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Home My WebLink AboutDAQ-2024-004691 DAQE-AN108840013-24 {{$d1 }} Jason Norlen Heber Light & Power Company 31 South 100 West Heber City, UT 84032 jnorlen@heberpower.com Dear Mr. Norlen: Re: Approval Order: Modification of Approval Order DAQE-AN108840012-22 to Update Equipment Project Number: N108840013 The attached Approval Order (AO) is issued pursuant to the Notice of Intent (NOI) received on January 4, 2023. Heber Light & Power Company must comply with the requirements of this AO, all applicable state requirements (R307), and Federal Standards. The project engineer for this action is Sarah Foran, who can be contacted at (385) 306-6724 or sforan@utah.gov. Future correspondence on this AO should include the engineer's name as well as the DAQE number shown on the upper right-hand corner of this letter. No public comments were received on this action. Sincerely, {{$s }} Bryce C. Bird Director BCB:SF:jg cc: Wasatch County Health Department 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 January 29, 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-AN108840013-24 Modification of Approval Order DAQE-AN108840012-22 to Update Equipment Prepared By Sarah Foran, Engineer (385) 306-6724 sforan@utah.gov Issued to Heber Light & Power Company - Power Plant Issued On {{$d2 }} Issued By {{$s }} Bryce C. Bird Director Division of Air Quality January 29, 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-AN108840013-24 Page 3 GENERAL INFORMATION CONTACT/LOCATION INFORMATION Owner Name Source Name Heber Light & Power Company Heber Light & Power Company - Power Plant Mailing Address Physical Address 31 South 100 West 735 West 300 South Heber City, UT 84032 Heber City, UT 84032 Source Contact UTM Coordinates Name: Jason Norlen 463,964 m Easting Phone: (435) 654-2913 4,483,733 m Northing Email: jnorlen@heberpower.com Datum NAD83 UTM Zone 12 SIC code 4911 (Electric Services) SOURCE INFORMATION General Description Heber Light & Power Company (Heber) operates an electricity generating facility at its Ray Farrell Internal Combustion Power Plant Site. The facility operates as an electric power peaking facility in Heber. The facility uses internal combustion natural gas and diesel fuel powered engines to power generators to produce electricity. The facility is generally operated during peak demand and emergency episodes. All power generated by the facility is sold to the existing power grid. Heber also generates energy through on-site research and development (R&D) engines. Combustion emissions are generated as a result of on-site operations. NSR Classification Minor Modification at Minor Source Source Classification Located in Attainment Area Wasatch County Airs Source Size: B Applicable Federal Standards NSPS (Part 60), A: General Provisions NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal Combustion Engines NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal Combustion Engines MACT (Part 63), A: General Provisions DAQE-AN108840013-24 Page 4 MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Project Description Heber has requested a modification to their AO for: 1. The addition of a new, 3,161 hp natural gas engine. 2. Update NOx and CO emissions as a result of engine operations and testing, requiring updated emission limits. 3. The removal of Engine Unit #6. 4. Updating engine sizing as follows: Unit #5; 1550 kW (previously 1620 kW), Unit #12; 2200 kW (previously 2150 kW). 5. Updating unit operational hours, including aggregating operational hours for engines with the same size and emission rate. Therefore, Units #4, #7, and #8 will have a combined total operational hour limit, and Units #12-14 will have a combined total operational limit. 6. Reducing the hours of operation for Engine #11 to 5,200 hours per year. 7. Subsequent PTE updates as a result of these changes. 8. Plant equipment reconfiguration and addition of SCRs to existing engines unit #12 and #13. 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 59659.00 Carbon Monoxide 19.28 25.43 Nitrogen Oxides -5.15 81.71 Particulate Matter - PM10 -0.52 2.69 Particulate Matter - PM2.5 -0.51 2.61 Sulfur Dioxide 0.04 0.41 Volatile Organic Compounds 0.74 28.88 Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr) Acetaldehyde (CAS #75070) 0 2800 Acrolein (CAS #107028) 0 1712 Formaldehyde (CAS #50000) 0 19140 Generic HAPs (CAS #GHAPS) 0 1112 Methanol (CAS #67561) 0 836 Change (TPY) Total (TPY) Total HAPs 0 12.80 DAQE-AN108840013-24 Page 5 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 two-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 two (2) 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 construction or modification 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] DAQE-AN108840013-24 Page 6 SECTION II: PERMITTED EQUIPMENT II.A THE APPROVED EQUIPMENT II.A.1 Plant Wide Power Plant II.A.2 One (1) Engine Generator Unit #1 Location: Bay #6 Maximum Rating: 1350 kW Fuel: Natural-gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.3 One (1) Engine Generator Unit #2 Location: Bay #9 Maximum Rating: 1350 kW Fuel: Natural gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.4 One (1) Engine Generator Unit #4 Location: Bay #10 Maximum Rating: 1850 kW Fuel: Natural gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.5 One (1) Engine Generator (NEW) Unit #5 Location: Bay #5 Maximum Rating: 1550 kW Fuel: Natural gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.6 One (1) Engine Generator Unit #7 Location: Bay #7 Maximum Rating: 1850 kW Fuel: Natural gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ DAQE-AN108840013-24 Page 7 II.A.7 One (1) Engine Generator Unit #8 Location: Bay #8 Maximum Rating: 1850 kW Fuel type: Natural gas CO Emissions control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.8 One (1) Engine Generator Unit #11 3516H Location: Bay #11 Maximum Rating: 1750 kW Fuel: Natural gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.9 One (1) Engine Generator Unit #12 3520H Location: Bay #12 Maximum Rating: 2200 kW Fuel: Natural gas Control: Oxidation catalyst, and SCR NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.10 One (1) Engine Generator (NEW) Unit #13 3520DSL Location: Bay #13 Maximum Rating: 2631 kW Fuel: Natural gas Control: Oxidation catalyst and SCR NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.11 One (1) Engine Generator (NEW) Unit #14 Location: Bay #14 Maximum Rating: 2550 kW Fuel: Natural gas Control: Oxidation catalyst, and SCR NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.12 Research and Development Engines Various Diesel and Natural Gas Engines DAQE-AN108840013-24 Page 8 II.A.13 Two (2) Backup Emergency Generators 1. Maximum Rating: 60 kW Fuel: Diesel 2. Maximum Rating: 80 kW Fuel: Diesel NSPS Applicability: Subpart IIII MACT Applicability: Subpart ZZZZ II.A.14 Various Portable Engines Maximum rating: 50 kW each Included for informational purposes SECTION II: SPECIAL PROVISIONS II.B REQUIREMENTS AND LIMITATIONS II.B.1 Limitation and Test Procedures II.B.1.a The owner/operator shall not allow visible emissions from the following emission points shall not exceed the following values: A. All diesel fired engines - 20% opacity B. All-natural gas fired engines - 10% opacity. [R307-201, R307-401-8] II.B.1.a.1 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 owner/operator shall not exceed the following operational hours per rolling 12-month period, from each unit as designated below: Unit #1, and #2: 4,000 hours combined Unit #4, #7, and #8: 7,800 hours combined Unit #5: 5,200 hours Unit #11: 5,200 hours Units #12,#13. #14: 15,600 hours combined R&D NG Engines: 8,000 hours combined Diesel R&D: 5,000 hours combined. "combined" refers to the sum of hours amongst all units within an engine group, as listed above. [R307-401-8] DAQE-AN108840013-24 Page 9 II.B.1.c The owner/operator shall maintain a log recording each unit's operational hours. The log shall include the unit's name and hours operated per month. The owner/operator shall calculate a new 12-month total by the 20th day of each month using data from the previous 12 months. [R307-401-8] II.B.1.d There shall not be more than six (6) R&D generators installed at the Heber Power Plant site. A report shall be submitted to DAQ before the engine generators are installed. The report shall include the manufactures expected emission levels, the expected hours of operation and the length of time that the engines will be operating. The following conditions shall apply to the R&D engine generators: A. The engine generators shall have not been manufactured more than 24-months prior to installation B. An engine generator shall not exceed 24-months of operation. [R307-401-8] II.B.1.d.1 A report describing the results of the test operations of each engine generator tested shall be submitted to the Director, attention New Source Review Section, within 45 days after the engine generator has finished operating. The report, at a minimum, shall include the hp and kW rating, power produced, pollution control equipment used on the engine generator, total hours of operation on the engine, the power produced, NOx and CO emissions measured, and a summary of the emissions testing results along with calculated factors. [R307-401-8] II.B.1.e The owner/operator shall ensure that each engine listed under II.A.2 - II.A.12 vents exhaust gases vertically unrestricted with an attached stack height of no less than 53' feet. All stacks shall be installed within 18-months of the issuance of this AO and comply with condition I.8 of this AO. [R307-401-8, R307-410-4] DAQE-AN108840013-24 Page 10 II.B.2 Stack Testing Requirements I.B.2.a The owner/operator shall not emit more than the following rates and concentrations from the following units: Location Pollutant lb/hr Unit #1 NOx 4.06 CO 1.0 Unit #2 NOx 4.06 CO 1.0 Unit #4 NOx 5.35 CO 1.0 Unit #5 NOx 3.00 CO 1.0 Unit #7 NOx 5.35 CO 1.0 Unit #8 NOx 5.35 CO 1.0 NG R&D Units (Each) NOx 5.50 CO 1.0 Diesel R&D NOx 2.5 CO 1.0 Unit #11 3516H NOx 4.75 CO 1.0 Unit #12 3520H NOx 0.54 CO 1.0 Unit #13 3520DSL NOx 0.54 CO 1.0 Unit #14 NOx 0.54 CO 1.0 [R307-401-8] DAQE-AN108840013-24 Page 11 II.B.2.a.1 Compliance Demonstration To demonstrate compliance with the emission limitations above, the owner/operator shall perform stack testing on the emissions unit according to the stack testing conditions contained in this AO. [R307-165-2, R307-401-8] II.B.2.b The owner/operator shall conduct any stack testing required by this AO according to the following conditions. [R307-401-8] II.B.2.b.1 Notification At least 30 days prior to conducting a stack test, the owner/operator shall submit a source test protocol to the Director. The source test protocol shall include the items contained in R307-165-3. If directed by the Director, the owner/operator shall attend a pretest conference. [R307-165-3, R307-401-8] II.B.2.b.2 Test Frequency The owner/operator shall conduct a stack test on each emission unit within whichever of the following parameters occurs first; three (3) years or 8,760 hours of unit operation after the date of the most recent stack test of each listed emission unit. The Director may require the owner/operator to perform a stack test at any time. [R307-165-2, R307-401-8] II.B.2.b.3 Initial Test The owner/operator shall conduct an initial stack test on Unit #14 within 180 days after startup of each emission unit. [R307-165-2] II.B.2.b.4 Testing & Test Conditions The owner/operator shall conduct testing according to the approved source test protocol and according to the test conditions contained in R307-165-4. [R307-165-4, R307-401-8] II.B.2.b.5 Reporting No later than 60 days after completing a stack test, the owner/operator shall submit a written report of the results from the stack testing to the Director. The report shall include validated results and supporting information. [R307-165-5, R307-401-8] II.B.2.c Test Methods When performing stack testing, the owner/operator shall use the appropriate EPA-approved test methods as acceptable to the Director. Acceptable test methods for pollutants are listed below. [R307-401-8] II.B.2.c.1 Standard Conditions A. Temperature - 68 degrees Fahrenheit (293 K) B. Pressure - 29.92 in Hg (101.3 kPa) C. Averaging Time - As specified in the applicable test method. [40 CFR 60 Subpart A, 40 CFR 63 Subpart A, R307-401-8] II.B.2.c.2 NOx 40 CFR 60, Appendix A, Method 7; Method 7E; or other EPA-approved testing method as acceptable to the Director. [R307-401-8] II.B.2.c.3 CO 40 CFR 60, Appendix A, Method 10 or other EPA-approved testing method as acceptable to the Director. [R307-401-8] DAQE-AN108840013-24 Page 12 II.B.3 Monitoring II.B.3.a The owner/operator shall install, calibrate, maintain, and operate a monitoring device for the continuous measurement of the temperature of each oxidation catalyst. The monitoring device shall be accurate within plus or minus 25 degrees Fahrenheit. The temperature shall not exceed 1300 degrees Fahrenheit. Continuous recording for the monitoring device is not required. However, daily records of readings shall be maintained. [R307-401-8] II.B.4 Emergency Engine Requirements II.B.4.a The owner/operator shall not operate each emergency engine on site for more than 100 hours per rolling 12-month period during non-emergency situations. There is no time limit on the use of the engines during emergencies. [R307-401-8, 40 CFR 63 Subpart ZZZZ] II.B.4.a.1 To determine compliance with a rolling 12-month total, the owner/operator shall calculate a new 12-month total by the 20th day of each month using data from the previous 12 months. Records documenting the operation of each emergency engine shall be kept in a log and shall include the following: a. The date the emergency engine was used b. The duration of operation in hours c. The reason for the emergency engine usage. [R307-401-8, 40 CFR 63 Subpart ZZZZ] II.B.4.b The owner/operator shall only use diesel fuel (e.g. fuel oil #1, #2, or diesel fuel oil additives) as fuel in each emergency engine. [R307-401-8] II.B.4.b.1 The owner/operator shall only combust diesel fuel that meets the definition of ultra-low sulfur diesel (ULSD), which has a sulfur content of 15 ppm or less. [R307-401-8] II.B.4.b.2 To demonstrate compliance with the ULSD fuel requirement, the owner/operator shall maintain records of diesel fuel purchase invoices or obtain certification of sulfur content from the diesel fuel supplier. The diesel fuel purchase invoices shall indicate that the diesel fuel meets the ULSD requirements. [R307-401-8] PERMIT HISTORY This Approval Order shall supersede (if a modification) or will be based on the following documents. Supersedes AO DAQE-AN108840012-22 dated June 6, 2022 Is Derived From Notice of Intent dated January 4, 2023 Incorporates Additional Information dated September 22, 2023 DAQE-AN108840013-24 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-IN108840013-23 December 11, 2023 Jason Norlen Heber Light & Power Company 31 South 100 West Heber City, UT 84032 jnorlen@heberpower.com Dear Mr. Norlen: Re: Intent to Approve: Modification of Approval Order DAQE-AN108840012-22 to Update Equipment Project Number: N108840013 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, Sarah Foran, as well as the DAQE number as shown on the upper right-hand corner of this letter. Sarah Foran, can be reached at (385) 306-6724 or sforan@utah.gov, if you have any questions. Sincerely, {{$s }} Jon L. Black, Manager New Source Review Section JLB:SF:jg cc: Wasatch County Health Department 195 North 1950 West • Salt Lake City, UT Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820 Telephone (801) 536-4000 • Fax (801) 536-4099 • T.D.D. (801) 536-4414 www.deq.utah.gov Printed on 100% recycled paper State of Utah SPENCER J. COX Governor DEIDRE HENDERSON Lieutenant Governor Department of Environmental Quality Kimberly D. Shelley Executive Director DIVISION OF AIR QUALITY Bryce C. Bird Director * ) ' & — F v A ? A B @ H w @ E ˜ STATE OF UTAH Department of Environmental Quality Division of Air Quality INTENT TO APPROVE DAQE-IN108840013-23 Modification of Approval Order DAQE-AN108840012-22 to Update Equipment Prepared By Sarah Foran, Engineer (385) 306-6724 sforan@utah.gov Issued to Heber Light & Power Company - Power Plant Issued On December 11, 2023 {{$s }} New Source Review Section Manager Jon L. Black {{#s=Sig_es_:signer1:signature}} * ) ' & — F v A ? A B @ H w @ E ˜ 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............................................................................................... 4 SECTION I: GENERAL PROVISIONS .................................................................................... 5 SECTION II: PERMITTED EQUIPMENT .............................................................................. 6 SECTION II: SPECIAL PROVISIONS ..................................................................................... 8 PERMIT HISTORY ................................................................................................................... 12 ACRONYMS ............................................................................................................................... 13 DAQE-IN108840013-23 Page 3 GENERAL INFORMATION CONTACT/LOCATION INFORMATION Owner Name Source Name Heber Light & Power Company Heber Light & Power Company - Power Plant Mailing Address Physical Address 31 South 100 West 735 West 300 South Heber City, UT 84032 Heber City, UT 84032 Source Contact UTM Coordinates Name Jason Norlen 463,964 m Easting Phone (435) 654-2913 4,483,733 m Northing Email jnorlen@heberpower.com Datum NAD83 UTM Zone 12 SIC code 4911 (Electric Services) SOURCE INFORMATION General Description Heber Light & Power Company (Heber) operates an electricity generating facility at its Ray Farrell Internal Combustion Power Plant Site. The facility operates as an electric power peaking facility in Heber. The facility uses internal combustion natural gas and diesel fuel powered engines to power generators to produce electricity. The facility is generally operated during peak demand and emergency episodes. All power generated by the facility is sold to the existing power grid. Heber also generates energy through on-site research and development (R&D) engines. Combustion emissions are generated as a result of on-site operations. NSR Classification Minor Modification at Minor Source Source Classification Located in Attainment Area Wasatch County Airs Source Size: B Applicable Federal Standards NSPS (Part 60), A: General Provisions NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal Combustion Engines NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal Combustion Engines MACT (Part 63), A: General Provisions MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines DAQE-IN108840013-23 Page 4 Project Description Heber has requested a modification to their AO for: 1. The addition of a new, 3,161 hp natural gas engine 2. Update NOx and CO emissions as a result of engine operations and testing, requiring updated emission limits 3. The removal of Engine Unit #6 4. Updating engine sizing as follows: Unit #5; 1550 kW (previously 1620 kW), Unit #12; 2200 kW (previously 2150 kW). 5. Updating unit operational hours, including aggregating operational hours for engines with the same size and emission rate. Therefore, Units #4, #7, and #8 will have a combined total operational hour limit, and Units #12-14 will have a combined total operational limit. 6. Reducing the hours of operation for Engine #11 to 5,200 hours per year. 7. Subsequent PTE updates as a result of these changes 8. Plant equipment reconfiguration and addition of SCRs to existing engines unit #12 and #13 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 59659.00 Carbon Monoxide 19.28 25.43 Nitrogen Oxides -5.15 81.71 Particulate Matter - PM10 -0.52 2.69 Particulate Matter - PM2.5 -0.51 2.61 Sulfur Dioxide 0.04 0.41 Volatile Organic Compounds 0.74 28.88 Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr) Acetaldehyde (CAS #75070) 0 2800 Acrolein (CAS #107028) 0 1712 Formaldehyde (CAS #50000) 0 19140 Generic HAPs (CAS #GHAPS) 0 1112 Methanol (CAS #67561) 0 836 Change (TPY) Total (TPY) Total HAPs 0 12.80 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 Wasatch Wave on December 13, 2023. During the public comment period the proposal and the evaluation of its impact on air quality will be available for the DAQE-IN108840013-23 Page 5 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] 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 two-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 two (2) 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 construction or modification 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] DAQE-IN108840013-23 Page 6 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 Plant Wide Power Plant II.A.2 One Engine Generator Unit #1 Location: Bay #6 Maximum Rating: 1350 kW Fuel: Natural-gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.3 One Engine Generator Unit #2 Location: Bay #9 Maximum Rating: 1350 kW Fuel: Natural gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.4 One Engine Generator Unit #4 Location: Bay #10 Maximum Rating: 1850 kW Fuel: Natural gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.5 One Engine Generator (NEW) Unit #5 Location: Bay #5 Maximum Rating: 1550 kW Fuel: Natural gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.6 One Engine Generator Unit #7 Location: Bay #7 Maximum Rating: 1850 kW Fuel: Natural gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ DAQE-IN108840013-23 Page 7 II.A.7 One Engine Generator Unit #8 Location: Bay #8 Maximum Rating: 1850 kW Fuel type: Natural gas CO Emissions control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.8 One Engine Generator Unit #11 3516H Location: Bay #11 Maximum Rating: 1750 kW Fuel: Natural gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.9 One Engine Generator Unit #12 3520H Location: Bay #12 Maximum Rating: 2200 kW Fuel: Natural gas Control: Oxidation catalyst, and SCR NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.10 One Engine Generator (NEW) Unit #13 3520DSL Location: Bay #13 Maximum Rating: 2631 kW Fuel: Natural gas Control: Oxidation catalyst and SCR NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.11 One Engine Generator (NEW) Unit #14 Location: Bay #14 Maximum Rating: 2550 kW Fuel: Natural gas Control: Oxidation catalyst, and SCR NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.12 Research and Development Engines Various Diesel and Natural Gas Engines II.A.13 Two Backup Emergency Generators 1. Maximum Rating: 60 kW Fuel: Diesel 2. Maximum Rating: 80 kW Fuel: Diesel NSPS Applicability: Subpart IIII MACT Applicability: Subpart ZZZZ DAQE-IN108840013-23 Page 8 II.A.14 Various Portable Engines Maximum rating: 50 kW each Included for informational purposes 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 Limitation and Test Procedures II.B.1.a The owner/operator shall not allow visible emissions from the following emission points shall not exceed the following values: A. All diesel fired engines - 20% opacity B. All-natural gas fired engines - 10% opacity. [R307-201, R307-401-8] II.B.1.a.1 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 owner/operator shall not exceed the following operational hours per rolling 12-month period, from each unit as designated below: Unit #1, and #2: 4,000 hours combined Unit #4, #7, and #8: 7,800 hours combined Unit #5: 5,200 hours Unit #11: 5,200 hours Units #12,#13. #14: 15,600 hours combined R&D NG Engines: 8,000 hours combined Diesel R&D: 5,000 hours combined "combined" refers to the sum of hours amongst all units within an engine group, as listed above. [R307-401-8] II.B.1.c The owner/operator shall maintain a log recording each unit's operational hours. The log shall include the unit's name and hours operated per month. The owner/operator shall calculate a new 12-month total by the 20th day of each month using data from the previous 12 months. [R307-401-8] DAQE-IN108840013-23 Page 9 II.B.1.d There shall not be more than six (6) R&D generators installed at the Heber Power Plant site. A report shall be submitted to DAQ before the engine generators are installed. The report shall include the manufactures expected emission levels, the expected hours of operation and the length of time that the engines will be operating. The following conditions shall apply to the R&D engine generators: A. The engine generators shall have not been manufactured more than 24-months prior to installation B. An engine generator shall not exceed 24-months of operation. [R307-401-8] II.B.1.d.1 A report describing the results of the test operations of each engine generator tested shall be submitted to the Director, attention New Source Review Section, within 45 days after the engine generator has finished operating. The report, at a minimum, shall include the hp and kW rating, power produced, pollution control equipment used on the engine generator, total hours of operation on the engine, the power produced, NOx and CO emissions measured, and a summary of the emissions testing results along with calculated factors. [R307-401-8] II.B.1.e The owner/operator shall ensure that each engine listed under II.A.2 - II.A.12 vents exhaust gases vertically unrestricted with an attached stack height of no less than 53' feet. All stacks shall be installed within 18-months of the issuance of this AO and comply with condition I.8 of this AO. [R307-401-8, R307-410-4] DAQE-IN108840013-23 Page 10 II.B.2 Stack Testing Requirements II.B.2.a The owner/operator shall not emit more than the following rates and concentrations from the following units: Location Pollutant lb/hr Unit #1 NOx 4.06 CO 1.0 Unit #2 NOx 4.06 CO 1.0 Unit #4 NOx 5.35 CO 1.0 Unit #5 NOx 3.00 CO 1.0 Unit #7 NOx 5.35 CO 1.0 Unit #8 NOx 5.35 CO 1.0 NG R&D Units (Each) NOx 5.50 CO 1.0 Diesel R&D NOx 2.5 CO 1.0 Unit #11 3516H NOx 4.75 CO 1.0 Unit #12 3520H NOx 0.54 CO 1.0 Unit #13 3520DSL NOx 0.54 CO 1.0 Unit #14 NOx 0.54 CO 1.0 [R307-401-8] DAQE-IN108840013-23 Page 11 II.B.2.a.1 Compliance Demonstration To demonstrate compliance with the emission limitations above, the owner/operator shall perform stack testing on the emissions unit according to the stack testing conditions contained in this AO. [R307-165-2, R307-401-8] II.B.2.b The owner/operator shall conduct any stack testing required by this AO according to the following conditions. [R307-401-8] II.B.2.b.1 Notification At least 30 days prior to conducting a stack test, the owner/operator shall submit a source test protocol to the Director. The source test protocol shall include the items contained in R307-165-3. If directed by the Director, the owner/operator shall attend a pretest conference. [R307-165-3, R307-401-8] II.B.2.b.2 Test Frequency The owner/operator shall conduct a stack test on each emission unit within whichever of the following parameters occurs first; 3 years or 8,760 hours of unit operation after the date of the most recent stack test of each listed emission unit. The Director may require the owner/operator to perform a stack test at any time. [R307-165-2, R307-401-8] II.B.2.b.3 Initial Test The owner/operator shall conduct an initial stack test on Unit #14 within 180 days after startup of each emission unit. [R307-165-2] II.B.2.b.4 Testing & Test Conditions The owner/operator shall conduct testing according to the approved source test protocol and according to the test conditions contained in R307-165-4. [R307-165-4, R307-401-8] II.B.2.b.5 Reporting No later than 60 days after completing a stack test, the owner/operator shall submit a written report of the results from the stack testing to the Director. The report shall include validated results and supporting information. [R307-165-5, R307-401-8] II.B.2.c Test Methods When performing stack testing, the owner/operator shall use the appropriate EPA-approved test methods as acceptable to the Director. Acceptable test methods for pollutants are listed below. [R307-401-8] II.B.2.c.1 Standard Conditions A. Temperature - 68 degrees Fahrenheit (293 K) B. Pressure - 29.92 in Hg (101.3 kPa) C. Averaging Time - As specified in the applicable test method. [40 CFR 60 Subpart A, 40 CFR 63 Subpart A, R307-401-8] II.B.2.c.2 NOx 40 CFR 60, Appendix A, Method 7; Method 7E; or other EPA-approved testing method as acceptable to the Director. [R307-401-8] II.B.2.c.3 CO 40 CFR 60, Appendix A, Method 10 or other EPA-approved testing method as acceptable to the Director. [R307-401-8] DAQE-IN108840013-23 Page 12 II.B.3 Monitoring II.B.3.a The owner/operator shall install, calibrate, maintain, and operate a monitoring device for the continuous measurement of the temperature of each oxidation catalyst. The monitoring device shall be accurate within plus or minus 25 degrees Fahrenheit. The temperature shall not exceed 1300 degrees Fahrenheit. Continuous recording for the monitoring device is not required. However, daily records of readings shall be maintained. [R307-401-8] II.B.4 Emergency Engine Requirements II.B.4.a The owner/operator shall not operate each emergency engine on site for more than 100 hours per rolling 12-month period during non-emergency situations. There is no time limit on the use of the engines during emergencies. [R307-401-8, 40 CFR 63 Subpart ZZZZ] II.B.4.a.1 To determine compliance with a rolling 12-month total, the owner/operator shall calculate a new 12-month total by the 20th day of each month using data from the previous 12 months. Records documenting the operation of each emergency engine shall be kept in a log and shall include the following: a. The date the emergency engine was used b. The duration of operation in hours c. The reason for the emergency engine usage. [R307-401-8, 40 CFR 63 Subpart ZZZZ] II.B.4.b The owner/operator shall only use diesel fuel (e.g. fuel oil #1, #2, or diesel fuel oil additives) as fuel in each emergency engine. [R307-401-8] II.B.4.b.1 The owner/operator shall only combust diesel fuel that meets the definition of ultra-low sulfur diesel (ULSD), which has a sulfur content of 15 ppm or less. [R307-401-8] II.B.4.b.2 To demonstrate compliance with the ULSD fuel requirement, the owner/operator shall maintain records of diesel fuel purchase invoices or obtain certification of sulfur content from the diesel fuel supplier. The diesel fuel purchase invoices shall indicate that the diesel fuel meets the ULSD requirements. [R307-401-8] PERMIT HISTORY This Approval Order shall supersede (if a modification) or will be based on the following documents: Supersedes AO DAQE-AN108840012-22 dated June 6, 2022 Is Derived From Notice of Intent dated January 4, 2023 DAQE-IN108840013-23 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 12/11/23, 11:08 AM State of Utah Mail - Legal Notice to be published December 13, 2023 https://mail.google.com/mail/u/0/?ik=b4fd0e1085&view=pt&search=all&permmsgid=msg-f:1785009627510117353&simpl=msg-f:1785009627510117353 1/1 Jeree Greenwood <jereeg@utah.gov> Legal Notice to be published December 13, 2023 Laurie B Wynn <editor@wasatchwave.com>Mon, Dec 11, 2023 at 11:04 AM To: Jeree Greenwood <jereeg@utah.gov> Got it L Laurie B Wynn, Co-Publisher The Wasatch Wave & Summit County News 165 S 100 W Heber City, UT 84032 Phone: (435)654-1471 “There are so many joys to hold, and behold, in this wonderful, rotten world.” -Norm Fuellenbach [Quoted text hidden] [Quoted text hidden] <DAQE-NN108840013-23.pdf> DAQE-NN108840013-23 December 11, 2023 Wasatch Wave Legal Advertising Dept. P.O. Box 128 Heber City, UT 84032 RE: Legal Notice of Intent to Approve This letter will confirm the authorization to publish the attached NOTICE in the Wasatch Wave on December 13, 2023. 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: Wasatch County cc: Mountainland Association of Governments 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-NN108840013-23 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: Heber Light & Power Company Location: Heber Light & Power Company - Power Plant – 735 West 300 South, Heber City, UT Project Description: Heber Light & Power Company (Heber) operates an electricity generating facility at its Ray Farrell Internal Combustion Power Plant Site. The facility uses internal combustion natural gas and diesel fuel-powered engines to power generators to produce electricity. Heber has requested a modification to their Approval Order for the addition of a new natural-gas-fired engine, the replacement of an existing engine, and the removal of diesel storage tanks. 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 January 12, 2024 will be considered in making the final decision on the approval/disapproval of the proposed project. Email comments will also be accepted at sforan@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: December 13, 2023 {{#s=Sig_es_:signer1:signature}} DAQE- RN108840013 November 29, 2023 Jason Norlen Heber Light & Power Company 31 South 100 West Heber City, UT 84032 jnorlen@heberpower.com Dear Jason Norlen, Re: Engineer Review: Modification of AO DAQE-AN108840012-22 to Update Equipment Project Number: N108840013 The DAQ requests a company representative review and sign the attached Engineer Review (ER). This ER identifies all applicable elements of the New Source Review permitting program. Heber Light & Power Company should complete this review within 10 business days of receipt. Heber Light & Power Company should contact Sarah Foran at (385) 306-6724 if there are questions or concerns with the review of the draft permit conditions. Upon resolution of your concerns, please email Sarah Foran at sforan@utah.gov the signed cover letter. Upon receipt of the signed cover letter, the DAQ will prepare an ITA for a 30-day public comment period. At the completion of the comment period, the DAQ will address any comments and will prepare an Approval Order (AO) for signature by the DAQ Director. If Heber Light & Power Company does not respond to this letter within 10 business days, the project will move forward without source concurrence. If Heber Light & Power Company has concerns that cannot be resolved and the project becomes stagnant, 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 N108840013: Heber Light & Power Company- Power Plant November 29, 2023 Page 1 UTAH DIVISION OF AIR QUALITY ENGINEER REVIEW SOURCE INFORMATION Project Number N108840013 Owner Name Heber Light & Power Company Mailing Address 31 South 100 West Heber City, UT, 84032 Source Name Heber Light & Power Company- Power Plant Source Location 735 West 300 South Heber City, UT 84032 UTM Projection 463,964 m Easting, 4,483,733 m Northing UTM Datum NAD83 UTM Zone UTM Zone 12 SIC Code 4911 (Electric Services) Source Contact Jason Norlen Phone Number (435) 654-2913 Email jnorlen@heberpower.com Billing Contact Jason Norlen Phone Number 4356542913 Email jnorlen@heberpower.com Project Engineer Sarah Foran, Engineer Phone Number (385) 306-6724 Email sforan@utah.gov Notice of Intent (NOI) Submitted January 5, 2023 Date of Accepted Application May 22, 2023 Engineer Review N108840013: Heber Light & Power Company- Power Plant November 29, 2023 Page 2 SOURCE DESCRIPTION General Description Heber Light & Power Company (Heber) operates an electricity generating facility at its Ray Farrell Internal Combustion Power Plant Site. The facility operates as an electric power peaking facility in Heber. The facility uses internal combustion natural gas and diesel fuel powered engines to power generators to produce electricity. The facility is generally operated during peak demand and emergency episodes. All power generated by the facility is sold to the existing power grid. Heber also generates energy through on-site research and development (R&D) engines. Combustion emissions are generated as a result of on-site operations. NSR Classification: Minor Modification at Minor Source Source Classification Located in Attainment Area, Wasatch County Airs Source Size: B Applicable Federal Standards NSPS (Part 60), A: General Provisions NSPS (Part 60), IIII: Standards of Performance for Stationary Compression Ignition Internal Combustion Engines NSPS (Part 60), JJJJ: Standards of Performance for Stationary Spark Ignition Internal Combustion Engines MACT (Part 63), A: General Provisions MACT (Part 63), ZZZZ: National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Project Proposal Modification of AO DAQE-AN108840012-22 to Update Equipment Project Description Heber has requested a modification to their AO for: 1. The addition of a new, 3,161 hp natural gas engine 2. Update NOx and CO emissions as a result of engine operations and testing, requiring updated emission limits 3. The removal of Engine Unit #6 4. Updating engine sizing as follows: Unit #5; 1550 kW (previously 1620 kW), Unit #12; 2200 kW (previously 2150 kW). 5. Updating unit operational hours, including aggregating operational hours for engines with the same size and emission rate. Therefore, Units #4, #7, and #8 will have a combined total operational hour limit, and Units #12-14 will have a combined total operational limit. 6. Reducing the hours of operation for Engine #11 to 5,200 hours per year. 7. Subsequent PTE updates as a result of these changes 8. Plant equipment reconfiguration and addition of SCRs to existing engines unit #12 and #13 Engineer Review N108840013: Heber Light & Power Company- Power Plant November 29, 2023 Page 3 EMISSION IMPACT ANALYSIS NOx modeling was conducted for the facility. As a result of the model, each engine must vent exhaust gases vertically unrestricted with an attached stack height of no less than 53 feet. This requirement is noted in condition II.B.1.e. [Last updated May 16, 2023] Engineer Review N108840013: Heber Light & Power Company- Power Plant November 29, 2023 Page 4 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 59659.00 Carbon Monoxide 19.28 25.43 Nitrogen Oxides -5.15 81.71 Particulate Matter - PM10 -0.52 2.69 Particulate Matter - PM2.5 -0.51 2.61 Sulfur Dioxide 0.04 0.41 Volatile Organic Compounds 0.74 28.88 Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr) Acetaldehyde (CAS #75070) 0 2800 Acrolein (CAS #107028) 0 1712 Formaldehyde (CAS #50000) 0 19140 Generic HAPs (CAS #GHAPS) 0 1112 Methanol (CAS #67561) 0 836 Change (TPY) Total (TPY) Total HAPs 0 12.80 Note: Change in emissions indicates the difference between previous AO and proposed modification. Engineer Review N108840013: Heber Light & Power Company- Power Plant November 29, 2023 Page 5 Review of BACT for New/Modified Emission Units 1. BACT review regarding New Engine and increased hours The addition of Unit #14, the increase in operation hours and higher emissions rates for CO and NOx, will result in a potential increase in emissions of criteria pollutants. PM10 and PM2.5 emissions from natural gas combustion occur from noncombustible constituents in the fuel. The EPA RACT/BACT/LAER Clearinghouse (RBLC) database lists good operation practices and the use of pipeline quality natural gas as the primary control technologies for natural- gas-fired generators of similar size. SO2 emissions from natural gas combustion result from the sulfur content of the natural gas burned during combustion. The RBLC database lists the use of low-sulfur natural gas as the primary control technology for natural-gas-fired generators. CO and VOC emissions from natural gas combustion are a result of incomplete combustion of the fuel. The RBLC database lists CO lb/hr limitations, good combustion practices and oxidation catalysts as the primary control technologies for natural-gas-fired turbines. BACT for the new and updated engines is compliance with the proposed 1.0 lb/hr CO emission rate (0.143 g/hp-hr). NOx emissions are generated from natural gas combustion. Potential add-on controls for NOx reduction include low NOx combustion technology and selective catalytic reduction (SCR) as the primary control technologies for natural-gas-fired generators. The source selected a SCR to control NOx emissions from the new engine. SCR was additionally selected by the source for engines unit #12, #13, and #14. No cost analysis was done prior to voluntarily selecting SCR as control for these engines. SCRs are the top control option for NOx. Regardless of controls selected, all stationary spark ignition engines must comply with 40 CFR 60 Subpart JJJJ. The use of natural gas as a fuel, low NOx combustion technology by design, catalytic oxidizers and good combustion practices for the remaining generators are accepted as BACT. [Last updated November 29, 2023] 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] Engineer Review N108840013: Heber Light & Power Company- Power Plant November 29, 2023 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 two-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 two (2) 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 construction or modification 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 Plant Wide Power Plant II.A.2 One Engine Generator Unit #1 Location: Bay #6 Maximum Rating: 1350 kW Fuel: Natural-gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ Engineer Review N108840013: Heber Light & Power Company- Power Plant November 29, 2023 Page 7 II.A.3 One Engine Generator Unit #2 Location: Bay #69 Maximum Rating: 1350 kW Fuel: Natural gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.4 One Engine Generator Unit #4 Location: Bay #10 Maximum Rating: 1850 kW Fuel: Natural gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.5 One Engine Generator (NEW) Unit #5 Location: Bay #5 Maximum Rating: 1550 kW Fuel: Natural gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.6 One Engine Generator Unit #7 Location: Bay #7 Maximum Rating: 1850 kW Fuel: Natural gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.7 One Engine Generator Unit #8 Location: Bay #8 Maximum Rating: 1850 kW Fuel type: Natural gas CO Emissions control Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ Commented [CE1]: Updated to Bay #9 Engineer Review N108840013: Heber Light & Power Company- Power Plant November 29, 2023 Page 8 II.A.8 One Engine Generator Unit #11 3516H Location: Bay #11 Maximum Rating: 1750 kW Fuel: Natural gas Control: Oxidation catalyst NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.9 One Engine Generator Unit #12 3520H Location: Bay #12 Maximum Rating: 2200 kW Fuel: Natural gas Control: Oxidation catalyst, and SCR NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.10 One Engine Generator (NEW) Unit #13 3520DSL Location: Bay #13 Maximum Rating: 2631 kW Fuel: Natural gas Control: Oxidation catalyst and SCR NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.11 NEW One Engine Generator (NEW) Unit #14 Location: Bay #14 Maximum Rating: 2550 kW Fuel: Natural gas Control: Oxidation catalyst, and SCR NSPS Applicability: Subpart JJJJ MACT Applicability: Subpart ZZZZ II.A.12 Research and Development Engines Various Diesel and Natural Gas Engines II.A.13 Two Backup Emergency Generators 1. Maximum Rating: 60 kW Fuel: Diesel 2. Maximum Rating: 80 kW Fuel: Diesel NSPS Applicability: Subpart IIII MACT Applicability: Subpart ZZZZ Engineer Review N108840013: Heber Light & Power Company- Power Plant November 29, 2023 Page 9 II.A.14 Various Portable Engines Maximum rating: 50 kW each Included for informational purposes 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 Limitation and Test Procedures II.B.1.a The owner/operator shall not allow visible emissions from the following emission points shall not exceed the following values: A. All diesel fired engines - 20% opacity B. All natural gas fired engines - 10% opacity [R307-201, R307-401-8] II.B.1.a.1 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 NEW The owner/operator shall not exceed the following operational hours per rolling 12-month period, from each unit as designated below: Unit #1, and #2: 4,000 hours combined Unit #4, #7, and #8: 7,800 hours combined Unit #5: 5,200 hours Unit #11: 5,200 hours Units #12,#13. #14: 15,600 hours combined R&D NG Engines: 8,000 hours combined Diesel R&D: 5,000 hours combined "combined" refers to the sum of hours allowed amongst all units for within the each engine group. [R307-401-8] II.B.1.c NEW The owner/operator shall maintain a log recording each unit's operational hours. The log shall include the unit's name and hours operated per month. The owner/operator shall calculate a new 12-month total by the 20th day of each month using data from the previous 12 months. [R307-401-8] Engineer Review N108840013: Heber Light & Power Company- Power Plant November 29, 2023 Page 10 II.B.1.d There shall not be more than six (6) R&D generators installed at the Heber Power Plant site. A report shall be submitted to DAQ before the engine generators are installed. The report shall include the manufactures expected emission levels, the expected hours of operation and the length of time that the engines will be operating. The following conditions shall apply to the R&D engine generators: A. The engine generators shall have not been manufactured more than 24-months prior to installation. B. An engine generator shall not exceed 24-months of operation. [R307-401-8] II.B.1.d.1 A report describing the results of the test operations of each engine generator tested shall be submitted to the Director, attention New Source Review Section, within 45 days after the engine generator has finished operating. The report, at a minimum, shall include the hp and kW rating, power produced, pollution control equipment used on the engine generator, total hours of operation on the engine, the power produced, NOx and CO emissions measured, and a summary of the emissions testing results along with calculated factors. [R307-401-8] II.B.1.e The owner/operator shall ensure that each engine listed under II.A.2 - II.A.12 vents exhaust gases vertically unrestricted with an attached stack height of no less than 53' feet. All stacks shall be installed within 18-months of the issuance of this AO and comply with condition I.8 of this AO. [R307-401-8, R307-410-4] II.B.2 Stack Testing Requirements II.B.2.a.1 Compliance Demonstration To demonstrate compliance with the emission limitations above, the owner/operator shall perform stack testing on the emissions unit according to the stack testing conditions contained in this AO. [R307-165-2, R307-401-8] Engineer Review N108840013: Heber Light & Power Company- Power Plant November 29, 2023 Page 11 II.B.2.a NEW The owner/operator shall not emit more than the following rates and concentrations from the following units: Location Pollutant lb/hr Unit #1 NOx 4.06 CO 1.0 Unit #2 NOx 4.06 CO 1.0 Unit #4 NOx 5.35 CO 1.0 Unit #5 NOx 3.00 CO 1.0 Unit #7 NOx 5.35 CO 1.0 Unit #8 NOx 5.35 CO 1.0 NG R&D Units (Each) NOx 5.50 CO 1.0 Diesel R&D NOx 2.5 CO 1.0 Unit #11 3516H NOx 4.75 CO 1.0 Unit #12 3520H NOx 0.54 CO 1.0 Unit #13 3520DSL NOx 0.54 CO 1.0 Unit #14 NOx 0.54 CO 1.0 [R307-401-8] Engineer Review N108840013: Heber Light & Power Company- Power Plant November 29, 2023 Page 12 II.B.2.b The owner/operator shall conduct any stack testing required by this AO according to the following conditions. [R307-401-8] II.B.2.b.1 Notification At least 30 days prior to conducting a stack test, the owner/operator shall submit a source test protocol to the Director. The source test protocol shall include the items contained in R307-165-3. If directed by the Director, the owner/operator shall attend a pretest conference. [R307-165-3, R307-401-8] II.B.2.b.2 Test Frequency The owner/operator shall conduct a stack test on each emission unit within whichever of the following parameters occurs first; 3 years or 8,760 hours of unit operation after the date of the most recent stack test of each listed emission unit. The Director may require the owner/operator to perform a stack test at any time. [R307-165-2, R307-401-8] II.B.2.b.3 NEW Initial Test The owner/operator shall conduct an initial stack test on Unit #14 within 180 days after startup of each emission unit. [R307-165-2] II.B.2.b.4 Testing & Test Conditions The owner/operator shall conduct testing according to the approved source test protocol and according to the test conditions contained in R307-165-4. [R307-165-4, R307-401-8] II.B.2.b.5 Reporting No later than 60 days after completing a stack test, the owner/operator shall submit a written report of the results from the stack testing to the Director. The report shall include validated results and supporting information. [R307-165-5, R307-401-8] II.B.2.c Test Methods When performing stack testing, the owner/operator shall use the appropriate EPA-approved test methods as acceptable to the Director. Acceptable test methods for pollutants are listed below. [R307-401-8] II.B.2.c.1 Standard Conditions A. Temperature - 68 degrees Fahrenheit (293 K) B. Pressure - 29.92 in Hg (101.3 kPa) C. Averaging Time - As specified in the applicable test method [40 CFR 60 Subpart A, 40 CFR 63 Subpart A, R307-401-8] II.B.2.c.2 NOx 40 CFR 60, Appendix A, Method 7; Method 7E; or other EPA-approved testing method as acceptable to the Director. [R307-401-8] II.B.2.c.3 CO 40 CFR 60, Appendix A, Method 10 or other EPA-approved testing method as acceptable to the Director. [R307-401-8] Engineer Review N108840013: Heber Light & Power Company- Power Plant November 29, 2023 Page 13 II.B.3 Monitoring II.B.3.a The owner/operator shall install, calibrate, maintain, and operate a monitoring device for the continuous measurement of the temperature of each oxidation catalyst. The monitoring device shall be accurate within plus or minus 25 degrees Fahrenheit. The temperature shall not exceed 1300 degrees Fahrenheit. Continuous recording for the monitoring device is not required. However, daily records of readings shall be maintained. [R307-401-8] II.B.4 Emergency Engine Requirements II.B.4.a The owner/operator shall not operate each emergency engine on site for more than 100 hours per rolling 12-month period during non-emergency situations. There is no time limit on the use of the engines during emergencies. [R307-401-8, 40 CFR 63 Subpart ZZZZ] II.B.4.a.1 To determine compliance with a rolling 12-month total, the owner/operator shall calculate a new 12-month total by the 20th day of each month using data from the previous 12 months. Records documenting the operation of each emergency engine shall be kept in a log and shall include the following: a. The date the emergency engine was used b. The duration of operation in hours c. The reason for the emergency engine usage [R307-401-8, 40 CFR 63 Subpart ZZZZ] II.B.4.b The owner/operator shall only use diesel fuel (e.g. fuel oil #1, #2, or diesel fuel oil additives) as fuel in each emergency engine. [R307-401-8] II.B.4.b.1 The owner/operator shall only combust diesel fuel that meets the definition of ultra-low sulfur diesel (ULSD), which has a sulfur content of 15 ppm or less. [R307-401-8] II.B.4.b.2 To demonstrate compliance with the ULSD fuel requirement, the owner/operator shall maintain records of diesel fuel purchase invoices or obtain certification of sulfur content from the diesel fuel supplier. The diesel fuel purchase invoices shall indicate that the diesel fuel meets the ULSD requirements. [R307-401-8] Engineer Review N108840013: Heber Light & Power Company- Power Plant November 29, 2023 Page 14 PERMIT HISTORY When issued, the approval order shall supersede (if a modification) or will be based on the following documents: Supersedes DAQE-AN108840012-22 dated June 6, 2022 Is Derived From Notice of Intent dated January 4, 2023 Incorporates Additional Information dated REVIEWER COMMENTS 1. Comment regarding Emission Estimates: Site-wide PTE was recalculated in this modification, including updated lb/hr limits as determined by engine testing for NOx and CO. All emissions were based on the maximum hours of operation per engine, the engine size, and specific emission rate. SO2, VOC, PM10, PM2.5 and HAP emissions for natural-gas fired engines were calculated using emission factors from AP-42 Chapter 3 Section 3.2. NOx and CO emissions were estimated using stack testing results. Each engine will be tested to the NOx and CO lb/hr rate as outline in the conditions of section II.B. Units fitted with an oxidation catalyst applied a 50% control efficiency to VOC, HAP emissions. SO2, VOC, PM10, PM2.5 and HAP emissions for the R&D Diesel Engines were calculated using emission factors from AP-42 Chapter 3, Section 3.4 Tables 1 and 2. NOx and CO emissions were estimate using previous stack testing data. Emissions for the diesel engines was estimated assuming 18.50 MMBtu/hr of diesel burned over 5,000 hours. Criteria emissions for the diesel-fired emergency engines were calculated using the "Diesel-Fired Engines" excel sheet proved by DAQ under the "Calculate Your Emissions" page. Emissions were estimated for 100 hours of use for the 60 kW and 80 kW engines. GHG emissions were estimated using the multiplication factors from 40 CFR Part 98, Subpart A, Table A-1. [Last updated May 16, 2023] 2. Comment regarding NSPS and MACT Applicability: 40 CFR 60 Subpart JJJJ Standards of Performance for Stationary Spark Ignition Internal Combustion Engines applies to new, modified, or reconstructed stationary sources that meet or exceed specified applicability thresholds. Engines Unit #5 and Unit #13 are subject to the requirements of this subpart. 40 CFR 63 Subpart ZZZZ National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines applies to stationary RICE at a major or area source of HAP emissions. All engines are subject to Subpart ZZZZ. [Last updated January 12, 2023] Engineer Review N108840013: Heber Light & Power Company- Power Plant November 29, 2023 Page 15 3. Comment regarding Title V Applicability: Title V of the 1990 Clean Air Act (Title V) applies to the following: 1. Any major source 2. Any source subject to a standard, limitation, or other requirement under Section 111 of the Act, Standards of Performance for New Stationary Sources; 3. Any source subject to a standard or other requirement under Section 112 of the Act, Hazardous Air Pollutants. 4. Any Title IV affected source. This source is not a major source, is not a Title IV source. Therefore, Title V does not apply to this facility. [Last updated January 12, 2023] 4. Comment regarding Updated Emission Rates: The total changes will result in a decrease of 6.84 ton per year for all engines combined. Emissions for the previous AO were based on proposed operating conditions with a 20% growth increase factored in. These emission parameters were factored into the operational hours. As a result of on- sight testing, the source has requested an update to each engine to account for these values within the operational hour limits and lb/hr limits. SCRs were added to engines #12, #13 and the new engine #14. After stack testing and facility evaluations, the source has requested each engine to change as follows: Previous Hours Proposed Hours Previous CO lb/hr Proposed CO lb/hr Previous NOx lb/hr Proposed NOx lb/hr Unit #1 1200 2000 0.3 1 3.76 4.06 Unit #2 24001200 2000 0.3 1 2.86 4.06 Unit #4 2400 2600 0.3 1 5.35 5.35 Unit #5 3600 5200 0.3 1 2.39 3 Unit #6 240 -- 0.3 -- 3.95 -- Unit #7 2640 2600 0.3 1 4.37 5.35 Unit #8 2520 2600 0.3 1 4.63 5.35 NG R&D 4800 8000 0.3 1 4.94 5.5 Diesel R&D 6000 5000 0.14 1 1.84 2.5 Unit #11 5400 5200 0.01 1 3.84 4.75 Unit #12 5400 5200 0.05 1 5.15 0.54 Unit #13 5400 5200 0.14 1 6.78 0.54 Unit #14 -- 5200 -- 1 -- 0.54 [Last updated November 29, 2023] Commented [CE2]: Please update to 1200 Engineer Review N108840013: Heber Light & Power Company- Power Plant November 29, 2023 Page 16 5. Comment regarding Updated Emission Rates Continued: Previous Hours Proposed Hours Change in TPY NOx Change in TPY CO Unit #1 1200 2000 1.804 0.82 Unit #2 24001200 2000 0.628 0.64 Unit #4 2400 2600 0.535 0.94 Unit #5 3600 5200 3.498 2.06 Unit #6 240 -- -0.474 -0.036 Unit #7 2640 2600 1.1866 0.904 Unit #8 2520 2600 1.1212 0.922 NG R&D 4800 8000 10.144 3.28 Diesel R&D 6000 5000 0.73 2.08 Unit #11 5400 5200 1.982 2.573 Unit #12 5400 5200 -12.501 2.465 Unit #13 5400 5200 -16.902 2.222 Unit #14 -- 5200 1.404 2.6 Total Change TPY -6.8442 21.47 Commented [CE3]: Sam comment as above Engineer Review N108840013: Heber Light & Power Company- Power Plant November 29, 2023 Page 17 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 Just Engines lb/hr lb/hr Previous HourProposed Hou Unit #1 Previous Proposed Unit #1 1200 2000 NOx 3.76 4.06 Unit #2 1200 2000 CO 0.3 1 Unit #4 2400 2600 Hours 1200 2000 Unit #5 3600 5200 Unit #6 240 -- Unit #2 Previous Proposed Unit #7 2640 2600 NOx 2.86 4.06 Unit #8 2520 2600 CO 0.3 1 NG R&D 4800 8000 Hours 2400 2000 Diesel R&D 6000 5000 Unit #11 5400 5200 Unit #4 Previous Proposed Unit #12 5400 5200 NOx 5.35 5.35 Unit #13 5400 5200 CO 0.3 1 Unit #14 --5200 Hours 2400 2600 Previous HourProposed Hou Unit #1 1200 2000 Unit #5 Previous Proposed Unit #2 1200 2000 NOx 2.39 3 Unit #4 2400 2600 CO 0.3 1 Unit #5 3600 5200 Hours 3600 5200 Unit #6 240 -- Unit #7 2640 2600 Unit #6 Previous Proposed Unit #8 2520 2600 NOx 3.95 --NG R&D 4800 8000 CO 0.3 --Diesel R&D 6000 5000 Hours 240 --Unit #11 5400 5200 Unit #12 5400 5200 Unit #7 Previous Proposed Unit #13 5400 5200 NOx 4.37 5.35 Unit #14 --5200 CO 0.3 1 Total Change Hours 2640 2600 Unit #8 Previous Proposed NOx 4.63 5.35 CO 0.3 1 Hours 2520 2600 NG R&D Previous Proposed NOx 4.94 5.5 CO 0.3 1 Hours 4800 8000 Diesel R&D Previous Proposed NOx 1.84 2.51 CO 0.14 1 Hours 6000 5000 Unit #11 Previous Proposed NOx 3.84 4.75 CO 0.01 1 Hours 5400 5200 Unit #12 Previous Proposed NOx 5.15 0.54 CO 0.05 1 Hours 5400 5200 Unit #13 Previous Proposed NOx 6.78 0.54 CO 0.14 1 Hours 5400 5200 Unit #14 Previous Proposed NOx --0.54 CO --1 Hours --5200 Previous CO Proposed CO Previous NOx Proposed NOx 0.3 1 3.76 4.06 0.3 1 2.86 4.06 0.3 1 5.35 5.35 0.3 1 2.39 3 0.3 --3.95 -- 0.3 1 4.37 5.35 0.3 1 4.63 5.35 0.3 1 4.94 5.5 0.14 1 1.84 2.5 0.01 1 3.84 4.75 0.05 1 5.15 0.54 0.14 1 6.78 0.54 --1 --0.54 Change in TPY NChange in TPY CO 0 1.804 0.82 2.344 0.82 0.535 0.94 3.498 2.06 -0.474 -0.036 1.1866 0.904 1.1212 0.922 10.144 3.28 0.73 2.08 1.982 2.573 -12.501 2.465 -16.902 2.222 1.404 2.6 -5.1282 21.65 DAQE-MN108840013-23 M E M O R A N D U M TO: Sarah Foran, NSR Engineer FROM: Jason Krebs, Air Quality Modeler DATE: June 27, 2022 SUBJECT: Modeling Analysis Review for the Notice of Intent for Heber Light and Power Company – Heber Power Plant, Wasatch County, Utah _____________________________________________________________________________________ This is not a Major Prevention of Significant Deterioration (PSD) Source. I. OBJECTIVE Heber Light and Power Company (Applicant) is seeking an approval order for their power plant located in Wasatch County, Utah. Heber has requested a modification to their AO for the addition of a new natural-gas-fired engine, the replacement of an existing engine, and the removal of diesel 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 Applicant. 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 9 , JK DAQE- MN108840013-23 Page 2 B. Assumptions 1. Topography/Terrain The Plant is at an elevation 5571 feet with terrain features that have an affect on concentration predictions. a. Zone: 12 b. Approximate Location: UTM (NAD83): 463,964 meters East 4,483,733 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 – Spanish Fork, UT NWS: 2004-208 Upper Air – Salt Lake Airport, UT NWS: 2004-2008 6. Background The background concentrations were based on concentrations measured in Price, 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- MN108840013-23 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 Source UTM Coordinates Modeled Emission Rates Easting Northing Nox (m) (m) (lb/hr) (tons/yr) hrs/year ENGINE1 464002 4483705 4.0600 17.783 8760 ENGINE2 463963 4483684 4.0600 17.783 8760 ENGINE4 464006 4483705 5.3500 23.433 8760 ENGINE7 463966 4483684 5.3500 23.433 8760 ENGINE8 463970 4483684 5.3500 23.433 8760 ENGINE5 463959 4483684 3.0000 13.140 8760 RD_NG#1 463996 4483811 5.5000 24.090 8760 RD_NG#2 463996 4483816 5.5000 24.090 8760 ENGINE11 464011 4483705 4.7500 20.805 8760 ENGINE12 464015 4483705 1.2000 5.256 8760 ENGINE13 464020 4483705 1.2000 5.256 8760 RD_DIESL 463996 4483821 2.5000 10.950 8760 ENGINE14 464025 4483705 1.2000 5.256 8760 Total 49.0203 214.7087 10. Source Location and Parameters Source Type Source Parameters Elev, Ht Temp Flow Dia (ft) (m) (ft) (K) (m/s) (ft) ENGINE1 POINT 5568.6 16.2 53.0 702 23.50 0.50 ENGINE2 POINT 5567.0 16.2 53.0 702 23.50 0.50 ENGINE4 POINT 5568.6 16.2 53.0 760 40.94 0.50 ENGINE7 POINT 5567.0 16.2 53.0 760 39.71 0.50 ENGINE8 POINT 5567.0 16.2 53.0 760 39.71 0.50 ENGINE5 POINT 5566.9 16.2 53.0 789 15.19 0.71 RD_NG#1 POINT 5563.9 16.2 53.0 714 22.95 0.53 RD_NG#2 POINT 5563.7 16.2 53.0 714 22.95 0.53 ENGINE11 POINT 5568.7 16.2 53.0 671 25.61 0.53 DAQE- MN108840013-23 Page 4 ENGINE12 POINT 5568.7 16.2 53.0 671 28.43 0.56 ENGINE13 POINT 5568.7 16.2 53.0 729 36.19 0.56 RD_DIESL POINT 5563.5 16.2 53.0 714 21.16 0.53 ENGINE14 POINT 5568.8 16.2 53.0 708 27.41 0.56 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. RESULTS 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 116.9 7.5 23.3 0.0 140.2 188 74.57% V. PERMIT CONDITIONS The following suggested permit language should be included under the Terms and Conditions in the AO:  The owner/operator shall ensure that each engine listed in this Approval Order vents exhaust gases vertically unrestricted with an attached stack height of no less than 53 feet. JMK:jg 4-Stroke Lean-Burn Engines Eng 5 Eng 11 Eng 12 Eng 13 Eng 14 Engine 1 Engine 2 Engine 4 G3516 Engine 7 Engine 8 3516H G3520H 3520DSL4 G35206 R&D NG KW 1350 1350 1850 1550 1850 1850 1750 2200 2631 2550 2700 MMBtu/hr 12.7 12.7 17.4 14.5 17.4 17.4 16.4 20.6 24.7 23.9 25.3 Hours/yr 2000 2000 2600 5200 2600 2600 5200 5200 5200 5200 8000 lb/MMBtu lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr TotalSO25.88E-04 7.45E-03 7.45E-03 1.02E-02 8.55E-03 1.02E-02 1.02E-02 9.65E-03 1.21E-02 1.45E-02 1.41E-02 1.49E-02 0.12 VOC1-6 1.18E-01 0.75 0.75 1.02 0.48 1.02 1.02 0.62 0.81 0.84 0.75 1.49 9.57PM107.71E-05 9.76E-04 9.76E-04 1.34E-03 1.12E-03 1.34E-03 1.34E-03 1.27E-03 1.59E-03 1.90E-03 1.84E-03 1.95E-03 1.56E-02 PM2.5 7.71E-05 9.76E-04 9.76E-04 1.34E-03 1.12E-03 1.34E-03 1.34E-03 1.27E-03 1.59E-03 1.90E-03 1.84E-03 1.95E-03 1.56E-02 1,3-Butadiene 2.67E-04 1.69E-03 1.69E-03 2.32E-03 1.94E-03 2.32E-03 2.32E-03 2.19E-03 2.75E-03 3.29E-03 3.19E-03 3.38E-03 2.71E-02 2,2,4-Trimethylpentane 2.50E-04 1.58E-03 1.58E-03 2.17E-03 1.82E-03 2.17E-03 2.17E-03 2.05E-03 2.58E-03 3.08E-03 2.99E-03 3.17E-03 2.54E-02 Acetaldehyde 8.36E-03 5.29E-02 5.29E-02 7.25E-02 6.08E-02 7.25E-02 7.25E-02 6.86E-02 8.63E-02 1.03E-01 1.00E-01 1.06E-01 8.48E-01 Acrolein 5.14E-03 3.25E-02 3.25E-02 4.46E-02 3.74E-02 4.46E-02 4.46E-02 4.22E-02 5.30E-02 6.34E-02 6.15E-02 6.51E-02 5.21E-01 Benzene 4.40E-04 2.79E-03 2.79E-03 3.82E-03 3.20E-03 3.82E-03 3.82E-03 3.61E-03 4.54E-03 5.43E-03 5.26E-03 5.57E-03 4.46E-02 Biphenyl 2.12E-04 1.34E-03 1.34E-03 1.84E-03 1.54E-03 1.84E-03 1.84E-03 1.74E-03 2.19E-03 2.62E-03 2.54E-03 2.68E-03 2.15E-02 Formaldehyde 5.28E-02 3.34E-01 3.34E-01 4.58E-01 3.84E-01 4.58E-01 4.58E-01 5.45E-01 3.41E-01 2.78E-01 3.05E-01 6.69E-01 4.56E+00 Methanol 2.50E-03 1.58E-02 1.58E-02 2.17E-02 1.82E-02 2.17E-02 2.17E-02 2.05E-02 2.58E-02 3.08E-02 2.99E-02 3.17E-02 2.54E-01 Hexane 1.11E-03 7.03E-03 7.03E-03 9.63E-03 8.07E-03 9.63E-03 9.63E-03 9.11E-03 1.15E-02 1.37E-02 1.33E-02 1.41E-02 1.13E-01 Toluene 4.08E-04 2.58E-03 2.58E-03 3.54E-03 2.97E-03 3.54E-03 3.54E-03 3.35E-03 4.21E-03 5.03E-03 4.88E-03 5.17E-03 4.14E-02 Xylene 1.84E-04 1.16E-03 1.16E-03 1.60E-03 1.34E-03 1.60E-03 1.60E-03 1.51E-03 1.90E-03 2.27E-03 2.20E-03 2.33E-03 1.87E-02 T/yr T/yr T/yr T/yr T/yr T/yr T/yr T/yr T/yr T/yr T/yr TotalSO27.45E-03 7.45E-03 1.33E-02 2.22E-02 1.33E-02 1.33E-02 2.51E-02 3.15E-02 3.77E-02 3.66E-02 5.96E-02 0.27 VOC 0.75 0.75 1.33 1.25 1.33 1.33 1.61 2.11 2.19 1.96 5.98 20.58PM109.76E-04 9.76E-04 1.74E-03 2.91E-03 1.74E-03 1.74E-03 3.29E-03 4.14E-03 4.95E-03 4.79E-03 7.81E-03 3.51E-02 PM2.5 9.76E-04 9.76E-04 1.74E-03 2.91E-03 1.74E-03 1.74E-03 3.29E-03 4.14E-03 4.95E-03 4.79E-03 7.81E-03 3.51E-02 1,3-Butadiene 1.69E-03 1.69E-03 3.01E-03 5.05E-03 3.01E-03 3.01E-03 5.70E-03 7.16E-03 8.56E-03 8.30E-03 1.35E-02 6.07E-02 2,2,4-Trimethylpentane 1.58E-03 1.58E-03 2.82E-03 4.73E-03 2.82E-03 2.82E-03 5.33E-03 6.71E-03 8.02E-03 7.77E-03 1.27E-02 5.68E-02 Acetaldehyde 5.29E-02 5.29E-02 9.43E-02 1.58E-01 9.43E-02 9.43E-02 1.78E-01 2.24E-01 2.68E-01 2.60E-01 4.23E-01 1.90E+00 Acrolein 3.25E-02 3.25E-02 5.80E-02 9.71E-02 5.80E-02 5.80E-02 1.10E-01 1.38E-01 1.65E-01 1.60E-01 2.60E-01 1.17E+00 Benzene 2.79E-03 2.79E-03 4.96E-03 8.32E-03 4.96E-03 4.96E-03 9.39E-03 1.18E-02 1.41E-02 1.37E-02 2.23E-02 1.00E-01 Biphenyl 1.34E-03 1.34E-03 2.39E-03 4.01E-03 2.39E-03 2.39E-03 4.52E-03 5.69E-03 6.80E-03 6.59E-03 1.07E-02 4.82E-02 Formaldehyde 3.34E-01 3.34E-01 5.96E-01 9.98E-01 5.96E-01 5.96E-01 1.42E+00 8.87E-01 7.24E-01 7.93E-01 2.67E+00 9.95E+00 Methanol 1.58E-02 1.58E-02 2.82E-02 4.73E-02 2.82E-02 2.82E-02 5.33E-02 6.71E-02 8.02E-02 7.77E-02 1.27E-01 5.68E-01 Hexane 7.03E-03 7.03E-03 1.25E-02 2.10E-02 1.25E-02 1.25E-02 2.37E-02 2.98E-02 3.56E-02 3.45E-02 5.62E-02 2.52E-01 Toluene 2.58E-03 2.58E-03 4.60E-03 7.71E-03 4.60E-03 4.60E-03 8.71E-03 1.09E-02 1.31E-02 1.27E-02 2.07E-02 9.28E-02 Xylene 1.16E-03 1.16E-03 2.08E-03 3.48E-03 2.08E-03 2.08E-03 3.93E-03 4.94E-03 5.90E-03 5.72E-03 9.32E-03 4.18E-02 14.24 1. Each engine (1,2,4,7,8) has an oxidation catalyst installed and each has a VOC and HAPs control efficiency of 50%. The total lb/hr and t/yr calculation is multiplied by 50% to account for the control device. 2. 3516H and 3520H have a control efficiency of VOCs and HAPs of 50%. 3. The R&D engines are assumed to have 50% control of VOC and HAPs. 4. 3520DSL has a site specific VOC emission rate of 0.29 g/kw-hr, Formaldehyde of 0.32 g/kw-hr; VOC and all HAPs except HCOH (see footnote 6) assume 50% control from OC. 5. Engine 5 has an oxycat with 50% control efficiency for VOC/HAPs; Also the VOC emission rate is derived from the CAT spec sheet in g/hp-hr 6. Engines 12-14 are now equipped with an SCR and OC that controls VOCs at 50% and formaldehyde at 75-85%. bhp VOC CO2 HCHO Eng5 2173 0.21 461 0 g/hp-hr Eng11 2745 0.43 399 0.18 g/hp-hr Eng12 3262 0.25 401 0.21 g/hp-hr Eng13 3525 0.29 587 0.32 g/kW-hr Eng14 3161 0.2 396 0.27 g/hp-hr 0.4288 4.232425 0.030016 0.143443 7.030129 Large Diesel Engines AP-42 Chapter 3 Section 3.4 Tables 1 & 2 R&D Engs MMBtu/hr 18.50 Hours/yr 5000 Emission factor lb/hr TotalSOx10.00809*S lb/hp-hr 5.70E-02 0.06 VOC 7.05E-04 lb/hp-hr 3.31 3.31PM105.73E-02 lb/MMBtu 1.06 1.06 PM2.5 5.56E-02 lb/MMBtu 1.03 1.03 HAPs Emission factor Formaldehyde 7.89E-05 lb/MMBtu 1.46E-03 1.46E-03 Acetaldehyde 2.52E-05 lb/MMBtu 4.66E-04 4.66E-04 Toluene 2.81E-04 lb/MMBtu 5.20E-03 0.01 Xylene 1.93E-04 lb/MMBtu 3.57E-03 0.00 Acrolein 7.88E-06 lb/MMBtu 1.46E-04 1.46E-04 T/yr Total T/yrSOx1.42E-01 0.14 VOC 8.27 8.27PM102.65 2.65 PM2.5 2.57 2.57 HAPs Formaldehyde 3.65E-03 3.65E-03 Acetaldehyde 1.17E-03 1.17E-03 Toluene 1.30E-02 1.30E-02 Xylene 8.93E-03 8.93E-03 Acrolein 3.64E-04 3.64E-04 0.03 1. 'S' refers to the percentage of sulfur assumed in the distillate fuel. Heber Light and Power uses ultra low sulfur which is assumed to be 15ppm or 0.0015% 2023 2024 2025 2026 2027 2028 NOx CO NOx T/yr CO T/yr NOx T/yr CO T/yr NOx T/yr CO T/yr NOx T/yr CO T/yr NOx T/yr CO T/yr NOx T/yr CO T/yr Average Maximum Average MaximumEngine 1 2000 2000 2000 2000 2000 2000 4.06 1.00 4.06 1.00 4.06 1.00 4.06 1.00 4.06 1.00 4.06 1.00 4.06 1.00 4.06 4.06 1.00 1.00Engine 2 2000 2000 2000 2000 2000 2000 4.06 1.00 4.06 1.00 4.06 1.00 4.06 1.00 4.06 1.00 4.06 1.00 4.06 1.00 4.06 4.06 1.00 1.00Engine 4 2600 2600 2600 2600 2600 2600 5.35 1.00 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 6.96 1.30 1.30Engine 5 5200 5200 5200 5200 5200 5200 3.00 1.00 7.80 2.60 7.80 2.60 7.80 2.60 7.80 2.60 7.80 2.60 7.80 2.60 7.80 7.80 2.60 2.60Engine 7 2600 2600 2600 2600 2600 2600 5.35 1.00 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 6.96 1.30 1.30Engine 8 2600 2600 2600 2600 2600 2600 5.35 1.00 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 6.96 1.30 1.30NG R&D Engines 8000 8000 8000 8000 8000 8000 5.50 1.00 22.00 4.00 22.00 4.00 22.00 4.00 22.00 4.00 22.00 4.00 22.00 4.00 22.00 22.00 4.00 4.00Diesel R&D Engines w/ urea 5000 5000 5000 5000 5000 5000 2.50 1.00 6.25 2.50 6.25 2.50 6.25 2.50 6.25 2.50 6.25 2.50 6.25 2.50 6.25 6.25 2.50 2.50 Engine 11 3516H 5200 5200 5200 5200 5200 5200 4.75 1.00 12.35 2.60 12.35 2.60 12.35 2.60 12.35 2.60 12.35 2.60 12.35 2.60 12.35 12.35 2.60 2.60 Engine 12 3520H 5200 5200 5200 5200 5200 5200 0.54 1.00 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 1.40 2.60 2.60 Engine 13 3520DSL 5200 5200 5200 5200 5200 5200 0.54 1.00 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 1.40 2.60 2.60 Engine 14 G3520 5200 5200 5200 5200 5200 5200 0.54 1.00 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 1.40 2.60 2.60 Totals 50800.0 50800.0 50800.0 50800.0 50800.0 50800.0 41.5 12.0 81.6 25.4 81.6 25.4 81.6 25.4 81.6 25.4 81.6 25.4 81.6 25.4 81.6 81.6 25.4 25.4 Max NOx Max CO Current Facility Engines 51.94 16.30 R&D Engines 28.25 6.50 CAT G3520 1.40 2.60 81.60 25.40 2024 2025 NOx T/yr CO T/yr Heber Light & Power 6 Year Emission Forecast lb/hr (Test Results)2023 2024 2025 2026 Equipment Details Rating 80 hp = (60 kw) Operational Hours 100 hours/year Sulfur Content 15 ppm or 0.0015% Criteria Pollutant Emission Standards (g/hp-hr) Emission Factor (lb/hp-hr) Emission Rate (lbs/hr) Emission Total (tons/year)Reference NOX 5.8022 1.03 0.05 CO 1.541 0.27 0.01 PM10 0.24 0.04 0.00 PM2.5 0.24 0.04 0.00 VOC 2.51E-03 0.20 0.01SO21.21E-05 0.00 0.00 AP-42 Table 3.4-1 HAP 0.00 0.00 See Below Green House Gas Pollutant Global Warming Potential Emission Factor (lb/hp-hr) Emission Rate (lbs/hr) Emission Total (tons/year)ReferenceCO2 (mass basis)1 1.15E+00 92 5 Methane (mass basis)25 0 0CO2e5 Hazardous Air Pollutant Emission Rate (lbs/hr) Emission Total (tons/year)Reference Benzene 9.33E-04 5.24E-04 2.62E-05 Toluene 4.09E-04 2.30E-04 1.15E-05 Xylenes 2.85E-04 1.60E-04 8.01E-06 1,3-Butadiene 3.91E-05 2.20E-05 1.10E-06 Formaldehyde 1.18E-03 6.63E-04 3.32E-05 Acetaldehyde 7.67E-04 4.31E-04 2.16E-05 Acrolein 9.25E-05 5.20E-05 2.60E-06 Naphthalene 8.48E-05 4.77E-05 2.38E-06 Acenaphthylene 5.06E-06 2.84E-06 1.42E-07 Acenaphthene 1.42E-06 7.98E-07 3.99E-08 Fluorene 2.92E-05 1.64E-05 8.21E-07 Phenanthrene 2.94E-05 1.65E-05 8.26E-07 Anthracene 1.87E-06 1.05E-06 5.26E-08 Fluoranthene 7.61E-06 4.28E-06 2.14E-07 Pyrene 4.78E-06 2.69E-06 1.34E-07 Benz(a)anthracene 1.68E-06 9.44E-07 4.72E-08 Chrysene 3.53E-07 1.98E-07 9.92E-09 Benzo(b)fluoranthene 9.91E-08 5.57E-08 2.79E-09 Benzo(k)fluoranthene 1.55E-07 8.71E-08 4.36E-09 Benzo(a)pyrene 1.88E-07 1.06E-07 5.28E-09 Indeno(1,2,3-cd)pyrene 3.75E-07 2.11E-07 1.05E-08 Dibenz(a,h)anthracene 5.83E-07 3.28E-07 1.64E-08 Benzo(g,h,l)perylene 4.89E-07 2.75E-07 1.37E-08 AP-42 Table 3.3-1 & Table 3.4-1 Emission Factor (lb/MMBtu) AP-42 Table 3.3-2, Table 3.4-3, & Table 3.4-4 (1,3-Butadiene will not popluate if the engine size is greater than 600 hp. AP-42 does not list 1,3- Butadiene for engines greater than 600 hp.) Diesel-Fired Engines Emergency Engines should equal 100 hours of operation per year Manufacturer Data, AP-42 Table 3.3-1, & Table 3.4-1 Page 5 of Version 1.1 February 21, 2019 Equipment Details Rating 107 hp = (80 kw) Operational Hours 100 hours/year Sulfur Content 15 ppm or 0.0015% Criteria Pollutant Emission Standards (g/hp-hr) Emission Factor (lb/hp-hr) Emission Rate (lbs/hr) Emission Total (tons/year)Reference NOX 5.1992 1.23 0.06 CO 1.2864 0.30 0.02 PM10 0.23 0.05 0.00 PM2.5 0.23 0.05 0.00 VOC 2.51E-03 0.27 0.01SO21.21E-05 0.00 0.00 AP-42 Table 3.4-1 HAP 0.00 0.00 See Below Green House Gas Pollutant Global Warming Potential Emission Factor (lb/hp-hr) Emission Rate (lbs/hr) Emission Total (tons/year)ReferenceCO2 (mass basis)1 1.15E+00 123 6 Methane (mass basis)25 0 0CO2e6 Hazardous Air Pollutant Emission Rate (lbs/hr) Emission Total (tons/year)Reference Benzene 9.33E-04 6.99E-04 3.50E-05 Toluene 4.09E-04 3.07E-04 1.53E-05 Xylenes 2.85E-04 2.14E-04 1.07E-05 1,3-Butadiene 3.91E-05 2.93E-05 1.47E-06 Formaldehyde 1.18E-03 8.85E-04 4.42E-05 Acetaldehyde 7.67E-04 5.75E-04 2.88E-05 Acrolein 9.25E-05 6.93E-05 3.47E-06 Naphthalene 8.48E-05 6.36E-05 3.18E-06 Acenaphthylene 5.06E-06 3.79E-06 1.90E-07 Acenaphthene 1.42E-06 1.06E-06 5.32E-08 Fluorene 2.92E-05 2.19E-05 1.09E-06 Phenanthrene 2.94E-05 2.20E-05 1.10E-06 Anthracene 1.87E-06 1.40E-06 7.01E-08 Fluoranthene 7.61E-06 5.71E-06 2.85E-07 Pyrene 4.78E-06 3.58E-06 1.79E-07 Benz(a)anthracene 1.68E-06 1.26E-06 6.30E-08 Chrysene 3.53E-07 2.65E-07 1.32E-08 Benzo(b)fluoranthene 9.91E-08 7.43E-08 3.71E-09 Benzo(k)fluoranthene 1.55E-07 1.16E-07 5.81E-09 Benzo(a)pyrene 1.88E-07 1.41E-07 7.05E-09 Indeno(1,2,3-cd)pyrene 3.75E-07 2.81E-07 1.41E-08 Dibenz(a,h)anthracene 5.83E-07 4.37E-07 2.19E-08 Benzo(g,h,l)perylene 4.89E-07 3.67E-07 1.83E-08 AP-42 Table 3.3-1 & Table 3.4-1 Emission Factor (lb/MMBtu) AP-42 Table 3.3-2, Table 3.4-3, & Table 3.4-4 (1,3-Butadiene will not popluate if the engine size is greater than 600 hp. AP-42 does not list 1,3- Butadiene for engines greater than 600 hp.) Diesel-Fired Engines Emergency Engines should equal 100 hours of operation per year Manufacturer Data, AP-42 Table 3.3-1, & Table 3.4-1 Page 6 of Version 1.1 February 21, 2019 Pollutants - Current Emissions lb/hr T/yr SOx 0.17 0.37 VOC 14.74 28.14 PM10 1.17 3.21 PM2.5 1.14 3.12 NOx 49.87 86.86 CO 3.60 6.15 HAPs 7.07 12.80 GHG1 25,349 44,630 1. Metric tons of CO2e Pollutants - Proposed Update lb/hr T/yrSOx0.18 0.41 VOC 13.35 28.88PM101.17 2.69 PM2.5 1.14 2.61 NOx 43.79 81.71 CO 12.58 25.43 HAPs 6.50 14.27 GHG1 28,921 59,732 1. Metric tons of CO2e GWP CH43 1 g/MMBtu 25 Greenhouse Gas Emissions CO23 53.06 kg/MMBtu 1 N2O3 0.10 g/MMBtu 298Emission Unit Rating CO2 N2O CH4 CO2e1 Engine 1 12.66 1478 3.E-03 2.79E-02 1480 Engine 2 12.66 1478 3.E-03 2.79E-02 1480 CH43 3 g/MMBtu Engine 4 17.35 2026 4.E-03 3.83E-02 2028 CO23 73.96 kg/MMBtu G35164 14.54 2208 3.E-03 3.21E-02 2210 N2O3 0.60 g/MMBtu Engine 7 17.35 2026 4.E-03 3.83E-02 2028 Engine 8 17.35 2026 4.E-03 3.83E-02 2028 3516H4 16.42 2415 4.E-03 3.62E-02 2417 G3520H4 20.64 2884 5.E-03 4.55E-02 2886 3520DSL4 24.68 3404 5.E-03 5.44E-02 3407 G35204 23.92 2760 5.E-03 5.27E-02 2762 R&D NG 25.33 2956 6.E-03 5.58E-02 2959 R&D Engs 18.50 3010 2.E-02 1.22E-01 3021 Diesel Emergency 15 92 0.00E+00 92 Diesel Emergency 25 123 0.00E+00 123 Total 28,886 0.07 0.57 28,921 Rating CO2 N2O CH4 CO2e1,2 Engine 1 12.66 1340.99 2.53E-03 0.03 1342.38 Engine 2 12.66 1340.99 0.00 0.03 1342.38 Engine 4 17.35 2388.96 0.00 0.05 2391.43 G3516 14.54 5209.08 0.01 0.08 5213.22 Engine 7 17.35 2388.96 0.00 0.05 2391.43 Engine 8 17.35 2388.96 0.00 0.05 2391.43 3516H 16.42 5695.29 0.01 0.09 5699.97 G3520H 20.64 6801.88 0.01 0.11 6807.76 3520DSL 24.68 8029.58 0.01 0.13 8036.61 G3520 23.92 6509.09 0.01 0.12 6515.90 R&D NG 25.33 10727.95 0.02 0.20 10739.05 R&D Engs 18.50 6827.03 0.06 0.28 6850.50 Diesel Emergency 1 4.19 0.00 4.19 Diesel Emergency 2 5.59 0.00 5.59 Total 59,659 0.15 1.19 59,732 1. The total CO2e was calculated using global warming potentials from 40 CFR Part 98, Subpart A, Table A-1 2. The conversion from pounds to metric tons is 2204.6 lb to each metric ton. 3. Emission factor are from EPA GHG Inventories. https://www.epa.gov/sites/production/files/2018-03/documents/emission-factors_mar_2018_0.pdf 4. G3516, 3516H, G3520H 3520DSL and G3520 has a CO2 emission rate of 461 g/hp-hr, 399 g/hp-hr, 401 g/hp-hr, 587 g/kw-hr and 396 g/hp-hr, respectively 5. Used UDAQ emission calculation spreadsheet with uses AP-42, Table 3.3-1 pounds per hour metric tons per year Heber Light & Power Company Notice of Intent Modification to Approval Order DAQE-AN108840012-22 Prepared for: Heber Light & Power 735 West 300 South Heber, Utah 84032 Contact: Jason Norlen 435-657-6450 Prepared by: Stantec Consulting Services, Inc 727 East Riverpark Lane Suite 150 Boise ID 83706-4089 Contact: Eric Clark 208.388.4324 January 4, 2023 Sign-off Sheet This document entitled Heber Light & Power Company Notice of Intent was prepared by Stantec Consulting Services Inc. (“Stantec”) for the account of Heber Light & Power Company (the “Client”). Any reliance on this document by any third party is strictly prohibited. The material in it reflects Stantec’s professional judgment in light of the scope, schedule and other limitations stated in the document and in the contract between Stantec and the Client. The opinions in the document are based on conditions and information existing at the time the document was published and do not take into account any subsequent changes. In preparing the document, Stantec did not verify information supplied to it by others. Any use which a third party makes of this document is the responsibility of such third party. Such third party agrees that Stantec shall not be responsible for costs or damages of any kind, if any, suffered by it or any other third party as a result of decisions made or actions taken based on this document. Prepared by (signature) Eric Clark, PE Reviewed by (signature) Daniel Heiser, PE HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Table of Contents EXECUTIVE SUMMARY ............................................................................................................... I 1.0 INTRODUCTION ...........................................................................................................1.1 OVERVIEW ................................................................................................................... 1.1 EMISSION SOURCES .................................................................................................... 1.1 2.0 REGULATORY APPLICABLITY .......................................................................................2.1 NATIONAL AMBIENT AIR QUALITY STANDARDS (NAAQS) ......................................... 2.1 TITLE V (PART 70) OPERATING PERMIT ........................................................................ 2.2 NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS (NESHAPS) ................................................................................................................... 2.2 NEW SOURCE REVIEW (NSR) REQUIREMENTS ............................................................ 2.3 NEW SOURCES PERFORMANCE STANDARDS (NSPS) ................................................ 2.3 ACID RAIN REQUIREMENTS ......................................................................................... 2.3 RISK MANAGEMENT PROGRAMS FOR CHEMICAL ACCIDENTAL RELEASE PREVENTION ................................................................................................................ 2.3 STATE RULES ................................................................................................................. 2.4 2.8.1 General Requirements ............................................................................. 2.4 2.8.2 General Requirements – Breakdowns ..................................................... 2.4 2.8.3 Emission Inventories ................................................................................... 2.4 2.8.4 Permit: New and Modified Sources ......................................................... 2.4 3.0 EMISSIONS SUMMARY .................................................................................................3.1 EMISSION CALCULATIONS .......................................................................................... 3.1 EMISSION OFFSET CREDITS .......................................................................................... 3.2 4.0 REQUESTED CHANGES TO 2022 APPROVAL ORDER ...................................................4.1 5.0 AIR POLLUTION CONTROL EQUIPMENT INFORMATION .............................................5.1 6.0 AMBIENT AIR QUALITY ANALYSIS ...............................................................................6.1 LIST OF TABLES Table 1 Hourly NOx and CO Emission Factors ..................................................................... 1.2 Table 2 Emission Rates ........................................................................................................... 1.3 Table 3 Regulatory Applicability Summary .......................................................................... 2.1 Table 4 Total Net Change in Emissions ................................................................................. 3.1 LIST OF APPENDICES NOI APPLICATION FORMS ........................................................................ A.1 LAYOUT MAP ............................................................................................. B.1 HEBER LIGHT & POWER COMPANY NOTICE OF INTENT EMISSIONS INVENTORY ............................................................................ C.1 SOURCE SIZE DETERMINATION ................................................................. D.1 OFFSET REQUIREMENTS .............................................................................. E.1 MANUFACTURER SPECIFICATIONS ............................................................ F.1 MODELING REPORT ...................................................................................G.1 FEDERAL REQUIREMENTS DISCUSSION ..................................................... H.1 HEBER LIGHT & POWER COMPANY NOTICE OF INTENT i Executive Summary Heber Light & Power Company (Heber) is filing this Notice of Intent (NOI) for a modification to their current Approval Order (AO). Requested changes include the addition of a new generator at the 3,161 brake horsepower (bhp) Natural Gas Unit into its production fleet. Heber is also proposing to modify nitrogen oxides (NOx) and carbon monoxide (CO) hourly emission rates, and operating hours such of which are proposed to be grouped. Engine Unit#6 is to be removed. All the Research & Development engines are to be moved to a new structure and all engines currently housed in Plant#1 are moved to Plant#2 or #3. Lastly, Engine #5 and Engine #12 maximum kilowatt (KW) has been modified slightly. All engines are covered by 40 CFR Part 60, Subpart JJJJ (Standards of Performance for Stationary Spark Ignition Internal Combustion Engines) or 40 CFR 63, Subpart ZZZZ (National Emission Standard for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines). Heber will continue to be classified as a minor facility (area source) regarding hazardous air pollutant (HAP) thresholds of 10 tpy of a single HAP and 25 tpy for all aggregated HAP emissions. HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Introduction January 4, 2023 ce v:\2037\active\203722882\05_report_deliv\deliverables\hlp_noi_draft_010423.docx 1.1 1.0 INTRODUCTION OVERVIEW The Heber Light & Power Ray Farrell Internal Combustion Power Plant is located in Wasatch County, an attainment area for all pollutants. At the emission levels described in this NOI, the facility remains a minor source. The facility will now consist of two Caterpillar G3516C engines (1&2), three Caterpillar G3520C engines (4,7,8), one Caterpillar G3516DSL engine (5), one Caterpillar G3516H engine (11), one G3520H engine (12), one Caterpillar 3520DSL (13), one G3520H (14) and research & development engines. Additionally, there are two portable emergency generators will be stored at the Power Plant Facility in 2021. Table 1 below identifies the NOx and CO hourly emission rates. EMISSION SOURCES The maximum annual hour usage was estimated to establish the potential emissions. The following table illustrates the projected emission rates for all engines. All engine emission factors list in Table 1 are based on performance test results from various tests over the past handful of years with added levels of conservatism. The lb/hr values are derived from the tested parts per million (ppm) concentration and corresponding flow rate (dscf). Applicable conversion factors from EPA Method 19, Table within 40 CFR 60 Appendix A-7 were used. The conversion to g/kW-hr assumed the kW utilized during the tests and 453.5 g/lb. All other pollutants are based on AP-42 emission factors. HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Introduction January 4, 2023 ce v:\2037\active\203722882\05_report_deliv\deliverables\hlp_noi_draft_010423.docx 1.2 Table 1 Hourly NOx and CO Emission Factors Engine # Engine Type NOx CO lb/hr lb/hr 1 CAT 3516C 4.06 1.00 2 CAT 3516C 4.06 4 CAT 3520C 5.35 5 CAT G3516DSL 3.00 7 CAT 3520C 5.35 8 CAT 3520C 5.35 11 CAT 3516H 4.75 12 CAT 3520H 0.54 13 CAT G3520DSL 0.54 14 CAT G3520H 0.54 NG R&D Natural Gas 5.50/per unit Diesel R&D Diesel 2.50 Table 2 converts the emission factors into emission rates based on the maximum hours of operation. HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Introduction January 4, 2023 ce v:\2037\active\203722882\05_report_deliv\deliverables\hlp_noi_draft_010423.docx 1.3 Table 2 Emission Rates Engine # Engine Type Annual Hours1 NOx CO hr/yr T/yr T/yr 1 CAT 3516C 4,000 8.12 2.00 2 CAT 3516C 4 CAT 3520C 7,800 20.88 3.90 7 CAT 3520C 8 CAT 3520C 5 CAT G3516DSL 5,200 7.80 2.60 11 CAT 3516H 5,200 12.35 2.60 12 CAT 3520H 15,600 4.20 7.80 13 CAT G3520DSL 14 CAT G3520H R&D Natural Gas 8,000 22.00 4.00 R&D Diesel 5,000 6.25 2.50 Total 81.60 25.40 1. Engines 1,2 are a combined total, engines 4,7,8 are a combined total, engines 12-14 are a combined total because all three are equipped with a SCR that emitted NOx at the same rate. HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Regulatory Applicablity January 4, 2023 ce v:\2037\active\203722882\05_report_deliv\deliverables\hlp_noi_draft_010423.docx 2.1 2.0 REGULATORY APPLICABLITY A review of state and local air quality regulations is provided in Table 3. Each regulation is described in the following sections. Table 3 Regulatory Applicability Summary Program Description Regulatory Citation Applicable 2.1 National Ambient Air Quality Standards (NAAQS)- (dispersion modeling) 40 CFR Part 50 Yes 2.2 Title V Operating Permit 40 CFR Part 70 No 2.3 Air Pollutants (NESHAPs) 40 CFR Parts 61, 63 Yes 2.4 New Source Review (NSR) 40 CFR Part 52 No 2.5 New Source Performance Standards (NSPS) 40 CFR Part 60 Yes 2.6 Acid Rain Requirements 40 CFR Parts 72–78 No 2.7 Risk Management Programs for Chemical Accidental Release Prevention 40 CFR Part 68 No 2.8. State Rules 2.8.1 General Requirements UAC [R307-101] Yes 2.8.2 General Requirements - Breakdowns UAC [R307-107] Yes 2.8.3 Emission Inventories UAC [307-150] Yes 2.8.4 Permit Requirements for New and Modified Sources UAC [307-401] Yes NATIONAL AMBIENT AIR QUALITY STANDARDS (NAAQS) Primary National Ambient Air Quality Standards (NAAQS) are identified in 40 CFR Part 50 and define levels of air quality, which the United States Environmental Protection Agency (USEPA) deems necessary to protect the public health. Secondary NAAQS define levels of air quality, which the USEPA judges necessary to protect public welfare from any known or anticipated adverse effects of a pollutant. Examples of public welfare include protecting wildlife, buildings, national monuments, vegetation, visibility, and property values from degradation due to excessive emissions of criteria pollutants. Specific standards for the following pollutants have been promulgated by USEPA: PM10, SO2, NOx, CO, ozone, lead, and PM2.5. Heber emits PM10, PM2.5, SO2, NOx, CO, and VOCs, a precursor to ozone. The modification is a net increase in emissions. Those that do increase do not exceed HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Regulatory Applicablity January 4, 2023 ce v:\2037\active\203722882\05_report_deliv\deliverables\hlp_noi_draft_010423.docx 2.2 any modeling thresholds. However, 1-hr NO2 modeling was conducted based on past experience with UDAQ modeling staff regarding this facility. For details refer to Appendix G. TITLE V (PART 70) OPERATING PERMIT Title V of the Clean Air Act (CAA) created the federal operating permit program. These permitting requirements are codified in 40 CFR Part 70. These permits are required for major sources with a PTE (considering federally enforceable limitations) greater than 100 tpy for any criteria pollutant, 25 tpy for all hazardous air pollutants (HAPs) in aggregate, or 10 tpy of any single HAP. Heber is a minor source because the potential to emit of all criteria emissions does not exceed 100 tons per year, nor are the HAPs thresholds exceeded. Therefore, a Title V Operating permit is not needed. NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS (NESHAPS) Two sets of National Emissions Standards for Hazardous Air Pollutants (NESHAPs) may potentially apply to Heber. The first NESHAP regulations were developed under the auspices of the original CAA. These standards are codified in 40 CFR Part 61 and address a limited number of pollutants and industries. 40 CFR Part 61 regulations do not apply to this facility. Newer regulations are codified in 40 CFR Part 63 under the authority of the 1990 Clean Air Act Amendments (CAAA). These standards regulate HAP emissions from specific source categories and typically affect only major sources of HAPs, however some affect minor sources of HAPs. Part 63 regulations are frequently called Maximum Achievable Control Technology (MACT) standards. Major HAP sources have the PTE 10 tpy or more of any single HAP or 25 tpy or more of all combined HAP emissions. At the Heber facility, potential emissions of individual HAPs will be less than 10 tpy and combined HAP emissions will be less than 25 tpy. A review of all potential NESHAPS concluded that subpart ZZZZ is applicable to Heber. All currently operational engines with the exception of the engines deemed R&D by the manufacturer are subject to Subpart ZZZZ as they were constructed prior to June 12, 2006 or meet the requirements by complying with 40 CFR Part 60, Subpart JJJJ. All onsite engines meet any ZZZZ requirements by complying with 40 CFR 60, Subpart JJJJ requirements as stated in section 40 CFR 63.6590(c) All engines have been retrofitted with oxidation catalysts. The R&D engines have been deemed to be exempt from Subpart ZZZZ as they meet the definition of a test stand/cell. Documentation from UDAQ indicating as such is provided in Appendix H. HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Regulatory Applicablity January 4, 2023 ce v:\2037\active\203722882\05_report_deliv\deliverables\hlp_noi_draft_010423.docx 2.3 NEW SOURCE REVIEW (NSR) REQUIREMENTS Wasatch County is designated as an attainment area for all criteria pollutants. The prevention of significant deterioration (PSD) regulations codified in 40 CFR Part 52 could potentially apply to the proposed facility. The PSD rule applies to: (1) a new major source that has the potential to emit 100 tons per year or more for any criteria pollutant for a facility that is one of the 28 industrial source categories listed in 40 CFR § 52.21(b)(1)(i)(a); or (2) a new major source that has the potential to emit 250 tons per year or more if the facility is not on the list of industrial source categories; or (3) a modification to an existing major source that results in a net emission increase greater than a PSD significant emission rate as specified in 40 CFR § 52.21 (b)(23)(i); or (4) a modification to an existing minor source that is major in itself. The proposed permitting action does not trigger any PSD actions. NEW SOURCES PERFORMANCE STANDARDS (NSPS) New Source Performance Standards (NSPS) in 40 CFR Part 60 are applicable to new, modified, or reconstructed stationary sources that meet or exceed specified applicability thresholds. 40 CFR Part 60, Subpart JJJJ (Standards of Performance for Stationary Spark Ignition Internal Combustion Engines) is applicable to Heber due to the Caterpillar G3516DSL (#5), G3516H (#11), G3520H (#12), G3520DSL (#13) engines as well as the proposed new Caterpillar G3520H (#14). Engines #1, 2, 4, 5, 7,8, 11-13 and the new G3520H engine are natural gas fired and applicable to Subpart JJJJ. Heber will comply with all applicable requirements of the subpart. ACID RAIN REQUIREMENTS The acid rain requirements codified in 40 CFR Parts 72-78 apply only to utilities and other facilities that combust fossil fuel and generate electricity for wholesale or retail sale. The Title IV Acid Rain Program is for sources that use coal as a source of combustion and sources that produce over 25 MW of power. 40 CFR Part 72, Subpart 7, of the Acid Rain Program outlines exemption criteria for new sources. A unit with a name plate of 25 MW or less, does not burn any coal or coal- derived fuels and burns gaseous fuel with a sulfur content less than 0.05 percent. The largest unit on site is 3.5 MW. All units burn exclusively low-sulfur natural gas or diesel (R&D units). RISK MANAGEMENT PROGRAMS FOR CHEMICAL ACCIDENTAL RELEASE PREVENTION The facility is not subject to the Chemical Accidental Release Prevention Program and will not be required to develop a Risk Management Plan (RMP). Facilities that produce, process, store, or use any regulated toxic or flammable substance in excess of the thresholds listed in 40 CFR Part 68 must develop an RMP. The facility does not store any regulated toxic or flammable substances in excess of the applicable thresholds. An RMP is not necessary for this facility. HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Regulatory Applicablity January 4, 2023 ce v:\2037\active\203722882\05_report_deliv\deliverables\hlp_noi_draft_010423.docx 2.4 STATE RULES The Utah Division of Administrative Rules (DAR) promulgates several emissions regulations that apply to Heber in addition to those listed above. 2.8.1 General Requirements Utah Administrative Code (UAC) R307-101 provides general definitions, terms, abbreviations and references applicable to the upcoming Approval Order. Heber will comply with this requirement and refer to the rules where necessary. 2.8.2 General Requirements – Breakdowns UAC R307-107 indicates the applicable general requirements for breakdown events. Breakdowns will be reported within 24 hours of an incident with a written description of the event. Heber will comply with the procedures and requirements outlined in R307-107 and submit the necessary information and reports to UDAQ related to excess emissions due to startup, shutdown, scheduled maintenance, safety measures, upsets and breakdowns. 2.8.3 Emission Inventories UAC R307-150 establishes requirements for emission inventory submittals. Heber will comply with this rule where appropriate. 2.8.4 Permit: New and Modified Sources UAC R307-401 establishes the permitting requirements for any new and modified sources. Heber will comply with any permitting requirements as defined in the rule and that applies to the approval order. HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Emissions Summary January 4, 2023 ce v:\2037\active\203722882\05_report_deliv\deliverables\hlp_noi_draft_010423.docx 3.1 3.0 EMISSIONS SUMMARY EMISSION CALCULATIONS Emissions from all engines are calculated based on engines performance test results, manufacturer specifications and AP-42 emission factors. All performance test data was established in 2017-2022 for each engine excluding the R&D engines. The test results were used to establish emission estimates for CO and NOx only. The test values were then increased to establish the proposed hourly rates to add a level of conservatism and safety factor during future testing. Two of the R&D bays operate using natural gas and the third on diesel. The R&D bays can rotate numerous units in and out throughout the year. The diesel unit includes a D-NOx system for controls which produce lower emission NOx rates than the natural gas units. All natural gas units are configured with an oxidation catalyst. To ensure conservatism regarding potential NOx emissions, an aggregated total of 8,000 hr/yr were assumed for the natural gas and 5,000 hr/yr for the diesel units in the analysis. The emissions associated with each engine are the worst case potential based on representative engine kW (mostly consistent with previous AO with a few minor updates) and source tests. All other pollutants (PM10, SO2, VOC and HAPs) estimates were derived using manufacturer specifications, AP-42, Section 3.2 and 3.4 for natural gas-fired and diesel-fired engines, respectively. The comparison of current (2022 AO) permitted emissions to projected PTE emissions from all engines is given in Table 4. The primary changes are the inclusion of the new CAT G3520H engine #14, the addition of SCR control to engines and #11-13 and modification to hourly NOx/CO rates for future testing and annual hours of operations. Table 4 Total Net Change in Emissions Source Total Facility Current Emission Rate1 (tpy) Total Facility Proposed Emission Rate (tpy) Change (tpy) PM2.5 3.12 2.61 -0.51 PM10 3.21 2.69 -0.52 NOx 86.86 81.71 -5.15 SO2 0.37 0.41 0.04 CO 6.15 25.43 19.28 VOC 28.14 28.88 0.74 HAPs 12.80 14.30 1.50 Total 140.65 156.03 15.38 1. PTE from DAQE-AN108840012-22 issued June 6th, 2022. HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Emissions Summary January 4, 2023 ce v:\2037\active\203722882\05_report_deliv\deliverables\hlp_noi_draft_010423.docx 3.2 EMISSION OFFSET CREDITS Emission offset credits are not required as Wasatch county is an attainment area for all pollutants. HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Requested Changes to 2022 Approval Order January 4, 2023 ce v:\2037\active\203722882\05_report_deliv\deliverables\hlp_noi_draft_010423.docx 4.1 4.0 REQUESTED CHANGES TO 2022 APPROVAL ORDER Heber Light & Power is requesting that the following permit conditions be modified from the current 2022 Approval Order, DAQE-AN108840012-22. • Permit Condition II.A.5 – The maximum rating of Unit #5 is proposed to be reduced from 1620 kW to 1550 kW. • Permit Condition II.A.6 – Unit #6 has been removed from the facility and it should be removed from the permit. • Permit Condition II.A.10 – The maximum rating of Unit #12 is proposed to be increased from 2150 kW to 2220 kW. • Permit Condition II.B.1.b – The aggregated total form Engines #1 and #2 are proposed to be updated to 4,000 hours. Engines 4,7, and 8 are proposed to be aggregated together to 7,800 hours as they are the same engine model and size. Engines 12-14 are also proposed to be aggregated to 15,600 hours. Each engine will be equipped with a SCR from Safety Power with an identical NOx exhaust emission rate. Engine #5 is proposed to be increased to 5,200 hours per year. Engine #11 is proposed to be reduced to 5,200 hours annually. • Permit Condition II.B.2.a – The hourly CO limits for all engines is proposed to be increased to 1.0 lb/hr. The NOx hourly emission limits are proposed to be updated as follows: o Units #1 and 2: 4.06 lb/hr o Units #4, 7 and 8: 5.35 lb/hr o Unit #5: 3.00 lb/hr o Unit #11: 4.75 lb/hr o Unit #12-14: 0.54 lb/hr o R&D NG Engines: 5.50 lb/hr o R&D Diesel Engines: 2.50 lb/hr HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Air Pollution Control Equipment Information January 4, 2023 ce v:\2037\active\203722882\05_report_deliv\deliverables\hlp_noi_draft_010423.docx 5.1 5.0 AIR POLLUTION CONTROL EQUIPMENT INFORMATION Natural Gas-fired Generators The UDAQ currently has established the general BACT guidelines for NOx emissions from internal combustions engines to be ≤1.0 g/hp-hr or compliant with 40 CFR Part 60 Subpart JJJJ Table 1 standards for non-emergency SI units. The engines covered in this NOI are below this emissions level due to the SCR technology associated with the Caterpillar engines. These engines will meet the BACT requirement for NOx without additional pollution control devices being installed. Additionally, the BACT Clearinghouse was evaluated. Several determinations were evaluated for Process Code 17.130 or natural gas internal combustion engines with greater than 600 hp. The State of Michigan issued a recent determination for a non-emergency unit on May 22, 2019, to Michigan State University. The NOx BACT was set to 0.5 g/hp-hr. Other determinations in California (2017 Gold Coast Packaging) and Kansas (2016 Mid-Kansas Electric Company) issued limits of 5.0 ppmv and 2.13 lb/hr, respectively. Lastly, a determination in 2013 for the South Texas Electric Cooperative issued a NOx limit of 0.084 g/hp-hr. As illustrated in the emission calculations (Appendix C), Heber is proposing an emission factor of less than all of the above at 0.077 g/hp-hr (safety factor added to reach proposed hourly limit of 0.54 lb/hr) for the three engines adding an SCR(existing #12 and 13 and the proposed new #14). Therefore, the proposed limit meets BACT for NOx. Subpart JJJJ limits CO and VOC to 2.0 and 0.7 g/hp-hr, respectively. The determinations above also limited CO and VOC to the following: • Michigan State: CO 0.3 g/hp-hr; VOC 11 lb/hr • Gold Coast Packaging: CO 54 ppmv; VOC 25 ppmv • Mid-Kansas Electric Company: CO 3.86 lb/hr; VOC 5.82 lb/hr • South Texas Electric Coop: CO 0.3 g/hp-hr; VOC 0.3 g/hp-hr The three engines adding the SCR will meet all of the previous BACT determinations and Subpart JJJJ standards. The proposed limit amongst the three is a maximum of 0.143 g/hp-hr for CO (safety factor added to reach proposed hourly limit of 1.0 lb/hr) and 0.0525 g/hp-hr for VOC. In addition to good combustion techniques, and the three installed SCRs, OCs are currently installed on all units. The OC/SCRs will reduce the CO and formaldehyde emissions by 93% and 85% (75% for engine #12). VOCs will be reduced by 50%. Manufacturer specifications regarding the OC/SCR control is available in Appendix F. HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Ambient Air Quality Analysis January 4, 2023 ce v:\2037\active\203722882\05_report_deliv\deliverables\hlp_noi_draft_010423.docx 6.1 6.0 AMBIENT AIR QUALITY ANALYSIS 1-hr NO2 modeling was conducted. Refer to Appendix G for specific details. Hazardous pollutants were not modeled because all engines are subject to NESHAP federal regulations. Per Utah Division of Air Quality correspondence with Dave Prey, HAP modeling is exempted when subject to a 40 CFR Part 63 Subpart (June 2, 2021, email from D. Prey) APPENDICIES HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Appendix A NOI Application Forms January 4, 2023 A.1 NOI APPLICATION FORMS Utah Division of Air Quality New Source Review Section Company_______________________ Site/Source_____________________ Form 11 Date___________________________ Internal Combustion Engines Equipment Information 1. Manufacturer: __________________________ Model no.: __________________________ The date the engine was constructed or reconstructed ________________________ 2. Operating time of Emission Source: average maximum ______ Hours/day ______ Hours/day Days/week Days/week ______ Weeks/year ______ Weeks/year 3. Manufacturer's rated output at baseload, ISO hp or Kw Proposed site operating range _____________________________ hp or Kw Gas Firing 4. Are you operating site equipment on pipeline quality natural gas: □ Yes □ No 5. Are you on an interruptible gas supply: □ Yes □ No If "yes", specify alternate fuel: _______________________________ 6. Annual consumption of fuel: _____________________________ MMSCF/Year 7. Maximum firing rate: _____________________________ BTU/hr 8. Average firing rate: _____________________________ BTU/hr Oil Firing 9. Type of oil: Grade number □ 1 □ 2 □ 4 □ 5 □ 6 Other specify ___________ 10. Annual consumption: ______________ gallons 11. Heat content:______________ BTU/lb or ______________ BTU/gal 12. Sulfur content:___________% by weight 13. Ash content: ____________% by weight 14. Average firing rate: gal/hr 15. Maximum firing rate: gal/hr 16. Direction of firing: □ horizontal □ tangential □ other: (specify) Page 1 of 4 Page 2 of 4 Internal Combustion Engine Form 11 (Continued) Operation 17. Application: □ Electric generation ______ Base load ______ Peaking □ Emergency Generator □ Driving pump/compressor □ Exhaust heat recovery □ Other (specify) ________________________ 18. Cycle □ Simple cycle □ Regenerative cycle □ Cogeneration □ Combined cycle Emissions Data 19. Manufacturer’s Emissions in grams per hour (gr/hp-hr): _______ NOX _______ CO ______ VOC _______ Formaldehyde 20. Attach manufacturer's information showing emissions of NOx, CO, VOC, SOx, CH2O, PM10, PM 2.5 , CO2, CH4 and N2O for each proposed fuel at engine loads and site ambient temperatures representative of the range of proposed operation. The information must be sufficient to determine maximum hourly and annual emission rates. Annual emissions may be based on a conservatively low approximation of site annual average temperature. Provide emissions in pounds per hour and except for PM10 and PM2.5 parts per million by volume (ppmv) at actual conditions and corrected to dry, 15% oxygen conditions. Method of Emission Control: □ Lean premix combustors □ Oxidation catalyst □ Water injection □ Other (specify)____________ □ Other low-NOx combustor □ SCR catalyst □ Steam injection Additional Information 21. On separate sheets provide the following: A. Details regarding principle of operation of emission controls. If add-on equipment is used, provide make and model and manufacturer's information. Example details include: controller input variables and operational algorithms for water or ammonia injection systems, combustion mode versus engine load for variable mode combustors, etc. B. Exhaust parameter information on attached form. C. All calculations used for the annual emission estimates must be submitted with this form to be deemed complete. D. All formaldehyde emissions must be modeled as per Utah Administrative Code R307-410-5 using SCREEN3. E. If this form is filled out for a new source, forms 1 and 2 must be submitted also. Page 4 of 4 INTERNAL COMBUSTION ENGINE FORM 11 (continued) EMISSION SOURCES Review of applications and issuance of permits will be expedited by supplying all necessary information requested on this form. AIR CONTAMINANT DATA EMISSION POINT DISCHARGE PARAMETERS STACK SOURCES (7) EMISSION POINT (1) CHEMICAL COMPOSITION OF TOTAL STREAM AIR CONTAMINANT EMISSION RATE UTM COORDINATES OF EMISSION PT. (6) EXIT DATA NUMBER NAME COMPONENT OR AIR CONTAMINANT NAME (2) CONC. (%V) (3) LB/HR (4) TONS/YR (5) ZONE EAST (METERS) NORTH (METERS) HEIGHT ABOVE GROUND (FT) HEIGHT ABOVE STRUCT. (FT) DIA. (FT) VELO. (FPS) TEMP. (OF) GROUND ELEVATION OF FACILITY ABOVE MEAN SEA LEVEL _______________ feet. UTAH AIR CONSERVATION BOARD STANDARD CONDITIONS ARE 68O F AND 14.7 PSIA. General Instructions for this form. 1. Identify each emission; point with a unique number for this plant site on plot plan, previous permits and emission inventory questionnaire. Limit emission point number to 8 character spaces. For each emission point use as many lines as necessary to list air contaminant data. Typical emission point names are: heater, vent, boiler, tank, reactor, separator, baghouse, fugitive, etc. Abbreviations are OK. 2. Typical component names are: air, H2O, nitrogen, oxygen, CO2, CO, NOx, SOx, hexane, particulate matter (PM10 and PM2.5), etc. Abbreviations are OK. 3. Concentration data is required for all gaseous components. Show concentration in volume percent of total gas stream. 4. Pounds per hour. (#/hr) is maximum emission rate expected by applicant. 5. Tons per year (T/Y) is annual maximum emission rate expected by applicant, which takes into account process operating schedule. 6. As a minimum applicant must furnish a facility plot plan drawn to scale showing a plant benchmark, latitude and longitude correct to the nearest second for the benchmark, and all emission points dimensioned with respect to the benchmark. Please show emission point UTM coordinates if known. 7. Supply additional information as follows if appropriate: (a) Stack exit configuration other than a round vertical stack. Show length and width for a rectangular stack. Indicate if horizontal discharge with a note. (b) Stack's height above supporting or adjacent structures if structure is within three "stack heights above ground" of stack. HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Appendix B Layout MAP January 4, 2023 B.1 LAYOUT MAP HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Appendix C Emissions Inventory January 4, 2023 C.1 EMISSIONS INVENTORY Pollutants - Current Emissions lb/hr T/yr SOx 0.17 0.37 VOC 14.74 28.14 PM10 1.17 3.21 PM2.5 1.14 3.12 NOx 49.87 86.86 CO 3.60 6.15 HAPs 7.07 12.80 GHG1 25,349 44,630 1. Metric tons of CO2e Pollutants - Proposed Update lb/hr T/yr SOx 0.18 0.41 VOC 13.84 30.16 PM10 1.17 2.69 PM2.5 1.14 2.61 NOx 43.79 81.71 CO 12.58 25.43 HAPs 6.51 14.30 GHG1 28,921 59,732 1. Metric tons of CO2e 4-Stroke Lean-Burn Engines AP-42 Chapter 3 Section 3.2 Table 2 Eng 5 Eng 11 Eng 12 Eng 13 Eng 14 Engine 1 Engine 2 Engine 4 G3516 Engine 7 Engine 8 3516H G3520H 3520DSL4 G35206 R&D NG KW 1350 1350 1850 1550 1850 1850 1750 2200 2631 2550 2700 MMBtu/hr 12.7 12.7 17.4 14.5 17.4 17.4 16.4 20.6 24.7 23.9 25.3 Hours/yr 2000 2000 2600 5200 2600 2600 5200 5200 5200 5200 8000 lb/MMBtu lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr lb/hr Total SO2 5.88E-04 7.45E-03 7.45E-03 1.02E-02 8.55E-03 1.02E-02 1.02E-02 9.65E-03 1.21E-02 1.45E-02 1.41E-02 1.49E-02 0.12 VOC1-6 1.18E-01 0.75 0.75 1.02 0.48 1.02 1.02 1.11 0.81 0.84 0.75 1.49 10.06 PM10 7.71E-05 9.76E-04 9.76E-04 1.34E-03 1.12E-03 1.34E-03 1.34E-03 1.27E-03 1.59E-03 1.90E-03 1.84E-03 1.95E-03 1.56E-02 PM2.5 7.71E-05 9.76E-04 9.76E-04 1.34E-03 1.12E-03 1.34E-03 1.34E-03 1.27E-03 1.59E-03 1.90E-03 1.84E-03 1.95E-03 1.56E-02 1,3-Butadiene 2.67E-04 1.69E-03 1.69E-03 2.32E-03 1.94E-03 2.32E-03 2.32E-03 2.19E-03 2.75E-03 3.29E-03 3.19E-03 3.38E-03 2.71E-02 2,2,4-Trimethylpentane 2.50E-04 1.58E-03 1.58E-03 2.17E-03 1.82E-03 2.17E-03 2.17E-03 2.05E-03 2.58E-03 3.08E-03 2.99E-03 3.17E-03 2.54E-02 Acetaldehyde 8.36E-03 5.29E-02 5.29E-02 7.25E-02 6.08E-02 7.25E-02 7.25E-02 6.86E-02 8.63E-02 1.03E-01 1.00E-01 1.06E-01 8.48E-01 Acrolein 5.14E-03 3.25E-02 3.25E-02 4.46E-02 3.74E-02 4.46E-02 4.46E-02 4.22E-02 5.30E-02 6.34E-02 6.15E-02 6.51E-02 5.21E-01 Benzene 4.40E-04 2.79E-03 2.79E-03 3.82E-03 3.20E-03 3.82E-03 3.82E-03 3.61E-03 4.54E-03 5.43E-03 5.26E-03 5.57E-03 4.46E-02 Biphenyl 2.12E-04 1.34E-03 1.34E-03 1.84E-03 1.54E-03 1.84E-03 1.84E-03 1.74E-03 2.19E-03 2.62E-03 2.54E-03 2.68E-03 2.15E-02 Formaldehyde 5.28E-02 3.34E-01 3.34E-01 4.58E-01 3.84E-01 4.58E-01 4.58E-01 5.45E-01 3.78E-01 2.78E-01 2.82E-01 6.69E-01 4.58E+00 Methanol 2.50E-03 1.58E-02 1.58E-02 2.17E-02 1.82E-02 2.17E-02 2.17E-02 2.05E-02 2.58E-02 3.08E-02 2.99E-02 3.17E-02 2.54E-01 Hexane 1.11E-03 7.03E-03 7.03E-03 9.63E-03 8.07E-03 9.63E-03 9.63E-03 9.11E-03 1.15E-02 1.37E-02 1.33E-02 1.41E-02 1.13E-01 Toluene 4.08E-04 2.58E-03 2.58E-03 3.54E-03 2.97E-03 3.54E-03 3.54E-03 3.35E-03 4.21E-03 5.03E-03 4.88E-03 5.17E-03 4.14E-02 Xylene 1.84E-04 1.16E-03 1.16E-03 1.60E-03 1.34E-03 1.60E-03 1.60E-03 1.51E-03 1.90E-03 2.27E-03 2.20E-03 2.33E-03 1.87E-02 T/yr T/yr T/yr T/yr T/yr T/yr T/yr T/yr T/yr T/yr T/yr Total SO2 7.45E-03 7.45E-03 1.33E-02 2.22E-02 1.33E-02 1.33E-02 2.51E-02 3.15E-02 3.77E-02 3.66E-02 5.96E-02 0.27 VOC 0.75 0.75 1.33 1.25 1.33 1.33 2.89 2.11 2.19 1.96 5.98 21.86 PM10 9.76E-04 9.76E-04 1.74E-03 2.91E-03 1.74E-03 1.74E-03 3.29E-03 4.14E-03 4.95E-03 4.79E-03 7.81E-03 3.51E-02 PM2.5 9.76E-04 9.76E-04 1.74E-03 2.91E-03 1.74E-03 1.74E-03 3.29E-03 4.14E-03 4.95E-03 4.79E-03 7.81E-03 3.51E-02 1,3-Butadiene 1.69E-03 1.69E-03 3.01E-03 5.05E-03 3.01E-03 3.01E-03 5.70E-03 7.16E-03 8.56E-03 8.30E-03 1.35E-02 6.07E-02 2,2,4-Trimethylpentane 1.58E-03 1.58E-03 2.82E-03 4.73E-03 2.82E-03 2.82E-03 5.33E-03 6.71E-03 8.02E-03 7.77E-03 1.27E-02 5.68E-02 Acetaldehyde 5.29E-02 5.29E-02 9.43E-02 1.58E-01 9.43E-02 9.43E-02 1.78E-01 2.24E-01 2.68E-01 2.60E-01 4.23E-01 1.90E+00 Acrolein 3.25E-02 3.25E-02 5.80E-02 9.71E-02 5.80E-02 5.80E-02 1.10E-01 1.38E-01 1.65E-01 1.60E-01 2.60E-01 1.17E+00 Benzene 2.79E-03 2.79E-03 4.96E-03 8.32E-03 4.96E-03 4.96E-03 9.39E-03 1.18E-02 1.41E-02 1.37E-02 2.23E-02 1.00E-01 Biphenyl 1.34E-03 1.34E-03 2.39E-03 4.01E-03 2.39E-03 2.39E-03 4.52E-03 5.69E-03 6.80E-03 6.59E-03 1.07E-02 4.82E-02 Formaldehyde 3.34E-01 3.34E-01 5.96E-01 9.98E-01 5.96E-01 5.96E-01 1.42E+00 9.82E-01 7.24E-01 7.34E-01 2.67E+00 9.98E+00 Methanol 1.58E-02 1.58E-02 2.82E-02 4.73E-02 2.82E-02 2.82E-02 5.33E-02 6.71E-02 8.02E-02 7.77E-02 1.27E-01 5.68E-01 Hexane 7.03E-03 7.03E-03 1.25E-02 2.10E-02 1.25E-02 1.25E-02 2.37E-02 2.98E-02 3.56E-02 3.45E-02 5.62E-02 2.52E-01 Toluene 2.58E-03 2.58E-03 4.60E-03 7.71E-03 4.60E-03 4.60E-03 8.71E-03 1.09E-02 1.31E-02 1.27E-02 2.07E-02 9.28E-02 Xylene 1.16E-03 1.16E-03 2.08E-03 3.48E-03 2.08E-03 2.08E-03 3.93E-03 4.94E-03 5.90E-03 5.72E-03 9.32E-03 4.18E-02 14.27 1. Each engine (1,2,4,7,8) has an oxidation catalyst installed and each has a VOC and HAPs control efficiency of 50%. The total lb/hr and t/yr calculation is multiplied by 50% to account for the control device. 2. 3516H and 3520H have a control efficiency of VOCs and HAPs of 50%. 3. The R&D engines are assumed to have 50% control of VOC and HAPs. 4. 3520DSL has a site specific VOC emission rate of 0.29 g/kw-hr, Formaldehyde of 0.32 g/kw-hr; VOC and all HAPs except HCOH (see footnote 6) assume 50% control from OC. 5. Engine 5 has an oxycat with 50% control efficiency for VOC/HAPs; Also the VOC emission rate is derived from the CAT spec sheet in g/hp-hr 6. Engines 12-14 are now equipped with an SCR and OC that controls VOCs at 50% and formaldehyde at 75-85%. Large Diesel Engines AP-42 Chapter 3 Section 3.4 Tables 1 & 2 R&D Engs MMBtu/hr 18.50 Hours/yr 5000 Emission factor lb/hr Total SOx1 0.00809*S lb/hp-hr 5.70E-02 0.06 VOC 7.05E-04 lb/hp-hr 3.31 3.31 PM10 5.73E-02 lb/MMBtu 1.06 1.06 PM2.5 5.56E-02 lb/MMBtu 1.03 1.03 HAPs Emission factor Formaldehyde 7.89E-05 lb/MMBtu 1.46E-03 1.46E-03 Acetaldehyde 2.52E-05 lb/MMBtu 4.66E-04 4.66E-04 Toluene 2.81E-04 lb/MMBtu 5.20E-03 0.01 Xylene 1.93E-04 lb/MMBtu 3.57E-03 0.00 Acrolein 7.88E-06 lb/MMBtu 1.46E-04 1.46E-04 T/yr Total T/yr SOx 1.42E-01 0.14 VOC 8.27 8.27 PM10 2.65 2.65 PM2.5 2.57 2.57 HAPs Formaldehyde 3.65E-03 3.65E-03 Acetaldehyde 1.17E-03 1.17E-03 Toluene 1.30E-02 1.30E-02 Xylene 8.93E-03 8.93E-03 Acrolein 0.0003645 3.64E-04 0.03 1. 'S' refers to the percentage of sulfur assumed in the distillate fuel. Heber Light and Power uses ultra low sulfur which is assumed to be 15ppm or 0.0015% 2023 2024 2025 2026 2027 2028 NOx CO NOx T/yr CO T/yr NOx T/yr CO T/yr NOx T/yr CO T/yr NOx T/yr CO T/yr NOx T/yr CO T/yr NOx T/yr CO T/yr Average (T/yr) Maximum (T/yr) Average (T/yr) Maximum (T/yr) Engine 1 2000 2000 2000 2000 2000 2000 4.06 1.00 4.06 1.00 4.06 1.00 4.06 1.00 4.06 1.00 4.06 1.00 4.06 1.00 4.06 4.06 1.00 1.00 Engine 2 2000 2000 2000 2000 2000 2000 4.06 1.00 4.06 1.00 4.06 1.00 4.06 1.00 4.06 1.00 4.06 1.00 4.06 1.00 4.06 4.06 1.00 1.00 Engine 4 2600 2600 2600 2600 2600 2600 5.35 1.00 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 6.96 1.30 1.30 Engine 5 5200 5200 5200 5200 5200 5200 3.00 1.00 7.80 2.60 7.80 2.60 7.80 2.60 7.80 2.60 7.80 2.60 7.80 2.60 7.80 7.80 2.60 2.60 Engine 7 2600 2600 2600 2600 2600 2600 5.35 1.00 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 6.96 1.30 1.30 Engine 8 2600 2600 2600 2600 2600 2600 5.35 1.00 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 1.30 6.96 6.96 1.30 1.30 NG R&D Engines 8000 8000 8000 8000 8000 8000 5.50 1.00 22.00 4.00 22.00 4.00 22.00 4.00 22.00 4.00 22.00 4.00 22.00 4.00 22.00 22.00 4.00 4.00 Diesel R&D Engines w/ urea 5000 5000 5000 5000 5000 5000 2.50 1.00 6.25 2.50 6.25 2.50 6.25 2.50 6.25 2.50 6.25 2.50 6.25 2.50 6.25 6.25 2.50 2.50 Engine 11 3516H 5200 5200 5200 5200 5200 5200 4.75 1.00 12.35 2.60 12.35 2.60 12.35 2.60 12.35 2.60 12.35 2.60 12.35 2.60 12.35 12.35 2.60 2.60 Engine 12 3520H 5200 5200 5200 5200 5200 5200 0.54 1.00 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 1.40 2.60 2.60 Engine 13 3520DSL 5200 5200 5200 5200 5200 5200 0.54 1.00 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 1.40 2.60 2.60 Engine 14 G3520 5200 5200 5200 5200 5200 5200 0.54 1.00 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 2.60 1.40 1.40 2.60 2.60 Totals 50800.0 50800.0 50800.0 50800.0 50800.0 50800.0 41.5 12.0 81.6 25.4 81.6 25.4 81.6 25.4 81.6 25.4 81.6 25.4 81.6 25.4 81.6 81.6 25.4 25.4 Max NOx Emissions Max CO Emissions Current Facility Engines 51.94 16.30 R&D Engines 28.25 6.50 CAT G3520 1.40 2.60 81.60 25.40 2024 2025 Heber Light & Power 6 Year Emission Forecast lb/hr (Test Results)2023 2024 2025 2026 NOx T/yr CO T/yr Equipment Details Rating 80 hp = (60 kw) Operational Hours 100 hours/year Sulfur Content 15 ppm or 0.0015% Criteria Pollutant Emission Standards (g/hp-hr) Emission Factor (lb/hp-hr) Emission Rate (lbs/hr) Emission Total (tons/year)Reference NOX 5.8022 1.03 0.05 CO 1.541 0.27 0.01 PM10 0.24 0.04 0.00 PM2.5 0.24 0.04 0.00 VOC 2.51E-03 0.20 0.01 SO2 1.21E-05 0.00 0.00 AP-42 Table 3.4-1 HAP 0.00 0.00 See Below Green House Gas Pollutant Global Warming Potential Emission Factor (lb/hp-hr) Emission Rate (lbs/hr) Emission Total (tons/year)Reference CO2 (mass basis)1 1.15 92 5 Methane (mass basis)25 0 0 CO2e 5 Hazardous Air Pollutant Emission Rate (lbs/hr) Emission Total (tons/year)Reference Benzene 9.33E-04 5.24E-04 2.62E-05 Toluene 4.09E-04 2.30E-04 1.15E-05 Xylenes 2.85E-04 1.60E-04 8.01E-06 1,3-Butadiene 3.91E-05 2.20E-05 1.10E-06 Formaldehyde 1.18E-03 6.63E-04 3.32E-05 Acetaldehyde 7.67E-04 4.31E-04 2.16E-05 Acrolein 9.25E-05 5.20E-05 2.60E-06 Naphthalene 8.48E-05 4.77E-05 2.38E-06 Acenaphthylene 5.06E-06 2.84E-06 1.42E-07 Acenaphthene 1.42E-06 7.98E-07 3.99E-08 Fluorene 2.92E-05 1.64E-05 8.21E-07 Phenanthrene 2.94E-05 1.65E-05 8.26E-07 Anthracene 1.87E-06 1.05E-06 5.26E-08 Fluoranthene 7.61E-06 4.28E-06 2.14E-07 Pyrene 4.78E-06 2.69E-06 1.34E-07 Benz(a)anthracene 1.68E-06 9.44E-07 4.72E-08 Chrysene 3.53E-07 1.98E-07 9.92E-09 Benzo(b)fluoranthene 9.91E-08 5.57E-08 2.79E-09 Benzo(k)fluoranthene 1.55E-07 8.71E-08 4.36E-09 Benzo(a)pyrene 1.88E-07 1.06E-07 5.28E-09 Indeno(1,2,3-cd)pyrene 3.75E-07 2.11E-07 1.05E-08 Dibenz(a,h)anthracene 5.83E-07 3.28E-07 1.64E-08 Benzo(g,h,l)perylene 4.89E-07 2.75E-07 1.37E-08 AP-42 Table 3.3-2, Table 3.4-3, & Table 3.4-4 (1,3-Butadiene will not popluate if the engine size is greater than 600 hp. AP-42 does not list 1,3- Butadiene for engines greater than 600 hp.) Diesel-Fired Engines AP-42 Table 3.3-1 & Table 3.4-1 Manufacturer Data, AP-42 Table 3.3-1, & Table 3.4-1 Emission Factor (lb/MMBtu) Emergency Engines should equal 100 hours of operation per year Page 5 of 7 Version 1.1 February 21, 2019 Equipment Details Rating 107 hp = (80 kw) Operational Hours 100 hours/year Sulfur Content 15 ppm or 0.0015% Criteria Pollutant Emission Standards (g/hp-hr) Emission Factor (lb/hp-hr) Emission Rate (lbs/hr) Emission Total (tons/year)Reference NOX 5.1992 1.23 0.06 CO 1.2864 0.30 0.02 PM10 0.23 0.05 0.00 PM2.5 0.23 0.05 0.00 VOC 2.51E-03 0.27 0.01 SO2 1.21E-05 0.00 0.00 AP-42 Table 3.4-1 HAP 0.00 0.00 See Below Green House Gas Pollutant Global Warming Potential Emission Factor (lb/hp-hr) Emission Rate (lbs/hr) Emission Total (tons/year)Reference CO2 (mass basis)1 1.15 123 6 Methane (mass basis)25 0 0 CO2e 6 Hazardous Air Pollutant Emission Rate (lbs/hr) Emission Total (tons/year)Reference Benzene 9.33E-04 6.99E-04 3.50E-05 Toluene 4.09E-04 3.07E-04 1.53E-05 Xylenes 2.85E-04 2.14E-04 1.07E-05 1,3-Butadiene 3.91E-05 2.93E-05 1.47E-06 Formaldehyde 1.18E-03 8.85E-04 4.42E-05 Acetaldehyde 7.67E-04 5.75E-04 2.88E-05 Acrolein 9.25E-05 6.93E-05 3.47E-06 Naphthalene 8.48E-05 6.36E-05 3.18E-06 Acenaphthylene 5.06E-06 3.79E-06 1.90E-07 Acenaphthene 1.42E-06 1.06E-06 5.32E-08 Fluorene 2.92E-05 2.19E-05 1.09E-06 Phenanthrene 2.94E-05 2.20E-05 1.10E-06 Anthracene 1.87E-06 1.40E-06 7.01E-08 Fluoranthene 7.61E-06 5.71E-06 2.85E-07 Pyrene 4.78E-06 3.58E-06 1.79E-07 Benz(a)anthracene 1.68E-06 1.26E-06 6.30E-08 Chrysene 3.53E-07 2.65E-07 1.32E-08 Benzo(b)fluoranthene 9.91E-08 7.43E-08 3.71E-09 Benzo(k)fluoranthene 1.55E-07 1.16E-07 5.81E-09 Benzo(a)pyrene 1.88E-07 1.41E-07 7.05E-09 Indeno(1,2,3-cd)pyrene 3.75E-07 2.81E-07 1.41E-08 Dibenz(a,h)anthracene 5.83E-07 4.37E-07 2.19E-08 Benzo(g,h,l)perylene 4.89E-07 3.67E-07 1.83E-08 Emission Factor (lb/MMBtu) AP-42 Table 3.3-2, Table 3.4-3, & Table 3.4-4 (1,3-Butadiene will not popluate if the engine size is greater than 600 hp. AP-42 does not list 1,3- Butadiene for engines greater than 600 hp.) Diesel-Fired Engines Emergency Engines should equal 100 hours of operation per year Manufacturer Data, AP-42 Table 3.3-1, & Table 3.4-1 AP-42 Table 3.3-1 & Table 3.4-1 Page 6 of 7 Version 1.1 February 21, 2019 GWP CH43 1 g/MMBtu 25 Greenhouse Gas Emissions CO23 53.06 kg/MMBtu 1 N2O3 0.10 g/MMBtu 298 Emission Unit Rating (MMBtu/hr)CO2 N2O CH4 CO2e1 Engine 1 12.66 1478 3.E-03 2.79E-02 1480 Engine 2 12.66 1478 3.E-03 2.79E-02 1480 CH43 3 g/MMBtu Engine 4 17.35 2026 4.E-03 3.83E-02 2028 CO23 73.96 kg/MMBtu G35164 14.54 2208 3.E-03 3.21E-02 2210 N2O3 0.60 g/MMBtu Engine 7 17.35 2026 4.E-03 3.83E-02 2028 Engine 8 17.35 2026 4.E-03 3.83E-02 2028 3516H4 16.42 2415 4.E-03 3.62E-02 2417 G3520H4 20.64 2884 5.E-03 4.55E-02 2886 3520DSL4 24.68 3404 5.E-03 5.44E-02 3407 G35204 23.92 2760 5.E-03 5.27E-02 2762 R&D NG 25.33 2956 6.E-03 5.58E-02 2959 R&D Engs 18.50 3010 2.E-02 1.22E-01 3021 Diesel Emergency 15 92 0.00E+00 92 Diesel Emergency 25 123 0.00E+00 123 Total 28,886 0.07 0.57 28,921 Rating (MMBtu/hr)CO2 N2O CH4 CO2e1,2 Engine 1 12.66 1340.99 2.53E-03 0.03 1342.38 Engine 2 12.66 1340.99 0.00 0.03 1342.38 Engine 4 17.35 2388.96 0.00 0.05 2391.43 G3516 14.54 5209.08 0.01 0.08 5213.22 Engine 7 17.35 2388.96 0.00 0.05 2391.43 Engine 8 17.35 2388.96 0.00 0.05 2391.43 3516H 16.42 5695.29 0.01 0.09 5699.97 G3520H 20.64 6801.88 0.01 0.11 6807.76 3520DSL 24.68 8029.58 0.01 0.13 8036.61 G3520 23.92 6509.09 0.01 0.12 6515.90 R&D NG 25.33 10727.95 0.02 0.20 10739.05 R&D Engs 18.50 6827.03 0.06 0.28 6850.50 Diesel Emergency 1 4.19 0.00 4.19 Diesel Emergency 2 5.59 0.00 5.59 Total 59,659 0.15 1.19 59,732 1. The total CO2e was calculated using global warming potentials from 40 CFR Part 98, Subpart A, Table A-1 2. The conversion from pounds to metric tons is 2204.6 lb to each metric ton. 3. Emission factor are from EPA GHG Inventories. https://www.epa.gov/sites/production/files/2018-03/documents/emission-factors_mar_2018_0.pdf 4. G3516, 3516H, G3520H 3520DSL and G3520 has a CO2 emission rate of 461 g/hp-hr, 399 g/hp-hr, 401 g/hp-hr, 587 g/kw-hr and 396 g/hp-hr, respectively 5. Used UDAQ emission calculation spreadsheet with uses AP-42, Table 3.3-1 pounds per hour metric tons per year HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Appendix D Source Size Determination January 4, 2023 D.1 SOURCE SIZE DETERMINATION *Meaning the source categories listed in R307-415-3 (2) “Major Source” (b)(i – xxvii) **”Non-fugitive emissions" means those emissions which could reasonably pass through a stack, chimney, vent, or other functionally equivalent opening (R307-401-2 “Fugitive emissions”). This document is intended for guidance and educational purposes only. It is not intended to include all possible scenarios. The DAQ NSR Section should be contacted for site specific requirements. Will annual potential emissions be less than 5 tons for any criteria pollutant, 500 pounds for any HAP, and 2,000 pounds for all HAPs combined? START Will annual potential emissions, including fugitives, be less than 100 tons for any criteria pollutant, 10 tons for any HAP, 25 tons for all HAPs combined, and 100,000 tons for CO2 equivalents? Is the source a listed* source category? END Are non-fugitive** annual potential emissions less than 100 tons for any criteria pollutant, 10 tons for any HAP, 25 tons for all HAPs combined, and 100,000 tons for CO2 equivalents? April 26, 2011 Source Type Determination YES NO YES YES NO NO YES NO 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 GARY R. HERBERT Governor GREG BELL Lieutenant Governor Department of Environmental Quality Amanda Smith Executive Director DIVISION OF AIR QUALITY Bryce Bird Acting Director Source is a Small Source (AO not required. Source may register as a small source, but registration is not required) Source is a Minor Source Source is a Title V Major Source. PSD may apply; contact a DAQ NSR Engineer for details. Heber is considered a Minor Source as annual potentials are below 100 tons for all criteria pollutants, 10 tons for any single HAP, 25 tons for all combined HAPs and 100,000 tonnes CO2e. HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Appendix E Offset Requirements January 4, 2023 E.1 OFFSET REQUIREMENTS Offset requirements are not necessary. Please see Section 3.2 of the application for details. HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Appendix F Manufacturer Specifications January 4, 2023 F.1 MANUFACTURER SPECIFICATIONS PRELIMINARY Safety Power Inc 26-5155 Spectrum Way Mississauga, On L4W 5A1 Canada www.safetypower.com Page 5 of 23 Confidential 99002010 Rev12.2 clean essential energy DESIGN PARAMETERS The design of the Safety Power emissions reduction system is based on the following conditions. Note: NOx is calculated as NO2. Table 1 – Engine Data Engine Type: CAT G3520H 2.1 Application Prime Engine Power 2261 ekW Exhaust Temperature 814 °F* Design Exhaust Flow Rate 14245 (CFM) Fuel Type Pipe Line NG Table 2 – Emissions Data at Full Engine Load Engine Option Emissions Catalyst Inlet Emissions Requirement Catalyst Outlet CAT G3520H 2.1 NOx (g/HP-h) 0.94 0.07 0.07 CO 1.21 (g/HP-h) 93 (% reduction) 93 (% reduction) VOC 0.20 (g/HP-h) 50 (% reduction) 50 (% reduction) HCHO 0.27 (g/HP-h) 85 (% reduction) 85 (% reduction) Notes: (1) The EPA does not treat methane and ethane as VOC’s. Safety Power can achieve a stated reduction of VOC’s based on the EPA definition assuming that the VOC’s manifest themselves as propene. (2) all emissions reductions are based on an average at steady state using SCAQMD method 100.1 for NOx and EPA Alternate Method 106 for CO and VOC’s or mutually agreed test method approved in writing. (3) if NMHC/VOC data isn’t provided 0.6 g/hp-hr is to be assumed (unless otherwise stated). Table 3 – SCR System Data Engine Option CAT G3520H 2.1 Max. Ammonia Slip @ 15% O2 8 ppm Urea Consumption - 32.5% solution (+/- 15%) 1.4 USG/hr System Pressure Loss 14.0" WC System Inlet/Outlet ANSI Flange Inches 22/22 HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Appendix G Modeling Report January 4, 2023 G.1 MODELING REPORT Air Quality Modeling Report – Heber City Light & Power – Notice of Intent Heber Light and Power 1-hr NO2 Modeling Prepared for: Utah Dept. of Environmental Quality Division of Air Quality PO Box 144820 Salt Lake City, Utah 84114-482 Phone: 801-536-4000 Prepared by: Stantec Consulting Services 727 East Riverpark Lane, Suite 150 Boise, ID 83706 Contact: Eric Clark Ph: 208-388-4324 December 14, 2022 Sign-off Sheet This document, entitled Air Quality Modeling Report – Heber City Light & Power – Notice of Intent was prepared by Stantec Consulting Services Inc. (“Stantec”) for the account of Rulon Harper (the “Client”). Any reliance on this document by any third party is strictly prohibited. The material in it reflects Stantec’s professional judgment in light of the scope, schedule and other limitations stated in the document and in the contract between Stantec and the Client. The opinions in the document are based on conditions and information existing at the time the document was published and do not take into account any subsequent changes. In preparing the document, Stantec did not verify information supplied to it by others. Any use which a third party makes of this document is the responsibility of such third party. Such third party agrees that Stantec shall not be responsible for costs or damages of any kind, if any, suffered by it or any other third party as a result of decisions made or actions taken based on this document. Prepared by (signature) Eric Clark, Project Engineer, PE Reviewed by (signature) Daniel Heiser, Manager, Engineering, PE Air Quality Modeling Report – Heber City Light & Power – Notice of Intent Table of Contents 1.0 PURPOSE ......................................................................................................................1.1 1.1 PROCESS DESCRIPTION .............................................................................................. 1.1 2.0 MODEL DESCRIPTION/JUSTIFICATION ........................................................................2.1 3.0 EMISSION AND SOURCE DATA ...................................................................................3.1 3.1 EMISSION SOURCES .................................................................................................... 3.1 3.1.1 Generators ................................................................................................ 3.1 3.2 SOURCE CHARACTERIZATION .................................................................................... 3.2 3.2.1 Operational Schedule .............................................................................. 3.2 3.2.2 Point Sources ............................................................................................. 3.2 4.0 RECEPTOR NETWORK ...................................................................................................4.1 5.0 ELEVATION DATA ........................................................................................................5.1 6.0 METEOROLOGICAL DATA ...........................................................................................6.1 7.0 LAND USE CLASSIFICATION ........................................................................................7.1 8.0 BACKGROUND CONCENTRATIONS............................................................................8.1 9.0 RESULTS ........................................................................................................................9.2 9.1 APPLICABLE LIMITS ...................................................................................................... 9.2 9.2 IMPACT ........................................................................................................................ 9.2 9.2.1 NO2 Results ................................................................................................ 9.2 LIST OF TABLES Table 3-1 Generator Emissions ............................................................................................. 3.1 Table 3-1 Generator Stack Parameters .............................................................................. 3.2 Table 8-1 Monthly Background Values ............................................................................... 8.1 Table 9-1 PM10 Modeling Results .......................................................................................... 9.2 AIR QUALITY MODELING REPORT – Heber Light & Power – Notice of Intent Purpose December 14, 2022 Heber Light & Power Notice of Intent 1.1 1.0 PURPOSE This air quality modeling report documents the methodology used to prepare an air quality analysis in support of a Utah Division of Air Quality (UDAQ) Notice of Intent (NOI) application for a modification to their current AO. The facility will now consist of two Caterpillar G3516C LE lean- burn engines (1&2), three Caterpillar G3520C LE engines (4,7,8), one Caterpillar G3516 engine (5), one Caterpillar G3516H engine (11), one G3520H engine (12), one Caterpillar 3520DSL (13), and research & development engines. A new G2520H (14) engine generator is proposed to be added. Per previous interaction with UDAQ’s modeling personnel request, 1-hr NO2 analysis was performed and outlined below. Additionally, new buildings and are added to the property. All pertinent, updated modeling-related files are provided in electronic format. This includes AERMAP terrain information, BPIP downwash files, NED data and meteorological data. 1.1 PROCESS DESCRIPTION Heber City Light and Power consist of a number of natural gas operating fleet engines and a handful of research and development (R&D) units. The R&D engines are also natural gas-fired, and one is a diesel unit. The facility consists of two existing plant buildings (#2 and #3) and adjacent buildings. Plant #1 will be removed but included in the model as it is unclear when that demolition with occur. To the north of the property, a new office building will be added. Adjacent to the office building will be new bays, one of which will house the R&D units. Engines #1, 2 and 4 will be moved from Plant #1. Engine #2 will be moved to Plant #2. Engines #1 and #4 are moved to Plant #3. Plant #2 will now house Engines: #2, 5, 7 and 8. Plant #3 will house Engines #1, 4, 11-14. The R&D units will be housed in the new “Generator Room” to the north. For details, refer to Appendix B of the Notice of Intent. Air Quality Modeling Report – Heber City Light & Power – Notice of Intent Model Description/Justification December 14, 2022 ce v:\2037\active\203722882\05_report_deliv\deliverables\appendices\apendix g - modeling report\rpt_1hr_no2_modeling_report_121422.docx 2.1 2.0 MODEL DESCRIPTION/JUSTIFICATION AERMOD is one of the most frequently used regulatory dispersion models in the United States since it replaced ISCST3. Based on EPA guidance, AERMOD (version 22112) is the most appropriate of the EPA-approved models, given the site’s physical characteristics and the facility emission sources. AERMOD was applied as recommended in EPA’s Guideline on Air Quality Models and consistent with guidance in UDAQ’s Modeling Guidelines. The BPIP Prime building downwash algorithm was applied for the facility, including all adjacent buildings. Terrain data were processed consistent with the approved model protocol and EPA guidance for AERMAP. The United States Geological Survey (USGS) National Viewer was used to obtain appropriate National Elevation Dataset (NED) data to establish proper elevations. Five years of meteorological data from the Spanish Fork Airport (2004-2008) was provided by UDAQ for this analysis. In general, the AERMOD model application uses model source data consistent with the permit emission inventory. The model receptor network and model domain remain consistent with past modeling analyses for the Heber City Light & Power facility. Air Quality Modeling Report – Heber City Light & Power – Notice of Intent Emission And Source Data December 14, 2022 ce v:\2037\active\203722882\05_report_deliv\deliverables\appendices\apendix g - modeling report\rpt_1hr_no2_modeling_report_121422.docx 3.1 3.0 EMISSION AND SOURCE DATA Emission rates from the generators are based on Heber Light & Power test data with levels of safety added and provided below in Table 1. In correspondence with UDAQ modeling staff, only 1-hr NO2 compliance was modeled, thus only those rates are provided. Emission rate calculations are based on catalyst output as stated by Safety Power and to ensure conservatism and consistency with recent Utah Division of Air Quality (UDAQ), emission calculations assume seven minutes of uncontrolled startup emissions (specifically the SCR) and 53 controlled minutes for each hour of operation. While it is extremely unlikely that the SCR and other equipment would startup and shutdown frequently, this approach is very conservative regarding the potential hourly emissions. The uncontrolled NOx emission rate of 0.94 g/hp-hr was applied for seven minutes or 11.67% of an hour. The remaining 53 minutes (88.33%) applied 0.07 g/hp-hr. This equates to a total hourly rate of 0.1715 g/hp-hr. Based on the maximum brake horsepower of 3,161, the lb/hr applied to the model is 1.20 lb/hr. This rate was applied for engines #12-14 for each hour of the year. 3.1 EMISSION SOURCES Emissions sources at the Heber facility that were included in the model are listed below: • Generator Emissions 3.1.1 Generators Table 3-1 Generator Emissions Model # Engine Type NO2 lb/hr Rate Engine 1 3516C 4.06 Engine 2 3516C 4.06 Engine 4 3520C 5.35 Engine 5 3516LE 3.00 Engine 7 3520C 5.35 Engine 8 3520C 5.35 Engine 11 3516H 4.75 Engine 12 3520H 1.20 Engine 13 3520DSL 1.20 Engine 14 G3520H 1.20 RD_NG#1 Natural Gas R&D 1 5.50 RD_NG#2 Natural Gas R&D 2 5.50 RD_DIESEL Diesel R&D 2.50 Air Quality Modeling Report – Heber City Light & Power – Notice of Intent Emission And Source Data December 14, 2022 ce v:\2037\active\203722882\05_report_deliv\deliverables\appendices\apendix g - modeling report\rpt_1hr_no2_modeling_report_121422.docx 3.2 3.2 SOURCE CHARACTERIZATION All emission sources are characterized as point sources. The following sections outline the rationale and basis for all parameters. 3.2.1 Operational Schedule All units are assumed to operate simultaneously. 3.2.2 Point Sources There are thirteen point sources within Heber. All parameters shown below were either derived from manufacturer specification sheets, calculations based on test data or provided by the facility. Heber has committed to increasing the stack height on all sources to 53’ above ground level. Table 3-2 Generator Stack Parameters Stack Stack Height (ft) Temperature (°F) Stack Diameter (inches) Flow Rate (acfm) Engine 1 53 803.5 19.5 9594 Engine 2 803.5 19.5 9594 Engine 4 909.0 19.5 16714 Engine 5 960.0 28 12780 Engine 7 909.0 19.8 16714 Engine 8 909.0 19.8 16714 Engine 11 748.0 21.0 12125 Engine 12 749.0 22.0 14773 Engine 13 852.0 22.0 18807 Engine 14 814.0 22.0 14245 Natural Gas R&D #1 825.5 21.0 10866 Natural Gas R&D #2 825.5 21.0 10866 Diesel R&D 825.5 21.0 10017 Air Quality Modeling Report – Heber City Light & Power – Notice of Intent Receptor network December 14, 2022 ce v:\2037\active\203722882\05_report_deliv\deliverables\appendices\apendix g - modeling report\rpt_1hr_no2_modeling_report_121422.docx 5.1 4.0 RECEPTOR NETWORK The facility is located in a rural area in Heber City, Utah within Wasatch County. Consistent with UDAQ Air Dispersion Modeling Guidance, the ambient air boundary used in this analysis is the leased property boundary, which also serves as the Public Access Boundary (PAB). Heber owns the area north of W 300 S and can control access along W 300 S west of South 6th West. Receptors along the PAB were spaced at 25 meter increments. The PAB represents the limit of access by the public to the project site. The receptor grid was established as follows: • Receptors spaced at 25 meters along the PAB; • Receptors spaced at 25 meters for the first 100 meters past the PAB; • Receptors spaced at a density of one per 50 meters out to 225 meters away from the PAB; • Receptors spaced at 100 meters from the PAB out to 400 meters; • Receptors spaced at 250 meters from the PAB out to 850 meters; • Receptors spaced at 500 meters from the PAB out to 2.1 kilometers past the PAB; and The receptor network ensures that the analysis meets or exceeds EPA receptor network requirements and captures the maximum impact from the facility. 5.0 ELEVATION DATA All source base and receptor elevations were calculated from USGS NED data obtained via the National Map Viewer website using the Bee-Line BEEST preprocessing system. A 1/3 arc second NED file was used in the analysis input and output files from AERMAP and will be included submitted with the report. Air Quality Modeling Report – Heber City Light & Power – Notice of Intent meteorological data December 14, 2022 ce v:\2037\active\203722882\05_report_deliv\deliverables\appendices\apendix g - modeling report\rpt_1hr_no2_modeling_report_121422.docx 6.1 6.0 METEOROLOGICAL DATA Preprocessed AERMOD-ready meteorological files were obtained via the UDAQ Guideline website 1. The data files cover the years 2004 through 2008 from the Spanish Fork Airport. The hourly average data is from the National Weather Service (NWS) Automated Surface Observing System (ASOS). The data presented by UDAQ is model-ready and was used without alteration or processing. Because these data originated from UDAQ, it will not be included as part of this submittal. 1 https://deq.utah.gov/air-quality/emissions-impact-assessment-guideline-preface Air Quality Modeling Report – Heber City Light & Power – Notice of Intent Land use Classification December 14, 2022 ce v:\2037\active\203722882\05_report_deliv\deliverables\appendices\apendix g - modeling report\rpt_1hr_no2_modeling_report_121422.docx 7.1 7.0 LAND USE CLASSIFICATION AERMOD includes rural and urban algorithm options. These options affect the wind speed profile, dispersion rates, and mixing-height formula used in calculating ground-level pollutant concentrations. A protocol was developed by USEPA to classify an area as either rural or urban for dispersion modeling purposes. The classification is based on average heat flux, land use, or population density within a three-km radius from the plant site. Of these techniques, the USEPA has specified that land use is the most definitive criterion (USEPA, 1987). The urban/rural classification scheme based on land use is as follows: The land use within the total area, A0, circumscribed by a 3-km circle about the source, is classified using the meteorological land use typing scheme proposed by Auer (1978). The classification scheme requires that more than 50% of the area, A0, be from the following land use types in order to be considered urban for dispersion modeling purposes: heavy industrial (I1); light-moderate industrial (I2); commercial (C1); single- family compact residential (R2); and multi-family compact residential (R3). Otherwise, the use of rural dispersion coefficients is appropriate. The Heber facility is located in a rural area, at Heber City, Utah. Although the immediate vicinity of the site is industrial and commercial, site and map reconnaissance showed that the area A0 within a 3-km circle of the source is below the 50% urban land use criteria necessary for use of urban dispersion coefficients. Rural dispersion coefficients were, therefore, used in the air quality dispersion modeling. Air Quality Modeling Report – Heber City Light & Power – Notice of Intent Background Concentrations December 14, 2022 ce v:\2037\active\203722882\05_report_deliv\deliverables\appendices\apendix g - modeling report\rpt_1hr_no2_modeling_report_121422.docx 8.1 8.0 BACKGROUND CONCENTRATIONS NO2 Monthly background values were obtained via the EPA Air Quality Monitors website 2. Numerous sites were evaluated, but Price was ultimately selected from November 2017 through October 2020. Price was selected because the topography and elevation are very similar (Heber City 5,604’ vs Price 5,627’). Additionally, Wasatch and Carbon County are both in attainment. Lastly, the other sites were much too close to the I-15 corridor and overestimating of NO2 relative to what is most likely in Heber City. These values are consistent with the most recent modeling submittal to UDAQ (January 8, 2021). The average three-year values used are as follows for the PVMRM Tier 3 analysis was : Table 8-1 Monthly Background Values Month O3 (ppm) NO2 (ppb) January 0.047 22.17 February 0.054 11.73 March 0.056 11.50 April 0.062 9.17 May 0.065 6.13 June 0.070 10.47 July 0.073 11.60 August 0.072 10.23 September 0.066 10.03 October 0.057 9.97 November 0.052 12.30 December 0.048 18.90 NO2 In-Stack Ratio Lastly, a representative NO2/NOx in-stack ratio of 0.18 for each natural gas engine was applied. This an average of the approximate maximum between the Caterpillar G3516 and G3520 engines as referenced in the EPA In-stack Ratio database 3. The R&D Diesel ratio was set to 0.05. These values are consistent with the January 8, 2021, modeling that was previously accepted by UDAQ. This number is an average value of three Caterpillar G3520 engines previously tested by the Oklahoma DEQ as stated in the EPA in-stack database. 2 https://www.epa.gov/outdoor-air-quality-data/interactive-map-air-quality-monitors 3 https://www.epa.gov/scram/nitrogen-dioxidenitrogen-oxide-stack-ratio-isr-database Air Quality Modeling Report – Heber City Light & Power – Notice of Intent Results December 14, 2022 ce v:\2037\active\203722882\05_report_deliv\deliverables\appendices\apendix g - modeling report\rpt_1hr_no2_modeling_report_121422.docx 9.2 9.0 RESULTS The following sections outline the methods used to complete an ambient air impact analysis as a result of the proposed Heber City project. 9.1 APPLICABLE LIMITS The air quality impact limits applicable to this analysis are the National Ambient Air Quality Standards (NAAQS). NO2 uses the design value that is the 98th percentile averaged over three years. That equates to a design value that is the 8th high over a five year period. 9.2 IMPACT The tables shown below demonstrate that there is no exceedance of the 1-hr NO2 NAAQS standards due to the proposed operation of the facility. 9.2.1 NO2 Results Table 9-1 PM10 Modeling Results PM10 Averaging Period Background Concentration (µg/m3)1 Modeled Impact (µg/m3)3 Total Concentration (µg/m3) NAAQS (µg/m3) % of Standard Heber 1-hr2 PVMRM 140.3 140.3 188 74.6% 1. Monthly ozone and NO2 backgrounds 2. 8th high design value 3. 2004-2018 Spanish Fork Met data HEBER LIGHT & POWER COMPANY NOTICE OF INTENT Appendix H Federal Requirements Discussion January 4, 2023 H.1 FEDERAL REQUIREMENTS DISCUSSION The majority of the discussion regarding 40 CFR 60, Subpart JJJJ and 40 CFR 63, Subpart ZZZZ is discussion can be found within Section 2 of the application. Found in this appendix is the ZZZZ exception documentation from UDAQ regarding the R&D engines.