POINT 5631.8 8.0 26.2 589 1.05 0.20 C_250 POINT 5629.0 14.3 47.0 730 49.71 0.31 C_251 POINT 5630.1 14.3 47.0 730 49.71 0.31 C_252 POINT 5631.3 14.3 47.0 718 50.30 0.31 C_253 POINT 5632.1 14.3 47.0 718 50.30 0.31 C_161 POINT 5634.3 6.7 22.0 780 27.29 0.31 C_162 POINT 5634.6 6.7 22.0 780 27.29 0.31 C_256 POINT 5633.0 6.7 22.0 779 22.66 0.20 C_257 POINT 5633.2 6.7 22.0 779 22.66 0.20 COM_1 POINT 5633.5 2.6 8.5 1033 0.53 0.76 COM_2 POINT 5634.2 2.6 8.5 1033 0.53 0.76 FL_1001 POINT 5630.0 22.1 72.4 1273 20.00 0.14 C163 POINT 5631.9 6.7 22.0 780 27.29 0.31 C258 POINT 5626.4 14.3 47.0 871 41.12 0.34 FL1 POINT 5633.8 12.2 40.0 473 36.78 0.08 FL2 POINT 5625.1 12.2 40.0 473 36.78 0.08 CUMUL1 POINT 6107.2 9.5 31.0 700 21.19 0.31 CUMUL2 POINT 6740.9 9.1 30.0 700 21.18 0.31 CUMUL3 POINT 5855.3 9.1 30.0 700 21.19 0.31 DAQE- MN102190018-24 Page 5 IV. RESULTS AND CONCLUSIONS A. National Ambient Air Quality Standards The below table provides a comparison of the predicted total air quality concentrations with the NAAQS. The predicted total concentrations are less than the NAAQS. Air Pollutant Period Prediction Class II Significant Impact Level Background Nearby Sources* Total NAAQS Percent (μg/m3) (μg/m3) (μg/m3) (μg/m3) (μg/m3) (μg/m3) NAAQS NO2 1- Hour 143.2 7.5 1.3 35.1 179.6 188 95.53% JK:jg Electronic Submittal December 20, 2023 Mr. Jon Black, Manager Major Source NSR Program Utah Division of Air Quality (UDAQ) 195 North 1950 West, 4th Floor Salt Lake City, UT 84116 Re: Kinder Morgan Altamont LLC – Bluebell Facility Notice of Intent to Modify DAQE‐AN102190015‐21 Dear Mr. Black, Kinder Morgan Altamont LLC (Kinder Morgan) is submitting the attached Notice of Intent (NOI) to modify Approval Order DAQE‐AN102190015‐21 for the Bluebell Facility. Kinder Morgan is proposing the following changes in the attached NOI:  Installation of a flare (FL‐1) to control emissions from existing condensate tanks CS T‐211, CS T‐212, CS T‐213, and CS T‐214;  Replacement of existing combustor (COM‐2) with a flare (FL‐2) to control emissions from existing condensate tanks GPP TK‐870 and GPP‐TK‐874;  Update represented potential to emit (PTE) from condensate truck loading activities. In July 2023, Kinder Morgan initiated an environmental self‐evaluation of condensate tank emissions at the Bluebell Facility that included on‐site measurements of condensate tank vent gasses performed by a third‐party consultant. Kinder Morgan performed an analysis and review of these measurements and determined the resulting VOC emissions exceed the currently permitted emission rates. As proposed in the voluntary disclosure correspondence submitted by Kinder Morgan to UDAQ on August 2, 2023, a flare (FL‐1) was installed and began operation on September 7, 2023 to control emissions from condensate tanks CS T‐211 through CS T‐214. Additionally, existing combustor (COM‐ 2) was replaced with a flare (FL‐2) to control emissions from condensate tanks GPP TK‐870 and GPP TK‐874 (FL‐2) on September 11, 2023. Please contact me at (918) 588‐5044 or by email at Janel_Nelson@kindermorgan.com if you have any questions regarding the attached NOI application. Sincerely, Janel Nelson Specialist – Permitting & Compliance Sr II Kinder Morgan Altamont LLC Page i Bluebell Facility December 2023 TABLE OF CONTENTS Section 1 Introduction .................................................................................................................. 1 1.1 Background & Project Description ................................................................................ 1 1.2 Project Emission Unit Additions & Modifications ......................................................... 2 Section 2 Application Contents..................................................................................................... 3 Section 3 Site Process & Project Review ...................................................................................... 4 3.1 Post-Project Process Description .................................................................................. 4 3.2 Project Emissions Information ...................................................................................... 5 Section 4 Air Quality Regulatory Requirements ........................................................................... 6 4.1 State (UDAQ) Regulatory Applicability ......................................................................... 6 4.2 Federal Regulatory Applicability ................................................................................. 10 Section 5 Best Available Control Technology (BACT) Review .................................................... 17 5.1 Organic Liquid Storage Tank Vents ............................................................................. 17 5.2 Tank Truck Loading Operation .................................................................................... 17 List of Tables Table 1-1 Project Emission Unit Additions & Modifications Summary .......................................... 2 Table 3-1 Project Emissions Summary ............................................................................................5 Table 4-1 Utah Administrative Code (UAC) Applicability Review ................................................... 6 Table 4-2 Federal Regulatory Applicability Review ........................................................................10 List of Appendices Appendix A UDAQ Form 1 – NOI Checklist Appendix B UDAQ Form 2 – Company Information Appendix C UDAQ Form 4 – Project Information Appendix D UDAQ Form 5 – Emission Information Appendix E UDAQ Process-Specific Forms Appendix F Detailed Air Emissions Calculations Appendix G Promax Simulation Report Kinder Morgan Altamont LLC Page 1 Bluebell Facility December 2023 Section 1 Introduction 1.1 Background & Project Description On July 3, 2018 Approval Order DAQE-AN10219001-18 (AO) was issued to Kinder Morgan Altamont LLC (Kinder Morgan), authorizing construction of the Bluebell Gas Plant adjacent to the existing Bluebell Compressor Station. The gas plant and compressor station are referred to as the Bluebell Facility in DAQE-AN10219001-18. The Bluebell Facility was commenced operation in September of 2019. Approval Order DAQE-AN102190013-20 was issued for the installation of one additional refrigeration compressor and to reflect equipment updates. Approval Order DAQE-AN102190015-21 was issued on June 7, 2021 to update equipment and emissions. In July 2023, Kinder Morgan initiated an environmental self-evaluation of condensate tank emissions at the Bluebell Facility that included on-site measurements of condensate tank vent gasses performed by a third-party consultant. Tanks included in the measurement study were: CS T-211 through T-214, GPP TK-870, and GPP TK-874. Kinder Morgan performed an analysis and review of these measurements and determined the resulting VOC emissions exceed the currently permitted emission rates. As proposed in the voluntary disclosure correspondence submitted by Kinder Morgan to Utah Department of Environmental Quality (UDAQ) on August 2, 2023, a flare was installed and began operation on September 7, 2023 to control emissions from condensate tanks CS T-211 through CS T-214. Additionally, the existing combustor (COM-2) was replaced with a flare to control emissions from condensate tanks GPP TK-870 and GPP TK-874 on September 11, 2023. Kinder Morgan is submitting this Notice of Intent (NOI) to reflect the updated facility operations at the Bluebell Facility. Table 1-1 shows the units to be added or modified. Kinder Morgan Altamont LLC Page 2 Bluebell Facility December 2023 1.2 Project Emission Unit Additions & Modifications The following is a summary of modifications to existing emission units and proposed new units: Table 1-1: Project Emission Unit Additions & Modifications Summary Emission Unit ID Emission Unit Description Make/Model Capacity Action COM-2 Enclosed Combustor (TK 870, TK 874 vents) Cimmaron 121 scfh (pilot) REMOVE CS T-211, T- 212, T-213 Bluebell CS Condensate Storage Tanks (three) N/A 400-bbl (each)UPDATE EMISSIONS CS T-214 Bluebell CS Pit Tank (condensate/water) N/A 400-bbl UPDATE EMISSIONS Bluebell CS Truck Loading: Condensate N/A 4,250,000 gal/yr UPDATE EMISSIONS GPP-870, GPP-874 Bluebell GP Condensate Storage Tanks (two) N/A 400-bbl (each)UPDATE EMISSIONS TRK1 Bluebell GP Truck Loading: Condensate N/A 34 bbl/day UPDATE EMISSIONS FL-1 Bluebell CS Condensate Tanks Flare Tornado 70 scfh (pilot) ADD FL-2 Bluebell GP Condensate Tanks Flare Tornado 70 scfh (pilot) ADD Kinder Morgan Altamont LLC Page 3 Bluebell Facility December 2023 Section 2 Application Contents The information contained in this NOI was developed in accordance with the requirements outlined in the Utah Administrative Code (UAC) at R307-401-5 and includes the necessary Utah Division of Air Quality (UDAQ) forms required to authorize the proposed facility changes. This NOI is organized as follows: a) Section 1: Introduction – This section summarizes the reason for submitting this NOI and includes a summary of the emission unit changes requested within the application. b) Section 2: Application Contents – This section includes a summary of the information provided in each section of the application. c) Section 3: Site Process & Project Review - This section details the post-project facility process and summarizes the PTE for criteria air pollutant, hazardous air pollutant (HAP), and greenhouse gas (GHG) emissions associated with the project. d) Section 4: Air Quality Regulatory Requirements – This section summarizes the potentially applicable air quality requirements associated with this project. This analysis includes a summary of the applicable emissions and operational limits, the associated regulatory citation, and a description of how the facility intends to demonstrate compliance. e) Section 5: Best Available Control Technology (BACT) Analysis – This section provides an evaluation of BACT, as required by R307-401-5(2)(d) for new and modified emissions sources. f) Appendices: Appendices included in this NOI modification include the following:  Appendix A: UDAQ Form 1 – NOI Checklist  Appendix B: UDAQ Form 2 – Company Information  Appendix C: UDAQ Form 4 – Project Information  Appendix D: UDAQ Form 5 – Emission Information  Appendix E: UDAQ Process-Specific Forms i. Form 4 – Flare Systems  Appendix F: Detailed Air Emissions Calculations  Appendix G: Promax Simulation Report Kinder Morgan Altamont LLC Page 4 Bluebell Facility December 2023 Section 3 Site Process & Project Review 3.1 Post-Project Process Description The Bluebell Facility’s primary function is to dehydrate field gas and extract Natural Gas Liquids (NGL). Field gas enters the facility via various trunk lines that combine into the main facility inlet. The inlet gas stream is directed to a slug catcher where free water and condensate are separated from the field gas. The water and condensate are directed to the existing storage tanks CS T-211, T-212, T-213, and T-214, located at the former Bluebell Compressor Station before being trucked from the facility. Emissions from these storage tanks, which were previously uncontrolled, will now be controlled with a flare (FL-1). Field gas from the slug catcher is directed to the inlet compressors. Any liquid collected from the second and third stage inlet compressor scrubbers is directed to an intermediate 3-phase flash separator V-405 (which is an enclosed vessel with zero emissions). The condensate from V-405 is routed to tanks GPP-870 and GPP-874, which were previously controlled with a combustor (COM- 2); however, will now be controlled with a flare (FL-2). After compression Ethylene Glycol (EG) is injected into the gas to prevent hydrates from forming prior to the gas going through a series of heat exchangers and a propane chiller to cool down the gas. EG and NGL are separated from the gas in the cold separator. The Rich EG is sent to a flash tank where free gas is separated and sent to a combustor for control. The EG is then sent to a regenerator. Water vapor from the EG regenerator is sent to TK-837 where the uncondensed vapor is controlled by a combustor. NGLs are then sent to a de-ethanizer tower where light end hydrocarbons are removed and sent to the fuel gas system. The NGL is then sent to pressurized bullet tanks for storage prior to being trucked off site. The Bluebell Gas Plant and the Bluebell Compressor Station is equipped with a flare (FL-1001) to manage unplanned pressure relief events, planned and unplanned maintenance activities, and plant emergency shut downs. Kinder Morgan Altamont LLC Page 5 Bluebell Facility December 2023 3.2 Project Emissions Information Kinder Morgan ran refined Promax process simulations using an updated liquid analysis for the facility’s existing operations. While there are no proposed changes to the facility’s permitted condensate throughput, the updated liquid analysis and newly installed control devices resulted in emissions changes for the existing condensate tanks and truck load-out operation. The facility’s storage and load-out operations will be a potential source of volatile organic compounds (VOC), HAPs, and GHG emissions. A summary of the facility’s existing site-wide potential to emit (PTE), project emissions changes, and new site-wide PTE are provided in Table 3-1 below. Detailed air emissions calculations for the project are provided in Appendix D and Appendix F. Table 3-1: Project Emissions Summary NOx CO VOC SO2 PM10/ PM2.5 Single HAP [2] Total HAPs CO2e (tpy) (tpy) (tpy) (tpy) (tpy) (tpy) (tpy) (tpy) Existing Site-Wide PTE [1] 131.44 104.28 110.77 1.43 3.64 6.29 12.12 108,176 Project Emission Changes +1.10 +5.24 +1.48 +0.01 +0.14 +0.01 +0.06 +1,895 Total New Site- Wide PTE 132.54 109.52 112.25 1.44 3.78 6.30 12.18 110,071 [1] Existing site-wide PTE obtained from AO DAQE-AN102190015-21. [2] Formaldehyde is the highest single HAP. In accordance with UAC R307-410-5, Kinder Morgan evaluated if the proposed HAP emission increases would trigger the need to conduct an ambient air impact analysis (air dispersion modeling). Based on procedures established in UDAQ’s Emissions Impact Assessment Guidelines, the proposed HAP emission increases do not exceed the applicable Emission Threshold Values for which an air dispersion modeling analysis would be required. In addition, based on UDAQ’s Emission Impact Assessment Guidelines, the total controlled project emission rates are below the emission thresholds of UAC R307-410-4. Therefore, no further impacts analyses are necessary for criteria pollutants of HAPs. Detailed emissions calculations and the impacts analysis are provided in Appendix F. Kinder Morgan Altamont LLC Page 6 Bluebell Facility December 2023 Section 4 Air Quality Regulatory Requirements 4.1 State (UDAQ) Regulatory Applicability A summary of potentially applicable UDAQ requirements for the proposed project emission sources is provided in Table 4-1. For each potentially applicable requirement, the table provides the regulatory citation, a summary of the requirement, the associated emissions or operational requirement, and a description of how Kinder Morgan intends to demonstrate initial and continuous compliance. Table 4-1: Utah Administrative Code (UAC) Applicability Review Applicability Determination Regulatory Citation Rule Summary & Applicability Notes Ap p l i c a b l e No t A p p l i c a b l e Determination Notes R307-150-5 Sources Identified in R307-150-3(2), Large Major Source Inventory Requirements X R307-150-5 applies to large major sources - see R307-150-3(2). Facility is not a "Large Major Source" as defined in R307-150-2. R307-150-6 Sources identified in 150-3(3) X R307-150-6 applies to: (a) each major source that is not a large major source; (b) each source with the potential to emit 5 tons or more per year of lead; and (c) each source not included in (2) or (3)(a) or (3)(b) above that is located in Davis, Salt Lake, Utah, or Weber Counties and that has the potential to emit 25 tons or more per year of any combination of oxides of nitrogen, oxides of sulfur and PM10, or the potential to emit 10 tons or more per year of volatile organic compounds- see R307-150-3(3) Facility is not a facility identified in 150-3(3). R307-150-7 Sources Identified in R307-150-3(4), Other Part 70 Sources X R307-150-7 Applies to Part 70 sources not included in R307-150-3(2) or (3) - see R307-150-3(4). R307-150-8 Exempted Hazardous Air Pollutants X R307-165 Emission testing X Establishes the emission testing requirements and frequency for all areas of Utah. Testing requirements will be set out in Approval Order. R307-170 Continuous Emission Monitoring Program X Source is not required to install a continuous monitoring system to determine emissions to the atmosphere or to measure control equipment efficiency R307-201 Emission Standards: General Emission Standards X R307-201-3 Visible Emission Standards X Opacity standards apply to any installation Kinder Morgan Altamont LLC Page 7 Bluebell Facility December 2023 Applicability Determination Regulatory Citation Rule Summary & Applicability Notes Ap p l i c a b l e No t A p p l i c a b l e Determination Notes R307-202 Emission Standards: General Burning X Permittee does not engage in regulated activity R307-203 Emission Standards: Sulfur Content of Fuels X All of the new/modified combustion sources will be fired with pipeline quality natural gas; therefore, the sulfur content limits of this section (fuel oil and coal only) do not apply. R307-204 Emission Standards: Smoke Management X Permittee does not engage in regulated activity R307-205 Fugitive Emissions and Fugitive Dust X R307-206 Emission Standards: Abrasive Blasting X Permittee does not engage in regulated activity R307-207 Residential Fireplaces and Solid Fuel Burning Devices X Permittee does not engage in regulated activity R307-208 Outdoor Wood Boilers X Permittee does not engage in regulated activity R307-210 Standards of Performance for New Stationary Sources X The provisions of 40 CFR Part 60, effective on July 1, 2016, except for Subparts Cb, Cc, Cd, Ce, BBBB, DDDD, and HHHH, are incorporated by reference. Permittee owns and operates "affected facilities" subject to certain NSPS subparts. R307-214 National Emission Standards for Hazardous Air Pollutants X The provisions of Title 40 of the Code of Federal Regulations (40 CFR) Part 61, National Emission Standards for Hazardous Air Pollutants, effective as of July 1, 2016, are incorporated into these rules by reference. No Part 61 rule applies. R307-220 Emission Standards: Plan for Designated Facilities X Permittee does not engage in regulated activity R307-221 Emission Standards: Emission Controls for Existing Municipal Solid Waste Landfills X Permittee does not engage in regulated activity R307-222 Emission Standards: Existing Incinerators for Hospital, Medical, Infectious Waste X Permittee does not engage in regulated activity R307-223 Emission Standards: Existing Small Municipal Waste Combustion Units X Permittee does not engage in regulated activity R307-224 Mercury Emission Standards: Coal-Fired Electric Generating Units X Permittee does not engage in regulated activity R307-250 Western Backstop Sulfur Dioxide Trading Program X Facility does not have the potential to emit 100 tons or more of sulfur dioxide per year and does not otherwise operate affected facilities R307-301 Utah and Weber Counties: Oxygenated Gasoline Program As a Contingency Measure X Permittee does not engage in regulated activity R307-302 Solid Fuel Burning Devices X Permittee does not engage in regulated activity Kinder Morgan Altamont LLC Page 8 Bluebell Facility December 2023 Applicability Determination Regulatory Citation Rule Summary & Applicability Notes Ap p l i c a b l e No t A p p l i c a b l e Determination Notes R307-303 Commercial Cooking X Permittee does not engage in regulated activity R307-305 Nonattainment and Maintenance Areas for PM10: Emission Standards X Permittee does not engage in regulated activity R307-306 PM10 Nonattainment and Maintenance Areas: Abrasive Blasting X Permittee does not engage in regulated activity R307-307 Road Salting and Sanding X Permittee does not engage in regulated activity R307-309 Nonattainment and Maintenance Areas for PM10 and PM2.5: Fugitive Emissions and Fugitive Dust X R307-309 applies to all sources of fugitive dust and fugitive emissions located in PM10 and PM2.5 nonattainment and maintenance plan areas as defined in 40 CFR 81.345 (July 1, 2011), except as specified in R307-309-3(2). Facility is not located in PM10 and PM2.5 nonattainment and maintenance plan areas. R307-310 Salt Lake County: Trading of Emission Budgets for Transportation Conformity X Permittee does not engage in regulated activity R307-311 Utah County: Trading of Emission Budgets for Transportation Conformity X Permittee does not engage in regulated activity R307-312 Aggregate Processing Operations for PM2.5 Nonattainment Areas X Permittee does not engage in regulated activity R307-320 Ozone Maintenance Areas and Ogden City: Employer- Based Trip Reduction Program X Permittee does not engage in regulated activity R307-325 Ozone Nonattainment and Maintenance Areas: General Requirements X R307-325 applies to all sources located in any nonattainment or maintenance area for ozone. Facility is not located in an ozone nonattainment area. R307-326 Ozone Nonattainment and Maintenance Areas: Control of Hydrocarbon Emissions in Petroleum Refineries X Permittee does not engage in regulated activity R307-327 Ozone Nonattainment and Maintenance Areas: Petroleum Liquid Storage X R307-327 applies to the owner or operator of any petroleum refinery or petroleum liquid storage facility located in any ozone nonattainment or maintenance area. Facility is not located in an ozone nonattainment area. R307-328 Gasoline Transfer and Storage X Permittee does not engage in regulated activity R307-335 Degreasing and Solvent Cleaning Operations X Permittee does not engage in regulated activity R307-341 Ozone Nonattainment and Maintenance Areas: Cutback Asphalt X Permittee does not engage in regulated activity R307-342 Adhesives and Sealants X Permittee does not engage in regulated activity Kinder Morgan Altamont LLC Page 9 Bluebell Facility December 2023 Applicability Determination Regulatory Citation Rule Summary & Applicability Notes Ap p l i c a b l e No t A p p l i c a b l e Determination Notes R307-343 Emissions Standards for Wood Furniture Manufacturing Operations X Permittee does not engage in regulated activity R307-344 Paper, Film, and Foil Coatings X Permittee does not engage in regulated activity R307-345 Fabric and Vinyl Coatings X Permittee does not engage in regulated activity R307-346 Metal Furniture Surface Coatings X Permittee does not engage in regulated activity R307-347 Large Appliance Surface Coatings X Permittee does not engage in regulated activity R307-348 Magnet Wire Coatings X Permittee does not engage in regulated activity R307-349 Flat Wood Panel Coatings X Permittee does not engage in regulated activity R307-350 Miscellaneous Metal Parts and Products Coatings X Permittee does not engage in regulated activity R307-351 Graphic Arts X Permittee does not engage in regulated activity R307-352 Metal Container, Closure, and Coil Coatings X Permittee does not engage in regulated activity R307-353 Plastic Parts Coatings X Permittee does not engage in regulated activity R307-354 Automotive Refinishing Coatings X Permittee does not engage in regulated activity R307-355 Control of Emissions from Aerospace Manufacture and Rework Facilities X Permittee does not engage in regulated activity R307-356 Appliance Pilot Light X Permittee does not engage in regulated activity R307-357 Consumer Products X Permittee does not engage in regulated activity R307-361 Architectural Coatings X Permittee does not engage in regulated activity R307-401 Permit: New and Modified Sources X Kinder Morgan Altamont LLC Page 10 Bluebell Facility December 2023 4.2 Federal Regulatory Applicability A general review of the potentially applicable federal requirements for the proposed project sources is provided in Table 4-2 below. For each requirement reviewed, the table provides the regulatory citation, a description of the requirement, indicates whether the regulatory requirement is applicable, and provides the reason for applicability or non-applicability. Table 4-2: Federal Regulatory Applicability Review Applicability Determination Re g u l a t o r y Ci t a t i o n Ru l e C i t a t i o n Ta r g e t Po l l u t a n t s Rule Summary & Applicability Notes Ap p l i c a b l e No t A p p l i c a b l e Determination Notes NSPS Subpart A §§60.1-60.19 General Provisions X Several subparts of 40 CFR Part 60 apply to this facility. Portions of the general provisions apply, as referenced in applicable subparts. Flares used as a control device for a referencing NSPS subpart will conform to the requirements of §60.18, as applicable and as required by that referencing subpart. NSPS Subpart Db §§60.40b- 60.49b NOx, SO2, PM Standards of Performance for Industrial-Commercial-Institutional Steam Generating Units with a heat input capacity >100 MMBtu/hr for which construction, modification, or reconstruction commenced after June 19,1984 X Permittee does not operate any affected facilities NSPS Subpart Dc §§60.40c- 60.48c NOx, SO2, PM Standards of Performance for Small Industrial-Commercial- Institutional Steam Generating Units for which construction, modification, or reconstruction is commenced after June 9, 1989 and that have a maximum design heat input capacity of 100 MMBtu/h or less, but greater than or equal to 10 MMBtu/h X Permittee does not operate any affected facilities NSPS Subpart K §§60.110- 60.113 VOC Standards of Performance for certain storage vessels for petroleum liquids for which construction, reconstruction, or modification commenced after June 11, 1973, and prior to May 19, 1978 and with a storage capacity >40,000 gallons X Permittee does not operate any affected facilities NSPS Subpart Ka §§60.110a- 60.115a VOC Standards of Performance for certain storage vessels for petroleum liquids for which construction, reconstruction, or modification commenced after May 18, 1978 and prior to July 23, 1984 and with a storage capacity >40,000 gallons X Permittee does not operate any affected facilities Kinder Morgan Altamont LLC Page 11 Bluebell Facility December 2023 Applicability Determination Re g u l a t o r y Ci t a t i o n Ru l e C i t a t i o n Ta r g e t Po l l u t a n t s Rule Summary & Applicability Notes Ap p l i c a b l e No t A p p l i c a b l e Determination Notes NSPS Subpart Kb §§60.110b- 60.116b VOC Standards of Performance for certain Volatile Organic Liquid (VOL) Storage Vessels (Including Petroleum Liquid Storage Vessels) for Which Construction, Reconstruction, or Modification Commenced After July 23, 1984 and with a design storage capacity greater than or equal to 75 cubic meters X Not applicable to this project NSPS Subpart GG §§60.330- 60.335 NOx, SO2 Standards of performance for stationary gas turbines with a heat input at peak load equal to or greater than 10 MMBtu/h (based on the lower heating value of the fuel fired) and for which construction, modification, or reconstruction commenced after October 3, 1977 and on or before February 18, 2005 X Permittee does not operate any stationary combustion turbine affected facilities NSPS Subpart KKK §§60.630- 60.636 VOC Subpart KKK—Standards of Performance for Equipment Leaks of VOC From Onshore Natural Gas Processing Plants for Which Construction, Reconstruction, or Modification Commenced After January 20, 1984, and on or Before August 23, 2011 X Construction of the natural gas processing plant (gas plant) will commence after August 23, 2011. Subpart KKK is not a relevant standard. NSPS Subpart LLL §§60.640- 60.648 SO2 Subpart LLL—Standards of Performance for SO2 Emissions From Onshore Natural Gas Processing for Which Construction, Reconstruction, or Modification Commenced After January 20, 1984, and on or Before August 23, 2011 X Construction of the gas plant will commence after August 23, 2011. Subpart LLL is not a relevant standard. NSPS Subpart IIII §§60.4200- 60.4219 NOx, NMHC, HC, CO, PM Standards of Performance for Stationary Compression Ignition Internal Combustion Engines (CI-ICE) for which construction, reconstruction or modification occurred after July 11, 2005 and where the stationary CI ICE was manufactured after April 1, 2006 (CI-ICE that are not fire pump engines) or manufactured as a certified National Fire Protection Association (NFPA) fire pump engine after July 1, 2006. X Permittee does not operate any stationary CI-ICE Kinder Morgan Altamont LLC Page 12 Bluebell Facility December 2023 Applicability Determination Re g u l a t o r y Ci t a t i o n Ru l e C i t a t i o n Ta r g e t Po l l u t a n t s Rule Summary & Applicability Notes Ap p l i c a b l e No t A p p l i c a b l e Determination Notes NSPS Subpart JJJJ §§60.4230- 60.4248 NOx, CO, VOC Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (SI-ICE) for which construction, reconstruction or modification occurred after June 12, 2006 and where the stationary SI-ICE was manufactured: (i) On or after July 1, 2007, for engines with a maximum engine power greater than or equal to 500 HP (except lean burn engines with a maximum engine power greater than or equal to 500 HP and less than 1,350 HP); (ii) on or after January 1, 2008, for lean burn engines with a maximum engine power greater than or equal to 500 HP and less than 1,350 HP; (iii) on or after July 1, 2008, for engines with a maximum engine power <500 HP; or on or after January 1, 2009, for emergency engines with a maximum engine power>25 HP X Existing units at the facility have applicability to this regulation; however, it is not applicable to this project. NSPS Subpart KKKK §§60.4300- 60.4420 NOx, SO2 Standards of Performance for stationary combustion turbines that commenced construction, modification, or reconstruction after February 18, 2005. X Permittee does not operate any stationary combustion turbine affected facilities NSPS Subpart OOOO §§60.5360- 60.5430 VOC, SO2 Subpart OOOO—Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution for which Construction, Modification or Reconstruction Commenced after August 23, 2011, and on or before September 18, 2015 X Permittee does not operate any affected facility for which construction, reconstruction or modification occurred after August 23, 2011, and on or before September 18, 2015 NSPS Subpart OOOOa §60.5375a VOC, GHG Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015: Wells X Permittee does not operate any well affected facility NSPS Subpart OOOOa §60.5380a VOC, GHG Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015: Centrifugal Compressors with Wet Seal Degassing Systems X Permittee does not operate any centrifugal compressor affected facility Kinder Morgan Altamont LLC Page 13 Bluebell Facility December 2023 Applicability Determination Re g u l a t o r y Ci t a t i o n Ru l e C i t a t i o n Ta r g e t Po l l u t a n t s Rule Summary & Applicability Notes Ap p l i c a b l e No t A p p l i c a b l e Determination Notes NSPS Subpart OOOOa §60.5385a VOC, GHG Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015: Reciprocating Compressors X Existing units at the facility have applicability to this regulation; however, it is not applicable to this project. NSPS Subpart OOOOa §60.5390a VOC, GHG Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015: Continuous Bleed Natural Gas-Driven Pneumatic Controllers X Permittee does not operate any natural gas pneumatic controller affected facilities. All controllers are operated by instrument air. NSPS Subpart OOOOa §60.5393a VOC, GHG Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015: Pneumatic Pumps at Natural Gas Processing Plants and Well Sites X Permittee does not operate a pneumatic pump affected facility NSPS Subpart OOOOa §60.5395a VOC, GHG Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015: Storage Vessels X The NGL storage vessels are pressure vessels deigned to operate in excess of 204.9 kilopascals and do not meet the definition of "storage vessel" in §60.5430a. The existing condensate tanks will each have controlled emissions less than the 6 tpy applicability threshold. NSPS Subpart OOOOa §60.5397a VOC, GHG Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015: Collection of Fugitive Emissions Components at a Well Site or Compressor Station X Facility is not a compressor station or well site as defined in §60.5430a. NSPS Subpart OOOOa §60.5398a VOC, GHG Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015: Alternative Means of Emission Limitations X Permittee has not requested an alternative means of emission limitations NSPS Subpart OOOOa §§60.5400a through 60.5402a VOC, GHG Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015: Equipment Leaks at Onshore Natural Gas Processing Plants X The facility is a natural gas processing plant, as defined in §60.5430a, and commenced construction after September 18, 2015. Provisions described in 60.5400a through 50.5402a will apply to all associated equipment located at the gas plant. §60.5365a(f)(2). Kinder Morgan Altamont LLC Page 14 Bluebell Facility December 2023 Applicability Determination Re g u l a t o r y Ci t a t i o n Ru l e C i t a t i o n Ta r g e t Po l l u t a n t s Rule Summary & Applicability Notes Ap p l i c a b l e No t A p p l i c a b l e Determination Notes NSPS Subpart OOOOa §§60.5405a through 60.5407a SO2 Subpart OOOOa—Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015: Sweetening Units at Onshore Natural Gas Processing Plants X Project is not applicable NESHAP Subpart A §§61.01-19 General Provisions X Facility is not subject to a subpart of 40 CFR 61. NESHAP Subpart J §§61.110- 61.112 Benzene National emission standard for fugitive equipment leaks of benzene. Applicable to pumps, compressors, pressure relief valves, connectors, surge control vessels, bottoms receivers and control devices that operate in benzene service. Benzene services means that the equipment contacts or contains a fluid (liquid or gas) that is 10% benzene by weight. X Facility does not process or produce any streams (liquid or gas) with more than 10% benzene by weight. NESHAP Subpart M §§61.140- 61.157 Asbestos National emissions standard pertaining to asbestos during milling, manufacturing, demolition/renovation or disposal. X Currently the facility is not engaging in any of these activities involving asbestos, however any demolition and/or renovation activities could be potentially subject to Subpart M, Standards for Demolition and Renovation. NESHAP Subpart V §§61.240- 61.247 HAP Applies to various sources that operate in volatile hazardous air pollutant (VHAP) service. X The facility does not operate the identified sources in VHAP service. NESHAP Subpart A §§63.1-63.16 HAP General Provisions X Permittee operates certain affected facilities. Subpart A applies as referenced by an underlying subpart. NESHAP Subpart HH §§63.760- 63.777 HAP National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities X Project is not applicable NESHAP Subpart HHH §§63.1270- 63.1289 HAP National Emission Standards for Hazardous Air Pollutants From Natural Gas Transmission and Storage Facilities (Major Sources) X The facility is not in the natural gas transmission source category, but is in the oil and natural gas production source category. Rule is not a relevant standard. NESHAP Subpart EEEE §§63.2330- 63.2406 HAP National Emission Standards for Hazardous Air Pollutants: Organic Liquids Distribution (Non-Gasoline). This subpart establishes national emission limitations, operating limits, and work practice standards for organic hazardous air pollutants (HAP) emitted from organic liquids distribution (OLD) (non-gasoline) operations at major sources of HAP emissions. X The facility is an area source of HAP emissions. This rule only applies to major sources of HAP emissions. [40 CFR §63.2334(a) and (c)(1)] Kinder Morgan Altamont LLC Page 15 Bluebell Facility December 2023 Applicability Determination Re g u l a t o r y Ci t a t i o n Ru l e C i t a t i o n Ta r g e t Po l l u t a n t s Rule Summary & Applicability Notes Ap p l i c a b l e No t A p p l i c a b l e Determination Notes NESHAP Subpart YYYY §§63.6080- 63.6175 HAP Establishes emissions limitations and operating limitations that apply to stationary combustion turbines located at major sources of HAP. X Permittee does not operate any stationary combustion turbine NESHAP Subpart ZZZZ §§63.6580- 63.6675 HAP National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines (RICE) Located at Major and Area Sources of HAP X Existing units at the facility have applicability to this regulation; however, it is not applicable to this project. NESHAP Subpart DDDDD §§63.7480- 63.7575 HAP National Emission Standards for Hazardous Air Pollutants for Major Sources: Industrial, Commercial, and Institutional Boilers and Process Heaters X Facility is an area source of HAP. Rule does not apply to area sources. NESHAP Subpart GGGGG §§63.7880- 63.7957 HAP National Emission Standards for Hazardous Air Pollutants: Site Remediation (Major Sources) X Facility is an area source of HAP. Rule does not apply to area sources. NESHAP Subpart JJJJJJ §§63.11193 -63.11237 HAP National Emission Standards for Hazardous Air Pollutants for Industrial, Commercial, and Institutional Boilers Area Sources X Permittee does not operate any boilers (defined in §63.11237) CAM §§64.1-64.10 Compliance Assurance Monitoring X Existing units at the facility have applicability to this regulation; however, it is not applicable to this project. RMP §§68.1- 68.220 Chemical Accident Prevention Provisions X Facility stores more than a threshold quantity of listed Flammable Substances as defined in §68.130 Table 3. Acid Rain 40 CFR 72- 40 CFR 78 Acid Rain Program X Acid rain permits are required only for facilities that generate electricity and serve a generator with a nameplate of 25 MW or more. 40 CFR 82 Subpart B §§82.30- 82.42 Ozone depleting substances Applies to any person performing service on motor vehicle equipment involving the refrigerant in the motor vehicle air conditioner. X Facility does not perform service on motor vehicle air conditioner units. 40 CFR 82 Subpart F §§82.150- 82.169 Ozone depleting substances Establishes work practices to recapture and recycle refrigerants and applies to any person servicing, maintaining, or repairing appliances. X Facility does not perform service on any appliances. 40 CFR 82 Subpart H §§82.250- 82.270 Halon Reduction of emissions of Halons from on-site equipment. X The facility does not operate a halon fire suppression system or any other equipment containing halon. Kinder Morgan Altamont LLC Page 16 Bluebell Facility December 2023 Applicability Determination Re g u l a t o r y Ci t a t i o n Ru l e C i t a t i o n Ta r g e t Po l l u t a n t s Rule Summary & Applicability Notes Ap p l i c a b l e No t A p p l i c a b l e Determination Notes 40 CFR 98 Subpart C §§98.30- 98.38 CO2, CH4, N2O Subpart C applies to combustion sources that exceed an annual CO2e emissions of 25,000 metric tons. X The combustion emissions from this facility exceed the threshold of 25,000 metric tons CO2e annually. Combustion emissions at the facility will be reported under Subpart C. 40 CFR 98 Subpart W §§98.230- 98.238 CO2, CH4, N2O Subpart W applies to all identified industry segments that will exceed an annual CO2e emissions of 25,000 metric tons. Source categories include Offshore petroleum and natural gas production, Onshore petroleum and natural gas production, Onshore natural gas processing, Onshore natural gas transmission, Underground natural gas storage, Liquefied natural gas (LNG) storage, LNG import and export equipment, Natural gas distribution, Onshore petroleum and natural gas gathering and boosting, and Onshore natural gas transmission. X The annual CO2e emissions are estimated to be more than 25,000 metric tons. The facility is considered a Natural gas processing facility applicable under Subpart W, because its design average throughput is 30 MMscf/day which is more than the threshold of 25 MMscf/day. Note: The subpart of each of the programs listed above were reviewed for applicability. Those subparts within each program that are categorically not relevant are not listed in above. Kinder Morgan Altamont LLC Page 17 Bluebell Facility December 2023 Section 5 Best Available Control Technology (BACT) Review Utah Administrative Code R307-401-5(2)(d) requires the NOI to include a BACT analysis for the proposed source(s) and/or modification(s) to existing sources. The sources subject to a BACT analysis include the three (3) existing condensate storage tanks and existing pit tank on the compressor station side of the facility, the two (2) existing condensate tanks on the gas plant side of the facility, two (2) new flares, and truck loading operations. 5.1 Organic Liquid Storage Tank Vents The vapors from the existing condensate storage tanks will be collected with an enclosed vapor collection system and directed to a flare, which has a VOC destruction efficiency of 98% or greater. The vapor collection system and flare arrangement for this type of source constitutes BACT. 5.2 Tank Truck Loading Operation Current truck loading requirements in R307-504 establish specific control requirements for the loading and unloading of liquids containing VOCs at oil or gas well sites. These control requirements include the use of bottom fill or submerged fill pipe as well as a “Vapor Capture Line” from the truck. The Bluebell Facility is not co-located with or directly associated with one or more oil wells or gas wells and therefore is not considered a “Well production facility” or a “well site” as described in R307-504, R307-506 or 40 CFR §60.5430a in NSPS Subpart OOOOa. Liquids will be removed from the condensate tanks using a tanker truck that utilizes bottom filling or submerged fill pipe techniques. The loading operations will continue to employ bottom filling which constitutes BACT. APPENDIX A UDAQ Form 1 – NOI Checklist Form 1 Date __________________ Notice of Intent (NOI) Application Checklist Company __________________ Utah Division of Air Quality New Source Review Section Source Identification Information [R307-401-5] 1. Company name, mailing address, physical address and telephone number 2. Company contact (Name, mailing address, and telephone number) 3. Name and contact of person submitting NOI application (if different than 2) 4. Source Universal Transverse Mercator (UTM) coordinates 5. Source Standard Industrial Classification (SIC) code 6. Area designation (attainment, maintenance, or nonattainment) 7. Federal/State requirement applicability (NAAQS, NSPS, MACT, SIP, etc.) 8. Source size determination (Major, Minor, PSD) 9. Current Approval Order(s) and/or Title V Permit numbers NOI Application Information:[R307-401] N/A N/A A. Air quality analysis (air model, met data, background data, source impact analysis) N/A Detailed description of the project and source process Discussion of fuels, raw materials, and products consumed/produced Description of equipment used in the process and operating schedule Description of changes to the process, production rates, etc. Site plan of source with building dimensions, stack parameters, etc. Best Available Control Technology (BACT) Analysis [R307-401-8] $BACT analysis for all new and modified equipment Emissions Related Information: [R307-401-2(b)] $Emission calculations for each new/modified unit and site-wide (Include PM10, PM2.5, NOx, SO2, CO, VOCs, HAPs, and GHGs) %References/assumptions, SDS, for each calculation and pollutant &All speciated HAP emissions (list in lbs/hr) Emissions Impact Analysis – Approved Modeling Protocol [R307-410] $Composition and physical characteristics of effluent (emission rates, temperature, volume, pollutant types and concentrations) Nonattainment/Maintenance Areas – Major NSR/Minor (offsetting only) [R307-403] $NAAQS demonstration, Lowest Achievable Emission Rate, Offset requirements %Alternative site analysis, Major source ownership compliance certification Major Sources in Attainment or Unclassified Areas (PSD) [R307-405, R307-406] %Visibility impact analysis, Class I area impact 6LJQDWXUHRQ$SSOLFDWLRQ N/A Note: The Division of Air Quality will not accept documents containing confidential information or data. Documents containing confidential information will be returned to the Source submitting the application. December 6, 2023 Kinder Morgan Altamont LLC ✔ ✔ ✔ ✔ ✔ ✔ ✔ ✔ ✔ ✔ ✔ ✔ ✔ ✔ ✔ ✔ ✔ ✔ ✔ ✔ APPENDIX B UDAQ Form 2 – Company Information APPENDIX C UDAQ Form 4 – Project Information Page 1 of 1 Form 4 Company____________________________ Project Information Site ______________________________ Utah Division of Air Quality New Source Review Section Process Data - For Modification/Amendment ONLY 1. Permit Number_______________________________ If submitting a new permit, then use Form 3 Requested Changes 2. Name of process to be modified/added: _______________________________ End product of this process: _______________________________ 3. Permit Change Type: New Increase* Equipment Process Condition Change ____________________ Other ______________________________ Other ______________________________ Other ______________________________ 4. Does new emission unit affect existing permitted process limits? Yes No 5. Condition(s) Changing: 6. Description of Permit/Process Change** 7. New or modified materials and quantities used in process. ** Material Quantity Annually 8. New or modified process emitting units ** Emitting Unit(s) Capacity(s) Manufacture Date(s) *If the permit being modified does not include CO2e or PM2.5, the emissions need to be calculated and submitted to DAQ, which may result in an emissions increase and a public comment period. **If additional space is required, please generate a document to accommodate and attach to form. Kinder Morgan Altamont LLC Bluebell Facility DAQE-AN102190015-21 Condensate Tanks and Truck Loading Condensate ✔ II.B.3.b ✔ Overall condensate throughput limit is not changing. All condensate tank vapors will be routed to a flare. Addition of a flare (FL-1) to control condensate storage tanks T-211, T-212, T-213, and T-214 N/A - no overall change to site throughput or material stored. CS T-211, T-212, T-213, T-214 400.00 GPP TK-870, TK-874 400.00 FL-1 FL-2 COM-2 CS Condensate Truck Loading GP Condensate Truck Loading APPENDIX D UDAQ Form 5 – Emission Information Page 1 of 1 Company___________________________ 6LWH_____________________________ Form Emissions Information Criteria/GHGs/ HAP’s Utah Division of Air Quality New Source Review Section Potential to Emit* Criteria Pollutants & GHGs Criteria Pollutants Permitted Emissions (tons/yr) Emissions Increases (tons/yr) Proposed Emissions (tons/yr) PM10 Total PM10 Fugitive PM2.5 NOx SO2 CO VOC VOC Fugitive NH3 Greenhouse Gases CO2e CO2e CO2e CO2 CH4 N2O HFCs PFCs SF6 Total CO2e *Potential to emit to include pollution control equipment as defined by R307-401-2. Hazardous Air Pollutants**(**Defined in Section 112(b) of the Clean Air Act ) Hazardous Air Pollutant*** Permitted Emissions (tons/yr) Emission Increase (tons/yr) Proposed Emission (tons/yr) Emission Increase (lbs/hr) Total HAP *** Use additional sheets for pollutants if needed Kinder Morgan Altamont LLC Bluebell Facility 3.64 0.14 3.78 3.64 0.14 3.78 131.44 1.10 132.54 1.43 0.01 1.44 104.28 5.24 109.52 110.77 1.48 112.25 0.58 0.00 0.58 73,740.55 1,869.66 75,610.21 1,375.82 1.03 1,376.85 0.13 0.00 0.13 108,175.10 Formaldehyde 6.29 0.01 6.30 0.00 n-Hexane 1.49 0.06 1.56 0.01 2,2,4-Trimethylpentane 0.11 0.00 0.11 0.00 Benzene 0.41 -0.09 0.32 -0.02 Toluene 0.24 0.01 0.25 0.00 Ethylbenzene 0.00 0.00 0.02 0.00 Xylenes 0.10 -0.03 0.07 0.00 Acrolein 0.91 0.00 0.91 0.00 Methanol 0.57 0.00 0.57 0.00 12.12 0.06 12.18 0.01 APPENDIX E UDAQ Equipment Forms Utah Division of Air Quality New Source Review Section Company___________________________ Site/Source__________________________ Form 4 Date_______________________________ Flare Systems Equipment Information 1. Manufacturer: _________________________ Model no.: _________________________ (if available) 2. Design and operation shall be in accordance with 40CFR63.11. In addition to the information listed in this form, provide the following: an assembly drawing with dimensions, interior dimensions and features, flare’s maximum capacity in BTU/hr. 3.Characteristics of Waste Gas Stream Input Components Min. Value Expected (scfm @ 68 oF, 14.7 psia) Ave. Value Expected (scfm @ 68oF, 14.7 psia) Design Max. (scfm @ 68oF, 14.7 psia) a. b. c. d. e. f. g. h. 4. Percent of time this condition occurs 5. Flow rate: Minimum Expected Design Maximum Temp oF Pressure (psig) Waste Gas Stream _______________ _______________ _______ ____________ Fuel Added to Gas Stream _______________ _______________ _______ ____________ Heat content of the gas to be flared ______________ BTU/ft3 6. Number of pilots 7. Type of fuel 8. Fuel Flow Rate (scfm @ 68oF & 14.7 psia) per pilot Page 1 of 3 Kinder Morgan Altamont LLC Bluebell Facility December 18, 2023 Tornado Technologies Pilot Gas Purge Gas FL-1: CS Condensate Tank Flare Tank Vapors 2.4 1.17 1.5 144.15 scfh 160 scfh 2,171.56 Natural Gas1 Page 2 of 3 Flare Systems Form 4 (Continued) Steam Injection 9. Steam pressure (psig) Minimum Expected __________________ Design Maximum __________________ 10. Total steam flow Rate (lb/hr) 11. Temperature (oF) 12. Velocity (ft/sec) 13. Number of jet streams 14. Diameter of steam jets (inches) 15. Design basis for steam injected (lb steam/lb hydrocarbon) Water Injection 16. Water pressure (psig) Minimum Expected __________________ Design Maximum __________________ 17. Total Water Flow Rate (gpm) Minimum Expected __________________ Design Maximum __________________ 18. Number of water jets 19. Diameter of Water jets (inches) 20. Flare height (ft) 21. Flare tip inside diameter (ft) Emissions Calculations (PTE) 22. Calculated emissions for this device PM10 _________Lbs/hr_________ Tons/yr PM2.5 __________Lbs/hr________ Tons/yr NOx __________Lbs/hr_________ Tons/yr SOx ___________Lbs/hr________ Tons/yr CO __________Lbs/hr_________ Tons/yr VOC ___________Lbs/hr________Tons/yr CO2 _________Tons/yr CH4 ___________Tons/yr N2O _________Tons/yr HAPs_________Lbs/hr (speciate)__________Tons/yr (speciate) Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix. 0.008 0.035 0.040 0.177 0.184 0.808 304.803 0.001 0.008 0.035 0.021 0.093 0.253 1.107 0.205 Utah Division of Air Quality New Source Review Section Company___________________________ Site/Source__________________________ Form 4 Date_______________________________ Flare Systems Equipment Information 1. Manufacturer: _________________________ Model no.: _________________________ (if available) 2. Design and operation shall be in accordance with 40CFR63.11. In addition to the information listed in this form, provide the following: an assembly drawing with dimensions, interior dimensions and features, flare’s maximum capacity in BTU/hr. 3.Characteristics of Waste Gas Stream Input Components Min. Value Expected (scfm @ 68 oF, 14.7 psia) Ave. Value Expected (scfm @ 68oF, 14.7 psia) Design Max. (scfm @ 68oF, 14.7 psia) a. b. c. d. e. f. g. h. 4. Percent of time this condition occurs 5. Flow rate: Minimum Expected Design Maximum Temp oF Pressure (psig) Waste Gas Stream _______________ _______________ _______ ____________ Fuel Added to Gas Stream _______________ _______________ _______ ____________ Heat content of the gas to be flared ______________ BTU/ft3 6. Number of pilots 7. Type of fuel 8. Fuel Flow Rate (scfm @ 68oF & 14.7 psia) per pilot Page 1 of 3 Kinder Morgan Altamont LLC Bluebell Facility December 18, 2023 Tornado Technologies Pilot Gas Purge Gas Tank Vapors 1.17 1.5 160 scfh Natural Gas1 FL-2: GP Condensate Tank Flare 20.58 1,234.99 scfh 2,418.15 Page 2 of 3 Flare Systems Form 4 (Continued) Steam Injection 9. Steam pressure (psig) Minimum Expected __________________ Design Maximum __________________ 10. Total steam flow Rate (lb/hr) 11. Temperature (oF) 12. Velocity (ft/sec) 13. Number of jet streams 14. Diameter of steam jets (inches) 15. Design basis for steam injected (lb steam/lb hydrocarbon) Water Injection 16. Water pressure (psig) Minimum Expected __________________ Design Maximum __________________ 17. Total Water Flow Rate (gpm) Minimum Expected __________________ Design Maximum __________________ 18. Number of water jets 19. Diameter of Water jets (inches) 20. Flare height (ft) 21. Flare tip inside diameter (ft) Emissions Calculations (PTE) 22. Calculated emissions for this device PM10 _________Lbs/hr_________ Tons/yr PM2.5 __________Lbs/hr________ Tons/yr NOx __________Lbs/hr_________ Tons/yr SOx ___________Lbs/hr________ Tons/yr CO __________Lbs/hr_________ Tons/yr VOC ___________Lbs/hr________Tons/yr CO2 _________Tons/yr CH4 ___________Tons/yr N2O _________Tons/yr HAPs_________Lbs/hr (speciate)__________Tons/yr (speciate) Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix. 0.037 0.162 0.1620.037 0.222 0.973 1.013 4.438 1,674.535 0.003 0.238 1.043 2.588 11.335 0.829 11:46 AM, 6/15/2010 VENDOR: CLIENT: PROJECT: QUOTE #: DESIGN CASE: SERVICE: DATE: [1] - Waste Gas Flow Rate 500,000.00 [SCFD]14,158.42 [SCMD] [2] - Fuel Gas Flow Rate 0.00 [SCFH]0.00 [SCMH] [3] - Waste Gas Inlet Temperature 80.00 [°F]26.67 [°C] [4] - Waste Gas Allowable Pressure Drop 5.00 [psig]34.48 [kPa] [5] - Ambient Air Temperature 60.00 [°F]15.56 [°C] [6] - Ambient Air Relative Humidity 80.00 [%]80.00 [%] [7] - Atmospheric Pressure 14.17 [psi]97.70 [kPa] [8] - Wind Speed for Radiation 29.33 [ft/s]8.94 [m/s] [9] - Flare Design Exit Mach Rating (as per API 521)0.20 [-]0.20 [-] [10] - Flare Gas Molecular Weight 22.70 [lb/lb-mol]22.70 [g/g-mol] FLARE DESIGN DATA SHEET Tornado Technologies Inc. Continuous Hydrocarbons June 15, 2010 FLARE DESIGN CRITERIA USED FLARE GAS CHARACTERISTICS [10] - Flare Gas Molecular Weight 22.70 [lb/lb-mol]22.70 [g/g-mol] [11] - Waste Gas Lower Heating Value 1202.20 [BTU/SCF]44.8 [MJ/SCM] [12] - Net Heat Release 28,745,780.84 [BTU/hr]30,328 [MJ/hr] [13] - Flare Height 40.00 [ft]12.2 [m] [14] - Tip Nominal Pipe Size 3.00 [in]0.076 [m] [15] - Purge Reducer Installed: [16] - Recommended Purge Flow Rate 90 [SCFH]2.5 [SCMH] [17] - Flare Tip Velocity 120.66 [ft/s]36.78 [m/s] [18] - Actual Flare Tip Exit Mach 0.10 [-]0.10 [-] [19] - Maximum Ground Level Radiation 510 [BTU/hr/ft2]1.61 [kW/m2] [20] - Radial Distance to Maximum Radiation 9.87 [ft]3.01 [m] [21] - Customer Specified Radial Distance to Determine Radiation 10.00 [ft]3.05 [m] [22] - Solar Radiation 300.00 [BTU/hr/ft2]0.95 [kW/m2] [23] - Radiation at Above Customer Specified Radial Distance 510.00 [BTU/hr/ft2]1.61 [kW/m2] [24] - Tip Pressure Drop at the Above Waste Gas Flow Rate 3.15 [in WC]0.78 [kPa] [25] - Purge Reducer Pressure Drop at the Above Waste Gas Flow Rate 0.00 [in WC]0.00 [kPa] [26] - Flare Riser Pressure Drop at the Above Waste Gas Flow Rate 1.28 [in WC]0.32 [kPa] [27] - Total Pressure Drop at the Above Waste Gas Flow Rate 4.43 [in. WC]1.10 [kPa] CALCULATED FLARE VALUES FLARE GEOMETRY No Seal Calgary Office 3236- 50 Ave. SE Calgary, Alberta T2B 3A3 Ph: (403) 244-3333 Fax: (403) 263-8399 Gadsby Office Box 1799 Settler, Alberta T0C 2L0 Ph: (403) 244-3333 Fax: (403) 263-8399 Texas Office 5854IH - 10 Alleyton,Texas 78935 - 2061 Ph: (979) 732-5546 Fax: (979) 732-2393 500 600 Ra d i a t i o n [ B T U / f t 2 / h r ] TORNADO TECHNOLOGIES INC. HEAT FLUX PROFILE 3 in. x 40 ft Flare Stack (Solar Radiation Included in Calculations) 0 100 200 300 400 0 200 400 600 800 1000 1200 1400 1600 Ra d i a t i o n [ B T U / f t 2 / h r ] Radial Distance [ft] 4'-o" 304SS 40•-o· 36'-o" I I NOTES T NOZZLE LEGEND BILL OF MATEAAL. TCT GAS STRIPPER TCT WINDSHROUD MK I QlY I sIzE IRATINGlcoNN.I DESCRIPTION MK I QlY DESCRIPTION MAfL e--11AF2 . o·T.O. STACK EL. n 40 - . o· 7'-4" 7- � TSl-6 PILOT N1 I 1 I 3• I 150# I RF I WASJE GAS INLET F1 I 1 I FLANGE; 3"-1 5 0# RFWN SA-105 F2 I 1 I CONCENTRIC REDUCER; 4" x 3" STD. WALL SA-234-WPB F3 I 1 I COUPLING; 1"-3000# NPT W/ HEX PLUG SA-105 P1 I 1 I PIPE; 4" STD. WALL SA-106B a::.....J.. 8" 4 LIFTING LUG PULLEY "{ b.. !: I I �- 0 �I 1'-4" �-IOTT P2 I 1 I PIPE; 3" STD. WALL SA-106B P3 I 1 I PIPE; 4" STD. WALL SA-106B P4 I 1 I PIPE; 3" STD. WALL 304SS S1 I 1 I PLATE; 1/2" x 16" x 16" (BASE PLATIE) SA-36 S2 I 4 I PLATE; 1/2" x 7" x 5• (GUSSET) I SA-36 S3 I 3 I PLATE; 1/2" x 7 3/4" x 3 1/4" (GUY WIRE LUG)I SA-36 S4 I 2 I PLATE; 1;2· x 5• x 4• (LIFTING LUG) SA-36 S5 I 1 I PLATE; 3/8" x 3 15/16" O.D. (SEAL PLATIE) SA-36 ,.....,____A � 1 GUY LUGS EL. 28' o• � II ◄ -+ 1'-4" Li '@ -+.I i- 8" ELEVATION VIEW SCALE: 3/16"=1'-0" 6"-+-1 II- � � I- t= � '::. t 1/2" SA-36 /I 0 oj--::!: WINCH 270" BASEPLATE DETAIL SCALE: 3/8"=1'-0" er TIRACKING SIDE; 1 1/8"1& HOLE (lYP. 4) GUSSET; 30" T i w:. JUNCTION BOX @ 2' -o• ELEV.; NAME TAG BRKT. @ 4' -o• ELEV. GUY LUG; - - -11<=-llllillllllf-A'-==90" GUSSET; /'-....Ur.--r�-, WASTE GAS INLET LIFTING LUG GUSSET; LIFTING LUG ® �AL- t--r 11-s..11 "-TIRACKING SUPPORT ---TRACKING � I� II 11 REJR.ICTING CABLE 1 EL. 5'-0"fn 4"-150# 1 EL. 4'-0" D / NAME TAG � JUNCTION Box-DJ tE JB-100 PIN I'--CABLE WINCH LAYDOWN ASSEMBLY NAME TAG BRACKET 225· WEEP HOLE 180" 150" GUSSET GUY LUG GUSSET 4 , _0• J.B. BRKT. 1 I 2''°" �- ORIENTATION PLAN SCALE: 3/4"=1'-0" (lYP. 4)� ®11 � f\/BASEPLATIE ELEVATION VIEW SHOWN W / TRACKING SCALE: 3/16"=1'-0" S1 . "LOWER ELEVATION SCALE: 1/2" = 1' -o• PAINT REQUIREMENTS· I This dra�ing is the property DRAWN: CHEa<ED: 3' X 40'-Q' TALL GlJY SUPPORTED ' of and intended o nly far ttie DG GK private use of TORNADO LITY FLARE MANUFACTURER: COMBUSTION TECHNOLOGIES, INC. �lE: 3/2/11 .IPPROIIED: GK lJTI SANDBLAST: and may not be reproduced P.O. No. JOBSITf or given to third parties without SC¥i ESr. WEIGHT: GENERAL ARRANGEMENT PRIMER: prior written consent. 3/16"=1'-0" 668 LBS I RE'IISION No. INTE:�!�:.! CUSTOMER: Tornado Combustion Technologies, Inc.· DRAWING No. � 16,mco mm, I o 3/2/11 oc GK GK osuro"' BUILT 4 • Alleyton, Texas 10856-30-100 No. �lE BY CHK'D. APP'D. DESCRFllON / I I// 1-888-732-2400 SHEET 1 of APPENDIX F Detailed Air Emissions Calculations Kinder Morgan Altamont, LLC ‐ Bluebell Facility December 2023 NOI Modification Application PTE Summary Emission Unit ID EU Description Make/ Model BSFC, HHV (Btu/bhp-hr) Heat Input (MMBtu/hr) Enforceable (Hrs/yr) Fuel HHV (Btu/scf) Fuel (MMscf/yr) Add-On Controls lb/hr tpy lb/hr tpy T-214 Pit Tank (condensate/water)400 bbl n/a 4,250,000 gal/yr n/a n/a FL-1 Not emitted Not emitted T-211, T-212, T-213 Condensate Storage Tanks (three)400 bbl n/a 4,250,000 gal/yr n/a n/a FL-1 Not emitted Not emitted FL-1 CS Condensate Tank Flare *NEW*Tornado 70 sch (pilot)n/a 0.1 8,760 NG 1,124 0.6 None 0.04 0.18 0.18 0.81 Truck Loading: Condensate *UPDATE*n/a 4,250,000 gal/yr n/a n/a None Not emitted Not emitted COM-2 Enclosed Combustor (TK-870, TK-874 vents) *REMOVE* Cimmaron 121 scfh (pilot)n/a 0.1 8,760 NG 1,124 1.1 None 0.01 0.05 0.01 0.01 FL-2 GP Condensate Tank Flare *NEW*Tornado 70 sch (pilot)n/a 0.1 8,760 NG 1,124 0.6 None 0.22 0.97 1.01 4.44 GPP-870, GPP-874 Condensate Storage Tanks (two). n/a 400 bbl n/a n/a 8,760 n/a n/a n/a COM-2 FL-2 Not emitted Not emitted TRK1 Truck Loading: Condensate Tanks *UPDATE*n/a 34 bbl/day n/a n/a 8,760 n/a n/a n/a None Not emitted Not emitted 0.25 1.10 1.20 5.24 131.44 104.28 132.54 109.52 Capacity (Site Rating) Bluebell Facility - Project Total Proposed Project Only Facility-wide Emissions Summary Permitted Bluebell Facility & Proposed Project NOx CO Existing Bluebell Facility Permitted Levels DAQE-AN102190015-21 Kinder Morgan Altamont, LLC ‐ Bluebell Facility December 2023 NOI Modification Application PTE Summary Emission Unit ID EU Description T-214 Pit Tank (condensate/water) T-211, T-212, T-213 Condensate Storage Tanks (three) FL-1 CS Condensate Tank Flare *NEW* Truck Loading: Condensate *UPDATE* COM-2 Enclosed Combustor (TK-870, TK-874 vents) *REMOVE* FL-2 GP Condensate Tank Flare *NEW* GPP-870, GPP-874 Condensate Storage Tanks (two). TRK1 Truck Loading: Condensate Tanks *UPDATE* Bluebell Facility - Project Total Proposed Project Only Facility-wide Emissions Summary Permitted Bluebell Facility & Proposed Project Existing Bluebell Facility Permitted Levels DAQE-AN102190015-21 lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy Not emitted Not emitted Not emitted 1.00 4.37 0.07 0.30 0.05 0.23 Not emitted Not emitted Not emitted 2.14 9.36 0.15 0.64 0.11 0.50 0.01 0.04 8.05E-03 0.04 Insignificant 0.25 1.11 0.02 0.09 3.56E-04 1.56E-03 0.01 0.06 Not emitted Not emitted Not emitted 2.46 10.76 0.14 0.61 0.10 0.45 9.20E-04 4.03E-03 9.20E-04 4.03E-03 7.26E-05 3.18E-04 3.54E-02 1.55E-01 1.02E-02 4.46E-02 9.08E-06 3.97E-05 2.49E-04 1.09E-03 0.04 0.16 0.04 0.16 Insignificant 2.59 11.33 0.24 1.04 0.00 0.01 0.15 0.65 Not emitted Not emitted Not emitted Vented to FL-2 Vented to FL-2 Not emitted Vented to FL-2 Not emitted Not emitted Not emitted 0.40 1.76 0.02 0.10 Not emitted 0.02 0.08 0.03 0.14 0.03 0.14 1.75E-03 0.01 0.34 1.48 0.01 0.06 0.002 0.01 0.01 0.06 3.64 3.64 1.43 110.77 12.12 6.29 1.49 3.78 3.78 1.44 112.25 12.18 6.30 1.56 Total HAP Formaldehyde n-HexanePM10 PM2.5 SO2 VOC Kinder Morgan Altamont, LLC ‐ Bluebell Facility December 2023 NOI Modification Application PTE Summary Emission Unit ID EU Description T-214 Pit Tank (condensate/water) T-211, T-212, T-213 Condensate Storage Tanks (three) FL-1 CS Condensate Tank Flare *NEW* Truck Loading: Condensate *UPDATE* COM-2 Enclosed Combustor (TK-870, TK-874 vents) *REMOVE* FL-2 GP Condensate Tank Flare *NEW* GPP-870, GPP-874 Condensate Storage Tanks (two). TRK1 Truck Loading: Condensate Tanks *UPDATE* Bluebell Facility - Project Total Proposed Project Only Facility-wide Emissions Summary Permitted Bluebell Facility & Proposed Project Existing Bluebell Facility Permitted Levels DAQE-AN102190015-21 lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy 3.48E-03 1.52E-02 0.01 0.03 4.21E-03 1.85E-02 0.00 0.00 1.11E-03 4.86E-03 Not emitted Not emitted 7.44E-03 3.26E-02 0.01 0.05 9.02E-03 3.95E-02 0.00 0.00 2.37E-03 1.04E-02 Not emitted Not emitted 1.10E-03 4.81E-03 0.00 0.01 1.55E-03 6.79E-03 No factor No factor No factor No factor 0.01 0.04 1.19E-02 5.20E-02 1.41E-03 6.16E-03 3.71E-03 1.63E-02 Not emitted Not emitted No factor 7.46E-03 3.27E-02 2.46E-03 1.08E-02 No factor No factor No factor No factor 1.12E-02 4.91E-02 1.44E-02 6.29E-02 1.54E-02 6.75E-02 No factor No factor No factor No factor Vented to FL-2 Vented to FL-2 Vented to FL-2 Vented to FL-2 Vented to FL-2 Not emitted Not emitted 1.35E-03 5.90E-03 1.78E-03 7.78E-03 1.84E-03 8.04E-03 2.09E-04 9.15E-04 4.52E-04 1.98E-03 Not emitted Not emitted -1.09E-03 0.00 -0.02 -0.09 2.70E-03 0.01 3.11E-04 0.0014 -0.01 -0.03 0.00 0.00 -1.65E-04 0.00 0.11 0.41 0.24 1.45E-02 0.10 0.91 0.57 0.11 0.32 0.25 0.016 0.07 0.91 0.57 Ethylbenzene Xylenes Acrolein Methanol2,2,4-Trimethylpentane Benzene Toluene Kinder Morgan Altamont, LLC ‐ Bluebell Facility December 2023 NOI Modification Application PTE Summary Emission Unit ID EU Description T-214 Pit Tank (condensate/water) T-211, T-212, T-213 Condensate Storage Tanks (three) FL-1 CS Condensate Tank Flare *NEW* Truck Loading: Condensate *UPDATE* COM-2 Enclosed Combustor (TK-870, TK-874 vents) *REMOVE* FL-2 GP Condensate Tank Flare *NEW* GPP-870, GPP-874 Condensate Storage Tanks (two). TRK1 Truck Loading: Condensate Tanks *UPDATE* Bluebell Facility - Project Total Proposed Project Only Facility-wide Emissions Summary Permitted Bluebell Facility & Proposed Project Existing Bluebell Facility Permitted Levels DAQE-AN102190015-21 lb/hr tpy lb/hr tpy lb/hr tpy lb/hr tpy Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted 69.59 304.80 0.047 0.21 0.00 0.00 70.800 310.10 Not emitted Not emitted Not emitted 25.04 109.68 1.72E-03 7.52E-03 4.73E-05 2.07E-04 2.51E+01 1.10E+02 382.31 1,674.54 0.19 0.83 7.21E-04 3.16E-03 387.26 1,696.20 Not emitted Not emitted Not emitted Not emitted Not emitted Not emitted 426.86 1,869.66 0.23 1.03 8.04E-04 0.00 432.76 1,895.48 73,740.55 1375.82 0.13 108,176.00 75,610.21 1,376.85 0.13 110,071.48 CO2eCarbon Dioxide Methane N2O Emissions Impact Assessment Bluebell Facility / December 2023 Modification Primary Pollutant Emissions (TPY) Modeling Threshold (TPY) Modeling Required? Nitrogen Oxides (NOx)1.10 40 NO Carbon Monoxide (CO)5.24 100 NO Sulfur Dioxide (SO2)0.01 40 NO PM10 (non‐fugitive)0.14 15 NO HAP Constituent Emissions (lb/hr) Modeling Threshold (lb/hr) Modeling Required? 2,2,4‐Trimethylpentane ‐4.78E‐03 0.29 NO Benzene ‐8.73E‐02 0.32 NO n‐Hexane 6.41E‐02 34.90 NO Toluene 1.18E‐02 14.92 NO Xylene ‐3.18E‐02 22.14 NO Formaldehyde 1.09E‐02 0.06 NO A new source or modification in an attainment area with a total controlled emission rate per pollutant greater than or equal to amounts specified in following table, or a modification to an existing source located in an attainment area which increases the total controlled emission rate per pollutant of the source in an amount greater than or equal to those specified in the following table, shall conduct air quality modeling. R307‐410‐4 Based on comparisons of the emissions increases to the modeling thresholds described in R307‐410‐4, modeling is not required for the proposed modification at the Bluebell Facility. Bluebell Facility Condensate Tank Flare (FL‐1) Emissions Calculations Updated: 12/18/2023 Make/Model:Annual hours operated:8,760 Destruction Efficiency (%):98 Pilot & Purge Gas Streams 7 Flow Rate (scfh) CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6+ HHV (btu/scf) Pilot Gas 70 0.542 0.808 89.868 6.880 1.605 0.113 0.130 0.011 0.000 0.001 1,761.60 Purge Gas 90 0.542 0.808 89.868 6.880 1.605 0.113 0.130 0.011 0.000 0.001 1,761.60 Waste Gas Streams to Flare7 Flow Rate (scfh) CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6+ HHV (btu/scf) CS T‐211, T‐212, T‐213, T‐214 Flashing Losses 106.55 0.729 0.110 28.395 17.077 18.702 4.417 10.545 3.607 4.515 5.717 2,084.88 CS T‐211, T‐212, T‐213, T‐214 Working Losses 22.33 0.587 0.009 8.100 23.241 24.755 5.722 13.542 4.536 5.629 6.795 2,417.10 CS T‐211, T‐212, T‐213, T‐214 Standing Losses 15.28 0.587 0.009 8.100 23.241 24.755 5.722 13.542 4.536 5.629 6.795 2,417.10 144.15 2,171.56 Continuent EF Units (lb/hr)(tpy)(lb/hr)(tpy)(lb/hr)(tpy)(lb/hr)(tpy)(lb/hr)(tpy)(lb/hr)(tpy) NOx1 0.068 lb/MMBtu 0.008 0.037 0.011 0.047 0.015 0.066 0.004 0.016 0.003 0.011 0.040 0.177 CO2 0.310 lb/MMBtu 0.038 0.167 0.049 0.215 0.069 0.302 0.017 0.073 0.011 0.050 0.184 0.808 Uncontrolled VOC3 0.178 0.782 0.229 1.005 8.447 36.997 2.246 9.836 1.536 6.728 12.636 55.348 Controlled VOC4 0.004 0.016 0.005 0.020 0.169 0.740 0.045 0.197 0.031 0.135 0.253 1.107 PM10 or PM2.56 40 µg/L 0.002 0.008 0.002 0.010 0.003 0.012 0.001 0.003 0.000 0.002 0.008 0.035 Benzene 2.504E‐07 1.097E‐06 3.219E‐07 1.41E‐06 8.94E‐04 3.91E‐03 2.28E‐04 9.97E‐04 1.56E‐04 6.82E‐04 0.001 0.006 Toluene 1.507E‐08 6.602E‐08 1.938E‐08 8.489E‐08 1.09E‐03 4.79E‐03 2.71E‐04 1.19E‐03 1.85E‐04 8.11E‐04 0.002 0.007 n‐Hexane 8.12E‐07 3.55E‐06 1.04E‐06 4.57E‐06 9.23E‐03 4.04E‐02 2.34E‐03 1.02E‐02 1.60E‐03 7.01E‐03 0.013 0.058 2,2,4‐Trimethylpentane 1.675E‐08 7.335E‐08 2.153E‐08 9.43E‐08 7.74E‐04 3.39E‐03 1.93E‐04 8.44E‐04 1.32E‐04 5.77E‐04 0.001 0.005 Controlled HAP5 8.63E‐06 3.78E‐05 8.63E‐06 3.78E‐05 1.49E‐02 0.065 3.74E‐03 0.016 2.56E‐03 0.011 0.021 0.093 Formadehyde8 1.169 lb/MMscf 8.18E‐05 3.58E‐04 1.05E‐04 4.61E‐04 0.000 0.001 0.000 0.000 0.000 0.000 0.000 0.002 CO29 116.978 lb/MMBtu 14.42 63.18 18.55 81.23 25.98 113.81 6.31 27.66 4.32 18.92 69.590 304.803 CH4 0.008 0.036 0.010 0.046 0.026 0.112 0.002 0.007 0.001 0.005 0.047 0.205 N2O9 0.0002 lb/MMBtu 2.72E‐05 1.19E‐04 3.50E‐05 1.53E‐04 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.001 Equations: CS T‐211, T‐212, T‐213, T‐214 Working Losses CS T‐211, T‐212, T‐213, T‐214 Standing Losses Tornado (Elevated Flare) Stream Composition (% by volume) Total Stream Calculated Criteria Emissions TotalEmission Factor Pilot CS T‐211, T‐212, T‐213, T‐214 Flashing LossesPurge see Equations see Equations see Equations see Equations see Equations see Equations see Equations see Equations 𝑁𝑂𝑥,𝐶𝑂,𝐶𝑂2,𝐶𝐻4 & 𝑁2𝑂 𝑙𝑏 ℎ𝑟ൌ𝐸𝐹 𝑙𝑏 𝑀𝑀𝑏𝑡𝑢 𝑥 𝐹𝑙𝑜𝑤 𝑅𝑎𝑡𝑒 𝑠𝑐𝑓 ℎ𝑟𝑥 𝐻𝐻𝑉 𝑏𝑡𝑢 𝑠𝑐𝑓 𝑥1 𝑀𝑀𝑏𝑡𝑢 1000000 𝑏𝑡𝑢 1. NOx EF from USEPA AP‐42, Chapter 13, Section 5, Tables 13.5‐1 2. CO EF from USEPA AP‐42, Chapter 13, Section 5, Table 13.5‐2 3. Uncontrolled VOC calculated based on the VOC fraction of each individual stream (see Uncontrolled VOC calculation equation below). 4. Controlled VOC represents the VOC fraction of each individual stream with a 98% destruction efficiency applied. (see Controlled VOC equation below). 5. Controlled HAPs calculated based on the HAP weight fraction of each individual stream. A 98% destruction efficiency rating is applied to calculate controlled emissions. 6. PM10 or PM2.5 factors are identical. From AP‐42 Tables 13.5‐1 & 2 (lightly smoking) 7. Stream compositions are representative based on measurements and facility knowledge. 8. Formaldehyde EF from Ventura County Air Pollution Control District AB2588 Combustion Emissions Factors (May 17, 2001). 9. CO2 EF from Table C‐1 of 40 CFR 98 and N2O EF from Table C‐2 of 40 CFR 98. 𝑃𝑀10 𝑙𝑏 ℎ𝑟ൌ𝐸𝐹 µ 𝐿 𝑥 𝐹𝑙𝑜𝑤 𝑠𝑐𝑓 ℎ𝑟𝑥 10.6 𝑠𝑐𝑓 𝑠𝑐𝑓 𝐶𝐻4 𝑥 0.0283 𝑚ଷ 𝑠𝑐𝑓 𝑥 1000 𝐿 𝑚ଷ 𝑥1𝑔 10଺ µ𝑔 𝑥𝑙𝑏 453.59𝑔 𝑈𝑛𝑐𝑜𝑛𝑡𝑟𝑜𝑙𝑙𝑒𝑑 𝑂𝑟𝑔𝑎𝑛𝑖𝑐 𝑜𝑟𝑔𝑙𝑏 ℎ𝑟ൌ𝑇𝑜𝑡𝑎𝑙 𝑆𝑡𝑟𝑒𝑎𝑚 𝑅𝑎𝑡𝑒𝑠𝑐𝑓௧ ℎ𝑟𝑥 𝑆𝑡𝑟𝑒𝑎𝑚 𝑚𝑜𝑙𝑒𝑐𝑢𝑙𝑎𝑟 𝑤𝑒𝑖𝑔ℎ𝑡𝑙𝑏௢௥௚ 𝑙𝑏𝑚𝑜𝑙௢௥௚ 𝑥1 𝑚𝑜𝑙௢௥௚ 379.1𝑠𝑐𝑓௢௥௚ 𝑥 𝑂𝑟𝑔𝑎𝑛𝑖𝑐 𝑤𝑒𝑖𝑔ℎ𝑡 𝑓𝑟𝑎𝑐𝑡𝑖𝑜𝑛 𝐶𝑜𝑛𝑡𝑟𝑜𝑙𝑙𝑒𝑑 𝑂𝑟𝑔𝑎𝑛𝑖𝑐𝑙𝑏 ℎ𝑟ൌ 𝑈𝑛𝑐𝑜𝑛𝑡𝑟𝑜𝑙𝑙𝑒𝑑 𝑂𝑟𝑔𝑎𝑛𝑖𝑐𝑙𝑏 ℎ𝑟𝑥 1 െ 𝑑𝑒𝑠𝑡𝑟𝑢𝑐𝑡𝑖𝑜𝑛 𝑒𝑓𝑓𝑖𝑐𝑖𝑒𝑛𝑐𝑦 Bluebell Facility Condensate Tank Flare (FL‐2) Emissions Calculations Updated: 12/18/2023 Make/Model:Annual hours operated:8,760 Destruction Efficiency (%):98 Pilot & Purge Gas Streams 7 Flow Rate (scfh) CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6+ HHV (btu/scf) Pilot Gas 70 0.542 0.808 89.868 6.880 1.605 0.113 0.130 0.011 0.000 0.001 1,761.60 Purge Gas 90 0.542 0.808 89.868 6.880 1.605 0.113 0.130 0.011 0.000 0.001 1,761.60 Waste Gas Streams to Flare7 Flow Rate (scfh) CO2 N2 C1 C2 C3 iC4 nC4 iC5 nC5 C6+ HHV (btu/scf) GPP TK‐870, TK‐874 Flashing Losses 1,210.01 0.393 0.026 16.380 14.122 21.070 5.907 14.624 5.377 6.883 7.371 2,417.54 GPP TK‐870, TK‐874 Working Losses 15.52 0.443 0.007 13.697 15.689 22.590 6.160 15.077 5.399 6.837 6.911 2,447.84 GPP TK‐870, TK‐874 Standing Losses 9.47 0.443 0.007 13.697 15.689 22.590 6.160 15.077 5.399 6.837 6.911 2,447.84 1,234.99 2,418.15 Continuent EF Units (lb/hr)(tpy)(lb/hr)(tpy)(lb/hr)(tpy)(lb/hr)(tpy)(lb/hr)(tpy)(lb/hr)(tpy) NOx1 0.068 lb/MMBtu 0.008 0.037 0.011 0.047 0.199 0.871 0.003 0.011 0.002 0.007 0.222 0.973 CO2 0.310 lb/MMBtu 0.038 0.167 0.049 0.215 0.907 3.972 0.012 0.052 0.007 0.031 1.013 4.438 Uncontrolled VOC3 0.178 0.782 0.229 1.005 126.337 553.357 1.642 7.193 1.002 4.390 129.390 566.727 Controlled VOC4 0.004 0.016 0.005 0.020 2.527 11.067 0.033 0.144 0.020 0.088 2.588 11.335 PM10 or PM2.56 40 µg/L 0.002 0.008 0.002 0.010 0.032 0.140 0.000 0.002 0.000 0.001 0.037 0.162 Benzene 2.504E‐07 1.097E‐06 3.219E‐07 1.41E‐06 1.41E‐02 6.17E‐02 1.74E‐04 7.60E‐04 1.06E‐04 4.64E‐04 0.014 0.063 Toluene 1.507E‐08 6.602E‐08 1.938E‐08 8.489E‐08 1.51E‐02 6.62E‐02 1.79E‐04 7.86E‐04 1.10E‐04 4.80E‐04 0.015 0.067 n‐Hexane 8.12E‐07 3.55E‐06 1.04E‐06 4.57E‐06 1.46E‐01 6.37E‐01 1.78E‐03 7.81E‐03 1.09E‐03 4.76E‐03 0.148 0.650 2,2,4‐Trimethylpentane 1.675E‐08 7.335E‐08 2.153E‐08 9.43E‐08 1.10E‐02 4.82E‐02 1.32E‐04 5.77E‐04 8.04E‐05 3.52E‐04 0.011 0.049 Controlled HAP5 8.63E‐06 3.78E‐05 8.63E‐06 3.78E‐05 2.34E‐01 1.023 2.83E‐03 0.012 1.73E‐03 0.008 0.238 1.043 Formadehyde8 1.169 lb/MMscf 8.18E‐05 3.58E‐04 1.05E‐04 4.61E‐04 0.001 0.006 0.000 0.000 0.000 0.000 0.002 0.007 CO29 116.978 lb/MMBtu 14.42 63.18 18.55 81.23 342.19 1,498.79 4.44 19.46 2.71 11.88 382.314 1674.535 CH4 0.008 0.036 0.010 0.046 0.168 0.735 0.002 0.008 0.001 0.005 0.189 0.829 N2O9 0.0002 lb/MMBtu 2.72E‐05 1.19E‐04 3.50E‐05 1.53E‐04 0.001 0.003 0.000 0.000 0.000 0.000 0.001 0.003 Equations: see Equations see Equations see Equations see Equations GPP TK‐870, TK‐874 Standing Losses Total see Equations see Equations see Equations see Equations Emission Factor Pilot Purge GPP TK‐870, TK‐874 Flashing Losses GPP TK‐870, TK‐874 Working Losses Tornado (Elevated Flare) Stream Composition (% by volume) Total Stream Calculated Criteria Emissions 𝑁𝑂𝑥,𝐶𝑂,𝐶𝑂2,𝐶𝐻4 & 𝑁2𝑂 𝑙𝑏 ℎ𝑟ൌ𝐸𝐹 𝑙𝑏 𝑀𝑀𝑏𝑡𝑢 𝑥 𝐹𝑙𝑜𝑤 𝑅𝑎𝑡𝑒 𝑠𝑐𝑓 ℎ𝑟𝑥 𝐻𝐻𝑉 𝑏𝑡𝑢 𝑠𝑐𝑓 𝑥1 𝑀𝑀𝑏𝑡𝑢 1000000 𝑏𝑡𝑢 1. NOx EF from USEPA AP‐42, Chapter 13, Section 5, Tables 13.5‐1 2. CO EF from USEPA AP‐42, Chapter 13, Section 5, Table 13.5‐2 3. Uncontrolled VOC calculated based on the VOC fraction of each individual stream (see Uncontrolled VOC calculation equation below). 4. Controlled VOC represents the VOC fraction of each individual stream with a 98% destruction efficiency applied. (see Controlled VOC equation below). 5. Controlled HAPs calculated based on the HAP weight fraction of each individual stream. A 98% destruction efficiency rating is applied to calculate controlled emissions. 6. PM10 or PM2.5 factors are identical. From AP‐42 Tables 13.5‐1 & 2 (lightly smoking) 7. Stream compositions are representative based on measurements and facility knowledge. 8. Formaldehyde EF from Ventura County Air Pollution Control District AB2588 Combustion Emissions Factors (May 17, 2001). 9. CO2 EF from Table C‐1 of 40 CFR 98 and N2O EF from Table C‐2 of 40 CFR 98. 𝑃𝑀10 𝑙𝑏 ℎ𝑟ൌ𝐸𝐹 µ 𝐿 𝑥 𝐹𝑙𝑜𝑤 𝑠𝑐𝑓 ℎ𝑟𝑥 10.6 𝑠𝑐𝑓 𝑠𝑐𝑓 𝐶𝐻4 𝑥 0.0283 𝑚ଷ 𝑠𝑐𝑓 𝑥 1000 𝐿 𝑚ଷ 𝑥1𝑔 10଺ µ𝑔 𝑥𝑙𝑏 453.59𝑔 𝑈𝑛𝑐𝑜𝑛𝑡𝑟𝑜𝑙𝑙𝑒𝑑 𝑂𝑟𝑔𝑎𝑛𝑖𝑐 𝑜𝑟𝑔𝑙𝑏 ℎ𝑟ൌ𝑇𝑜𝑡𝑎𝑙 𝑆𝑡𝑟𝑒𝑎𝑚 𝑅𝑎𝑡𝑒𝑠𝑐𝑓௧ ℎ𝑟𝑥 𝑆𝑡𝑟𝑒𝑎𝑚 𝑚𝑜𝑙𝑒𝑐𝑢𝑙𝑎𝑟 𝑤𝑒𝑖𝑔ℎ𝑡𝑙𝑏௢௥௚ 𝑙𝑏𝑚𝑜𝑙௢௥௚ 𝑥1 𝑚𝑜𝑙௢௥௚ 379.1𝑠𝑐𝑓௢௥௚ 𝑥 𝑂𝑟𝑔𝑎𝑛𝑖𝑐 𝑤𝑒𝑖𝑔ℎ𝑡 𝑓𝑟𝑎𝑐𝑡𝑖𝑜𝑛 𝐶𝑜𝑛𝑡𝑟𝑜𝑙𝑙𝑒𝑑 𝑂𝑟𝑔𝑎𝑛𝑖𝑐𝑙𝑏 ℎ𝑟ൌ 𝑈𝑛𝑐𝑜𝑛𝑡𝑟𝑜𝑙𝑙𝑒𝑑 𝑂𝑟𝑔𝑎𝑛𝑖𝑐𝑙𝑏 ℎ𝑟𝑥 1 െ 𝑑𝑒𝑠𝑡𝑟𝑢𝑐𝑡𝑖𝑜𝑛 𝑒𝑓𝑓𝑖𝑐𝑖𝑒𝑛𝑐𝑦 Bluebell Facility VOC Emissions from Truck Loading Condensate Storage Tanks (TK‐870a, TK‐870b) Uncontrolled Controlled Bluebell Facility Condensate Submerged loading: dedicated normal service 12,514 bbl/year 525.6 0.6 9.95 48.00 73 6.70 0.00% 6.698 1.8 tpy 1.8 tpy 12,514 bbls/yr 34 bbls/day of crude oil is assumed loaded to trucks for 365 days per year. 1 Source: AP‐42 Table 5.2‐1 (1/95) 2 Equation 1 for loading losses: (12.46) * (SPM / T) = LL Where: LL = loading losses, lbs/1000 gal of liquid loaded S = saturation factor M = Molecular wt of vapors, lb/lb‐mol (from Bryan Research & Engineering, Inc. ProMax™ 3.2 simulation software program for BTEX_Bluebell 30 MMSCFD_02_08_1018.pmx.xlsx. T = temperature of bulk liquids loaded oR (oF = 460) AP‐42 Chapter 5.2, Table 5.2‐1 (1/95) 0.5 HAP Wt. % 3 Uncontrolled Controlled 0.6 Benzene 0.4418 0.0296 lb/kgal 15.6 lb/yr 0.01 tpy 15.55 lb/yr 0.01 tpy 1.0 Toluene 0.4567 0.0306 lb/kgal 16.1 lb/yr 0.01 tpy 16.08 lb/yr 0.01 tpy 1.45 Ethylbenzene 0.0520 0.0035 lb/kgal 1.8 lb/yr 0.00 tpy 1.83 lb/yr 0.00 tpy 1.45 Xylenes 0.1124 0.0075 lb/kgal 4.0 lb/yr 0.00 tpy 3.96 lb/yr 0.00 tpy 1 n‐Hexane 4.5362 0.3038 lb/kgal 159.7 lb/yr 0.08 tpy 159.69 lb/yr 0.08 tpy 0.2 2,2,4 Trimethylpentane 0.3351 0.0224 lb/kgal 11.8 lb/yr 0.01 tpy 11.80 lb/yr 0.01 tpy 0.5 Total 208.9 lb/yr 0.10 tpy 208.90 lb/yr 0.10 tpy Sales (kgal/year) Saturation Factor (S) 1 3 Condensate Tank W&S Vapor from Bryan Research & Engineering, Inc. ProMax™ 3.2 simulation software program from Bluebell Tank Emissions without stabilizer 062023 (27.5MM to plant)_Rev1.xlsx. VOC Emissions P = true vapor pressure of liquid loaded (psia). TVP derived from stream compositions in Bryan Research & Engineering, Inc. ProMax™ 3.2 simulation software program for BTEX_Bluebell 30 MMSCFD_02_08_1018.pmx.xlsx. HAP Emissions Tank trucks and rail tank cars Submerged loading of a clean cargo tank Submerged loading: dedicated normal service Submerged loading: dedicated vapor balance service True Vapor Pressure (P) [psia] Molecular Weight (M) [lb/lb‐mol] Bulk Temp. (T) [F] Uncontrolled Loading Loss (LL) 2 [lb/kgal] Control Efficiency [%] Controlled Loading Loss (LL) [lb/kgal] Splash loading: dedicated vapor balance service Marine vessels Submerged loading: ships Submerged loading: barges Site Product Loading Mode Splash loading of a clean cargo tank Splash loading: dedicated normal service Sales Bluebell Facility VOC Emissions from Truck Loading Condensate Storage Tanks (CS T‐211, T‐212, T‐213, T‐214) Uncontrolled Controlled Bluebell Facility Condensate Submerged loading: dedicated normal service 101,196 bbl/year 4,250 0.6 7.58 47.48 71 5.06 0.00% 5.062 10.76 tpy 10.76 tpy 101,196 bbls/yr 277 bbls/day of crude oil is assumed loaded to trucks for 365 days per year. 1 Source: AP‐42 Table 5.2‐1 (1/95) 2 Equation 1 for loading losses: (12.46) * (SPM / T) = LL Where: LL = loading losses, lbs/1000 gal of liquid loaded S = saturation factor M = Molecular wt of vapors, lb/lb‐mol (from Bryan Research & Engineering, Inc. ProMax™ 3.2 simulation software program from Bluebell Tank Emissions without stabilizer 062023 (27.5MM to plant)_Rev1.xlsx. T = temperature of bulk liquids loaded oR (oF = 460) AP‐42 Chapter 5.2, Table 5.2‐1 (1/95) 0.5 HAP Wt. % 3 Uncontrolled Controlled 0.6 Benzene 0.4069 0.0206 lb/kgal 87.5 lb/yr 0.04 tpy 87.54 lb/yr 0.04 tpy 1.0 Toluene 0.4838 0.0245 lb/kgal 104.1 lb/yr 0.05 tpy 104.09 lb/yr 0.05 tpy 1.45 Ethylbenzene 0.0573 0.0029 lb/kgal 12.3 lb/yr 0.01 tpy 12.32 lb/yr 0.01 tpy 1.45 Xylenes 0.1511 0.0077 lb/kgal 32.5 lb/yr 0.02 tpy 32.52 lb/yr 0.02 tpy 1 n‐Hexane 4.1830 0.2118 lb/kgal 900.0 lb/yr 0.45 tpy 900.04 lb/yr 0.45 tpy 0.2 2,2,4 Trimethylpentane 0.3443 0.0174 lb/kgal 74.1 lb/yr 0.04 tpy 74.08 lb/yr 0.04 tpy 0.5 Total 1,210.6 lb/yr 0.61 tpy 1,210.58 lb/yr 0.61 tpy Splash loading of a clean cargo tank Splash loading: dedicated normal service Splash loading: dedicated vapor balance service Marine vessels Submerged loading: ships Submerged loading: barges 3 Condensate Tank W&S Vapor from Bryan Research & Engineering, Inc. ProMax™ 3.2 simulation software program from Bluebell Tank Emissions without stabilizer 062023 (27.5MM to plant)_Rev1.xlsx. VOC Emissions P = true vapor pressure of liquid loaded (psia). TVP derived from stream compositions in Bryan Research & Engineering, Inc. ProMax™ 3.2 simulation software program from Bluebell Tank Emissions without stabilizer 062023 (27.5MM to plant)_Rev1.xlsx. HAP Emissions Tank trucks and rail tank cars Submerged loading of a clean cargo tank Submerged loading: dedicated normal service Submerged loading: dedicated vapor balance service True Vapor Pressure (P) [psia] Molecular Weight (M) [lb/lb‐mol] Bulk Temp. (T) [F] Uncontrolled Loading Loss (LL) 2 [lb/kgal] Control Efficiency [%] Controlled Loading Loss (LL) [lb/kgal]Site Product Loading Mode Sales Sales (kgal/year) Saturation Factor (S) 1 APPENDIX G Promax Simulation Report Flowsheet Atmospheric Tanks Flowsheet Atmospheric Tanks_at Comp Station Tank Losses Block Name TK‐870/874 Tank Losses Block Inlet Stream 3015 Tank Type Time Frame Material Category Number of Tanks Shell Height [ft] Diameter [ft] [ft] Maximum Liquid Height [%] | [ft] 90.000 18.000 Average Liquid Height [%] | [ft] 50.000 10.000 Minimum Liquid Height [%] | [ft] 10.000 2.000 Sum of Increases in Liquid Level [ft/yr] Tank Volume [gal] | [bbl] 16920.536 402.870 Insulation Bolted or Riveted Construction Vapor Balanced Tank Shell Color Shell Paint Condition Roof Color Roof Paint Condition Type Diameter [ft] Slope [ft/ft] Breather Vacuum Pressure [psig] Breather Vent Pressure [psig] False Tank Parameters Tank Characteristics Vertical Cylinder June Light Organics 2 20.000 12.000 1219.633 Uninsulated False 0.625 Paint Characteristics Tan Average Tan Average Roof Characteristics Cone ‐ 0.063 Breather Vent Settings ‐0.025 Cargo Carrier Land Based Mode of Operation Marine Based Mode of Operation Control Efficiency [%] Truck Annual Leak Test Passed Overall Reduction Efficiency [%] Location Average Atmospheric Pressure [psia] Maximum Average Temperature [°F] Minimum Average Temperature [°F] Solar Insolation [BTU/ft^2*day] Average Wind Speed [mph] Flashing Temperature [°F] Maximum Liquid Surface Temperature [°F] Average Liquid Surface Temperature [°F] Known Liquid Bulk Temperature? Bulk Liquid Temperature [°F] Net Throughput [bbl/day] | [bbl/yr] 134.631 49140.439 Net Throughput Per Tank [bbl/day] | [bbl/yr] 67.316 24570.219 Annual Turnovers Per Tank Residual Liquid [bbl/day] Residual Liquid Per Tank [bbl/day] Raoult's Law Used for Vapor Pressure Calc? Vapor Pressure @ Minimum Liquid Surface Temperature [psia] Vapor Pressure @ Maximum Liquid Surface Temperature [psia] Vapor Pressure @ Average Daily Liquid Surface Temperature [psia] Heated Tank? Number of Heating Cycles Maximum Liquid Bulk Temperature [°F] Minimum Liquid Bulk Temperature [°F] 57.300 Loading Loss Parameters Tank Truck or Rail Tank Car ubmerged Loading of a Clean Cargo Tank ‐ ‐ ‐ 0.000 Meteorological Data Salt Lake City, UT 12.620 81.800 False 2336.000 9.200 Tank Conditions 85.532 85.532 75.900 False 72.984 76.227 133.626 66.813 ‐ ‐ 9.641 12.620 11.034 Tank Conditions ‐ ‐ Tank Losses Block Name TK_901/910/921C/931 Tank Losses Block Inlet Stream 3033 Tank Type Time Frame Material Category Number of Tanks Shell Height [ft] Diameter [ft] [ft] Maximum Liquid Height [%] | [ft] 90.000 18.000 Average Liquid Height [%] | [ft] 50.000 10.000 Minimum Liquid Height [%] | [ft] 10.000 2.000 Sum of Increases in Liquid Level [ft/yr] Tank Volume [gal] | [bbl] 16920.536 402.870 Insulation Bolted or Riveted Construction Vapor Balanced Tank Shell Color Shell Paint Condition Roof Color Roof Paint Condition Type Diameter [ft] Slope [ft/ft] Breather Vacuum Pressure [psig] Breather Vent Pressure [psig] Cargo Carrier Land Based Mode of Operation Marine Based Mode of Operation Control Efficiency [%] Truck Annual Leak Test Passed Overall Reduction Efficiency [%] Location Average Atmospheric Pressure [psia] Maximum Average Temperature [°F] Minimum Average Temperature [°F] Solar Insolation [BTU/ft^2*day] Average Wind Speed [mph] Flashing Temperature [°F] Maximum Liquid Surface Temperature [°F] Average Liquid Surface Temperature [°F] Known Liquid Bulk Temperature? Bulk Liquid Temperature [°F] Net Throughput [bbl/day] | [bbl/yr] 241.495 88145.840 Net Throughput Per Tank [bbl/day] | [bbl/yr] 60.374 22036.460 Annual Turnovers Per Tank Residual Liquid [bbl/day] Residual Liquid Per Tank [bbl/day] Raoult's Law Used for Vapor Pressure Calc? Vapor Pressure @ Minimum Liquid Surface Temperature [psia] Vapor Pressure @ Maximum Liquid Surface Temperature [psia] Vapor Pressure @ Average Daily Liquid Surface Temperature [psia] Heated Tank? False Tank Parameters Tank Characteristics Vertical Cylinder June Light Organics 4 20.000 12.000 1093.860 Uninsulated False 0.500 Paint Characteristics White Average White Average Roof Characteristics Cone ‐ 0.063 Breather Vent Settings ‐0.025 57.300 Loading Loss Parameters Tank Truck or Rail Tank Car ubmerged Loading of a Clean Cargo Tank ‐ ‐ ‐ 0.000 Meteorological Data Salt Lake City, UT 12.620 81.800 False 2336.000 9.200 Tank Conditions 80.273 80.273 72.790 False 71.302 68.366 240.432 60.108 10.512 12.620 11.519 Tank Conditions ‐ 2 Emissions TK‐870/874 Emission Summary Component Subset Tank Losses Flashing Losses Working Losses Standing Losses Loading Losses [ton/yr] [ton/yr] [ton/yr] HAPs 42.69 41.87 0.51 0.31 0.37 [ton/yr] [ton/yr] VOCs 564.37 552.80 7.19 4.39 5.16 H2S 0.01 0.01 0.00 0.00 0.00 BTEX 7.77 7.62 0.09 0.06 0.07 [ton/yr] [ton/yr] VOCs 282.18 276.40 3.59 2.19 2.58 Emission Summary [Per Tank] Component Subset Tank Losses Flashing Losses Working Losses Standing Losses Loading Losses [ton/yr] [ton/yr] [ton/yr] BTEX 3.89 3.81 0.05 0.03 0.03 HAPs 21.34 20.93 0.26 0.16 0.18 Stream Properties Tank Inlet Flashing Losses Working Losses Standing Losses Loading Losses Residual H2S 0.00 0.00 0.00 0.00 0.00 48.00 65.19 Net Ideal Gas Heating Value [BTU/scf]‐2417.54 2447.84 2447.84 2447.84 ‐ Molecular Weight [lb/lbmol]62.87 47.50 48.00 48.00 267.34 ‐ Specific Gravity ‐‐‐‐ ‐0.71 Standard Vapor Volumetric Flow [scf/d]‐29040.20 372.36 227.27 ‐9.95 API Gravity ‐‐‐‐ ‐63.42 Reid Vapor Pressure [psi]17.37 ‐‐‐ Total Emissions [ton/yr] [ton/yr] [ton/yr] [ton/yr] [ton/yr] [ton/yr] [ton/yr] ‐133.63 Stream Mass Flow [Total] Component Tank Inlet Flashing Losses Working Losses Standing Losses Loading Losses Residual Standard Liquid Volumetric Flow [bbl/d] 153.38 ‐‐‐ 0.06 2.47 Nitrogen 0.10 0.10 0.00 0.00 0.00 0.00 0.10 Carbon Dioxide 2.53 2.41 0.03 0.02 0.03 0.00 0.00Oxygen0.00 0.00 0.00 0.00 0.00 Methane 37.33 36.70 0.39 0.24 0.28 0.00 Propane 175.76 129.76 1.78 1.09 1.28 43.13 132.63 37.33 Ethane 65.65 59.30 0.84 0.52 0.61 4.98 60.66 41.22 48.98 n‐Butane 272.82 118.71 1.57 0.96 1.13 151.59 121.23 i‐Butane 90.20 47.95 0.64 0.39 0.46 0.91 0.55 i‐Pentane 228.84 54.18 0.70 0.43 0.50 173.54 55.30 Neopentane 1.46 0.54 0.01 0.00 0.01 297.43 70.78 2,2‐Dimethylbutane 6.53 0.79 0.01 0.01 0.01 5.72 0.80 n‐Pentane 368.21 69.36 0.88 0.54 0.63 59.53 6.22 2‐Methylpentane 229.00 19.84 0.25 0.15 0.18 208.76 20.24 2,3‐Dimethylbutane 65.76 6.10 0.08 0.05 0.05 108.85 9.37 n‐Hexane 497.52 31.84 0.39 0.24 0.28 465.06 32.46 3‐Methylpentane 118.23 9.19 0.11 0.07 0.08 0.00 0.00 Cyclohexane 162.63 7.73 0.09 0.06 0.07 154.75 7.88 Cyclopentane 0.00 0.00 0.00 0.00 0.00 1419.74 31.85 2,2,4‐Trimethylpentane 102.67 2.41 0.03 0.02 0.02 100.22 2.45 n‐Heptane 1451.59 31.26 0.37 0.23 0.27 408.48 9.41 Benzene 48.23 3.08 0.04 0.02 0.03 45.08 3.14 Methylcyclohexane 417.88 9.23 0.11 0.07 0.08 164.58 3.37 Ethylbenzene 61.16 0.39 0.00 0.00 0.00 60.76 0.40 Toluene 167.95 3.31 0.04 0.02 0.03 50.15 0.30 p‐Xylene 50.02 0.30 0.00 0.00 0.00 49.71 0.31 m‐Xylene 50.45 0.29 0.00 0.00 0.00 49.11 0.26 Octane 774.57 5.44 0.06 0.04 0.04 769.03 5.54 o‐Xylene 49.36 0.25 0.00 0.00 0.00 251.12 0.58 Decane 418.56 0.31 0.00 0.00 0.00 418.25 0.31 nC9 251.69 0.57 0.01 0.00 0.00 660.78 12.32 Hydrogen Sulfide 0.01 0.01 0.00 0.00 0.00 0.00 0.01 Water 673.10 12.10 0.14 0.08 0.10 0.00 0.00 TEG 0.00 0.00 0.00 0.00 0.00 0.00 0.00 EG 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Argon 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Methanol 0.00 0.00 0.00 0.00 0.00 [Mol%] [Mol%] [Mol%] [Mol%] [Mol%] [Mol%] Stream Compostion Component Tank Inlet Flashing Losses Working Losses Standing Losses Loading Losses Residual 0.00 Nitrogen 0.00 0.03 0.01 0.01 0.01 0.00 Carbon Dioxide 0.05 0.39 0.44 0.44 0.44 0.00 Component Tank Inlet Flashing Losses Working Losses Standing Losses Loading Losses Residual [Mass%] [Mass%] Oxygen 0.00 0.00 0.00 0.00 0.00 0.00Oxygen0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 0.00 0.02 0.00 0.00 0.00 0.00 0.00 Ethane 2.01 14.12 15.69 15.69 15.69 0.18 Methane 2.14 16.38 13.70 13.70 13.70 1.03 i‐Butane 1.43 5.91 6.16 6.16 6.16 0.75 Propane 3.66 21.07 22.59 22.59 22.59 2.76 Neopentane 0.02 0.05 0.06 0.06 0.06 0.01 n‐Butane 4.31 14.62 15.08 15.08 15.08 2.54 n‐Pentane 4.69 6.88 6.84 6.84 6.84 4.36 i‐Pentane 2.92 5.38 5.40 5.40 5.40 0.07 2,3‐Dimethylbutane 0.70 0.51 0.49 0.49 0.49 0.73 2,2‐Dimethylbutane 0.07 0.07 0.06 0.06 0.06 2.56 3‐Methylpentane 1.26 0.76 0.74 0.74 0.74 1.34 2‐Methylpentane 2.44 1.65 1.60 1.60 1.60 5.71 Cyclopentane 0.00 0.00 0.00 0.00 0.00 0.00 n‐Hexane 5.31 2.65 2.53 2.53 2.53 1.95 n‐Heptane 13.32 2.23 2.06 2.06 2.06 14.99 Cyclohexane 1.78 0.66 0.63 0.63 0.63 0.93 Methylcyclohexane 3.91 0.67 0.63 0.63 0.63 4.40 2,2,4‐Trimethylpentane 0.83 0.15 0.14 0.14 0.14 0.61 Toluene 1.68 0.26 0.24 0.24 0.24 1.89 Benzene 0.57 0.28 0.27 0.27 0.27 0.61 m‐Xylene 0.44 0.02 0.02 0.02 0.02 0.50 Ethylbenzene 0.53 0.03 0.02 0.02 0.02 0.50 o‐Xylene 0.43 0.02 0.02 0.02 0.02 0.49 p‐Xylene 0.43 0.02 0.02 0.02 0.02 7.12 nC9 1.80 0.03 0.03 0.03 0.03 2.07 Octane 6.23 0.34 0.30 0.30 0.30 3.11 Water 34.34 4.81 4.24 4.24 4.24 38.80 Decane 2.70 0.02 0.01 0.01 0.01 0.00 EG 0.00 0.00 0.00 0.00 0.00 0.00 Hydrogen Sulfide 0.00 0.00 0.00 0.00 0.00 0.00 Methanol 0.00 0.00 0.00 0.00 0.00 0.00 TEG 0.00 0.00 0.00 0.00 0.00 0.00 Methane 0.55 5.53 4.58 4.58 4.58 0.00 Argon 0.00 0.00 0.00 0.00 0.00 [Mass%] [Mass%] [Mass%] [Mass%] Carbon Dioxide 0.04 0.36 0.41 0.41 0.41 0.08 Propane 2.57 19.56 20.75 20.75 20.75 0.70 Ethane 0.96 8.94 9.83 9.83 9.83 0.67 n‐Butane 3.99 17.89 18.26 18.26 18.26 2.46 i‐Butane 1.32 7.23 7.46 7.46 7.46 0.01 i‐Pentane 3.35 8.17 8.12 8.12 8.12 2.82 Neopentane 0.02 0.08 0.08 0.08 0.08 4.83 2,2‐Dimethylbutane 0.10 0.12 0.12 0.12 0.12 0.09 n‐Pentane 5.38 10.45 10.28 10.28 10.28 0.97 2‐Methylpentane 3.35 2.99 2.87 2.87 2.87 3.39 2,3‐Dimethylbutane 0.96 0.92 0.89 0.89 0.89 1.77 n‐Hexane 7.27 4.80 4.54 4.54 4.54 7.55 3‐Methylpentane 1.73 1.39 1.32 1.32 1.32 0.00 Cyclohexane 2.38 1.16 1.10 1.10 1.10 2.51 Cyclopentane 0.00 0.00 0.00 0.00 0.00 23.04 2,2,4‐Trimethylpentane 1.50 0.36 0.34 0.34 0.34 1.63 n‐Heptane 21.22 4.71 4.31 4.31 4.31 6.63 Benzene 0.71 0.46 0.44 0.44 0.44 0.73 Methylcyclohexane 6.11 1.39 1.28 1.28 1.28 2.67 Ethylbenzene 0.89 0.06 0.05 0.05 0.05 0.99 Toluene 2.46 0.50 0.46 0.46 0.46 0.81 p‐Xylene 0.73 0.05 0.04 0.04 0.04 0.81 m‐Xylene 0.74 0.04 0.04 0.04 0.04 0.80 Octane 11.32 0.82 0.72 0.72 0.72 12.48 o‐Xylene 0.72 0.04 0.03 0.03 0.03 4.07 Decane 6.12 0.05 0.04 0.04 0.04 6.79 nC9 3.68 0.09 0.07 0.07 0.07 10.72 Hydrogen Sulfide 0.00 0.00 0.00 0.00 0.00 0.00 Water 9.84 1.82 1.59 1.59 1.59 0.00 TEG 0.00 0.00 0.00 0.00 0.00 0.00 EG 0.00 0.00 0.00 0.00 0.00 0.00 Argon 0.00 0.00 0.00 0.00 0.00 0.00 Methanol 0.00 0.00 0.00 0.00 0.00 4 Emissions TK_901/910/921C/931 Emission Summary Component Subset Tank Losses Flashing Losses Working Losses Standing Losses Loading Losses [ton/yr] [ton/yr] [ton/yr] HAPs 3.89 2.73 0.69 0.47 0.56 [ton/yr] [ton/yr] VOCs 53.51 36.96 9.83 6.72 8.00 H2S 0.00 0.00 0.00 0.00 0.00 BTEX 0.77 0.54 0.13 0.09 0.11 [ton/yr] [ton/yr] VOCs 13.38 9.24 2.46 1.68 2.00 Emission Summary [Per Tank] Component Subset Tank Losses Flashing Losses Working Losses Standing Losses Loading Losses [ton/yr] [ton/yr] [ton/yr] BTEX 0.19 0.14 0.03 0.02 0.03 HAPs 0.97 0.68 0.17 0.12 0.14 Stream Properties Tank Inlet Flashing Losses Working Losses Standing Losses Loading Losses Residual H2S 0.00 0.00 0.00 0.00 0.00 47.48 21.68 Net Ideal Gas Heating Value [BTU/scf]‐2084.88 2417.10 2417.10 2417.10 ‐ Molecular Weight [lb/lbmol]21.73 40.83 47.48 47.48 436.39 ‐ Specific Gravity ‐‐‐‐ ‐0.92 Standard Vapor Volumetric Flow [scf/d]‐2557.08 536.00 366.64 ‐7.58 API Gravity ‐‐‐‐ ‐22.00 Reid Vapor Pressure [psi]11.40 ‐‐‐ Total Emissions [ton/yr] [ton/yr] [ton/yr] [ton/yr] [ton/yr] [ton/yr] [ton/yr] ‐240.43 Stream Mass Flow [Total] Component Tank Inlet Flashing Losses Working Losses Standing Losses Loading Losses Residual Standard Liquid Volumetric Flow [bbl/d] 242.62 ‐‐‐ 0.09 0.51 Nitrogen 0.04 0.04 0.00 0.00 0.00 0.00 0.04 Carbon Dioxide 0.60 0.39 0.07 0.05 0.05 0.00 0.00Methanol 0.00 0.00 0.00 0.00 0.00 Methane 6.23 5.60 0.33 0.23 0.27 0.06 Propane 32.48 10.14 2.81 1.92 2.29 17.60 14.88 6.17 Ethane 10.46 6.31 1.80 1.23 1.47 1.11 9.35 15.86 4.60 n‐Butane 68.28 7.54 2.03 1.39 1.65 57.33 10.95 i‐Butane 20.46 3.16 0.86 0.59 0.70 0.36 0.05 i‐Pentane 69.20 3.20 0.84 0.58 0.69 64.58 4.62 Neopentane 0.41 0.03 0.01 0.01 0.01 108.88 5.77 2,2‐Dimethylbutane 2.26 0.05 0.01 0.01 0.01 2.19 0.07 n‐Pentane 114.65 4.01 1.05 0.72 0.85 43.33 0.81 2,3‐Dimethylbutane 24.06 0.37 0.10 0.07 0.08 23.52 0.54 3‐Methylpentane 44.14 0.57 0.14 0.10 0.12 82.64 1.74 n‐Hexane 195.70 2.02 0.51 0.35 0.42 192.82 2.88 2‐Methylpentane 84.38 1.22 0.31 0.21 0.25 0.00 0.00 Cyclohexane 55.03 0.41 0.10 0.07 0.08 54.45 0.58 Cyclopentane 0.00 0.00 0.00 0.00 0.00 692.08 3.26 2,2,4‐Trimethylpentane 46.95 0.17 0.04 0.03 0.03 46.71 0.24 n‐Heptane 695.34 2.30 0.57 0.39 0.46 150.40 0.74 Benzene 18.99 0.20 0.05 0.03 0.04 18.71 0.28 Methylcyclohexane 151.15 0.52 0.13 0.09 0.11 30.96 0.04 Toluene 80.55 0.24 0.06 0.04 0.05 80.21 0.34 Ethylbenzene 31.00 0.03 0.01 0.00 0.01 32.87 0.04 p‐Xylene 32.59 0.03 0.01 0.00 0.01 32.55 0.04 m‐Xylene 32.91 0.03 0.01 0.00 0.01 26.95 0.03 Octane 573.27 0.59 0.14 0.10 0.12 572.44 0.83 o‐Xylene 26.98 0.02 0.00 0.00 0.00 264.75 0.12 Decane 300.95 0.03 0.01 0.00 0.01 300.91 0.04 nC9 264.87 0.09 0.02 0.01 0.02 11226.94 1.25 Hydrogen Sulfide 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Water 11228.19 0.90 0.21 0.14 0.17 0.00 0.00 TEG 0.00 0.00 0.00 0.00 0.00 0.00 0.00 EG 0.00 0.00 0.00 0.00 0.00 [Mol%] [Mol%] [Mol%] [Mol%] [Mol%] [Mol%] Stream Compostion Component Tank Inlet Flashing Losses Working Losses Standing Losses Loading Losses Residual 0.00 Nitrogen 0.00 0.11 0.01 0.01 0.01 0.00 Carbon Dioxide 0.00 0.73 0.59 0.59 0.59 0.00 Component Tank Inlet Flashing Losses Working Losses Standing Losses Loading Losses Residual [Mass%] [Mass%] Methanol 0.00 0.00 0.00 0.00 0.00 0.00Methanol 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 0.00 0.08 0.01 0.01 0.01 0.00 0.00 Ethane 0.05 17.08 23.24 23.24 23.24 0.01 Methane 0.06 28.40 8.10 8.10 8.10 0.06 i‐Butane 0.05 4.42 5.72 5.72 5.72 0.04 Propane 0.11 18.70 24.76 24.76 24.76 0.15 Neopentane 0.00 0.04 0.05 0.05 0.05 0.00 n‐Butane 0.18 10.55 13.54 13.54 13.54 0.14 n‐Pentane 0.24 4.51 5.63 5.63 5.63 0.23 i‐Pentane 0.15 3.61 4.54 4.54 4.54 0.00 3‐Methylpentane 0.08 0.53 0.65 0.65 0.65 0.08 2,2‐Dimethylbutane 0.00 0.04 0.05 0.05 0.05 0.04 2‐Methylpentane 0.15 1.15 1.41 1.41 1.41 0.15 2,3‐Dimethylbutane 0.04 0.35 0.43 0.43 0.43 0.34 Cyclopentane 0.00 0.00 0.00 0.00 0.00 0.00 n‐Hexane 0.35 1.91 2.30 2.30 2.30 0.10 n‐Heptane 1.06 1.87 2.20 2.20 2.20 1.06 Cyclohexane 0.10 0.40 0.48 0.48 0.48 0.06 Methylcyclohexane 0.24 0.43 0.51 0.51 0.51 0.23 2,2,4‐Trimethylpentane 0.06 0.12 0.14 0.14 0.14 0.04 Ethylbenzene 0.04 0.02 0.03 0.03 0.03 0.04 Benzene 0.04 0.20 0.25 0.25 0.25 0.13 m‐Xylene 0.05 0.02 0.02 0.02 0.02 0.05 Toluene 0.13 0.21 0.25 0.25 0.25 0.05 o‐Xylene 0.04 0.02 0.02 0.02 0.02 0.04 p‐Xylene 0.05 0.02 0.03 0.03 0.03 0.77 nC9 0.32 0.05 0.06 0.06 0.06 0.32 Octane 0.77 0.42 0.48 0.48 0.48 0.32 Water 95.31 4.06 4.49 4.49 4.49 95.54 Decane 0.32 0.02 0.02 0.02 0.02 0.00 EG 0.00 0.00 0.00 0.00 0.00 0.00 Hydrogen Sulfide 0.00 0.00 0.00 0.00 0.00 0.00 Methane 0.04 11.16 2.74 2.74 2.74 0.00 TEG 0.00 0.00 0.00 0.00 0.00 [Mass%] [Mass%] [Mass%] [Mass%] Carbon Dioxide 0.00 0.79 0.54 0.54 0.54 0.01 Propane 0.23 20.20 22.99 22.99 22.99 0.12 Ethane 0.07 12.58 14.72 14.72 14.72 0.11 n‐Butane 0.48 15.01 16.58 16.58 16.58 0.41 i‐Butane 0.14 6.29 7.00 7.00 7.00 0.00 i‐Pentane 0.49 6.37 6.89 6.89 6.89 0.46 Neopentane 0.00 0.07 0.08 0.08 0.08 0.77 2,2‐Dimethylbutane 0.02 0.09 0.10 0.10 0.10 0.02 n‐Pentane 0.81 7.98 8.55 8.55 8.55 0.31 2,3‐Dimethylbutane 0.17 0.75 0.79 0.79 0.79 0.17 3‐Methylpentane 0.31 1.13 1.18 1.18 1.18 0.58 n‐Hexane 1.38 4.02 4.18 4.18 4.18 1.36 2‐Methylpentane 0.59 2.42 2.55 2.55 2.55 0.00 Cyclohexane 0.39 0.82 0.85 0.85 0.85 0.39 Cyclopentane 0.00 0.00 0.00 0.00 0.00 4.89 2,2,4‐Trimethylpentane 0.33 0.34 0.34 0.34 0.34 0.33 n‐Heptane 4.89 4.59 4.65 4.65 4.65 1.06 Benzene 0.13 0.39 0.41 0.41 0.41 0.13 Methylcyclohexane 1.06 1.04 1.06 1.06 1.06 0.22 Toluene 0.57 0.48 0.48 0.48 0.48 0.57 Ethylbenzene 0.22 0.06 0.06 0.06 0.06 0.23 p‐Xylene 0.23 0.06 0.06 0.06 0.06 0.23 m‐Xylene 0.23 0.06 0.05 0.05 0.05 0.19 Octane 4.03 1.18 1.17 1.17 1.17 4.05 o‐Xylene 0.19 0.04 0.04 0.04 0.04 1.87 Decane 2.12 0.06 0.06 0.06 0.06 2.13 nC9 1.86 0.17 0.16 0.16 0.16 79.39 Hydrogen Sulfide 0.00 0.00 0.00 0.00 0.00 0.00 Water 79.00 1.79 1.70 1.70 1.70 0.00 TEG 0.00 0.00 0.00 0.00 0.00 0.00 EG 0.00 0.00 0.00 0.00 0.00