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Home My WebLink AboutDAQ-2024-008198 DAQE-AN144290009-24 {{$d1 }} Michael LeBaron Peak Minerals Incorporated 10808 South River Front Parkway, Suite 343 South Jordan, UT 84095 mike@peakminerals.com Dear Mr. LeBaron: Re: Approval Order: Minor Modification to Approval Order DAQE-AN144290005A-19 for the Sevier Playa Potash Project Project Number: N144290009 The attached Approval Order (AO) is issued pursuant to the Notice of Intent (NOI) received on October 31, 2023. Peak Minerals Incorporated must comply with the requirements of this AO, all applicable state requirements (R307), and Federal Standards. The project engineer for this action is John Jenks, who can be contacted at (385) 306-6510 or jjenks@utah.gov. Future correspondence on this AO should include the engineer's name as well as the DAQE number shown on the upper right-hand corner of this letter. No public comments were received on this action. Sincerely, {{$s }} Bryce C. Bird Director BCB:JJ:jg cc: Central Utah 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 May 16, 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-AN144290009-24 Minor Modification to Approval Order DAQE-AN144290005A-19 for the Sevier Playa Potash Project Prepared By John Jenks, Engineer (385) 306-6510 jjenks@utah.gov Issued to Peak Minerals Incorporated - Sevier Playa Potash Project Issued On {{$d2 }} Issued By {{$s }} Bryce C. Bird Director Division of Air Quality May 16, 2024 TABLE OF CONTENTS TITLE/SIGNATURE PAGE ....................................................................................................... 1 GENERAL INFORMATION ...................................................................................................... 3 CONTACT/LOCATION INFORMATION ............................................................................... 3 SOURCE INFORMATION ........................................................................................................ 3 General Description ................................................................................................................ 3 NSR Classification .................................................................................................................. 4 Source Classification .............................................................................................................. 4 Applicable Federal Standards ................................................................................................. 4 Project Description.................................................................................................................. 4 SUMMARY OF EMISSIONS .................................................................................................... 5 SECTION I: GENERAL PROVISIONS .................................................................................... 5 SECTION II: PERMITTED EQUIPMENT .............................................................................. 6 SECTION II: SPECIAL PROVISIONS ..................................................................................... 8 PERMIT HISTORY ................................................................................................................... 14 ACRONYMS ............................................................................................................................... 15 DAQE-AN144290009-24 Page 3 GENERAL INFORMATION CONTACT/LOCATION INFORMATION Owner Name Source Name Peak Minerals Incorporated Peak Minerals Incorporated - Sevier Playa Potash Project Mailing Address Physical Address 10808 South River Front Parkway, Suite 343 South Jordan, UT 84095 Sevier Playa Lakeview Yard 36200 West Crystal Peak Spur Road Delta, UT 84624 Source Contact UTM Coordinates Name: Michael LeBaron 314,505 m Easting Phone: (801) 920-4421 4,313,105 m Northing Email: mike@peakminerals.com Datum NAD83 UTM Zone 12 SIC code 1474 (Potash, Soda, & Borate Minerals) SOURCE INFORMATION General Description Peak Minerals Incorporated (Peak Minerals) will operate a potash mining project, the Sevier Playa Potash Project, in Millard County. Peak Minerals will produce potash in the form of potassium sulfate (K2SO4), also known as sulfate of potash (SOP), and magnesium chloride from salts present in the brines of the playa. The site will consist of the following major features: 1) a brine extraction system consisting of canals, trenches, and wells; 2) a recharge system consisting of canals and trenches. Fresh water is introduced to the extraction system to maintain the hydraulic head. 3) evaporation ponds consisting of preconcentration and production ponds. This will concentrate the brine to the saturation point. Salts will precipitate within each of the ponds. At the pre-concentration ponds, sodium chloride (NaCl) wet harvesting will occur via a dredge, and solid NaCl storage areas (salt pads) allow for additional potassium recovery. 4) Waste Product Storage Area; and 5) Processing Facility. Brines will be extracted from below the surface of the Sevier Playa and concentrated by solar evaporation in a series of preconcentration ponds. The potassium-rich salts harvested from the production ponds will be windrowed and then hauled to the processing facility for final treatment. Process tailings will be loaded and hauled to the tailings management area. MOP will be imported to the processing facility, where it will be reacted with the residual brine containing magnesium sulfate to increase SOP production. DAQE-AN144290009-24 Page 4 In the processing facility, muriate of potash (MOP) reacts with the residual brine containing magnesium sulfate to increase SOP production. Raw potash salts in the processing facility will go through the process feed. This step will convey salts from a hopper into a crusher to be sized. A crushed salt slurry will then enter the conversion circuit. In this step, high-sulfate brine from the halite leach step will cause the mixed potassium pond salts to form schoenite. Along with schoenite, halite and magnesium sulfate are also expected to be present. Then the slurry will enter conditioning and flotation to remove insolubles. Insolubles are then conveyed to the tailing management area. Schoenite will be separated from other salts and slimes by adding flotation reagents and oils to the potash salt slurry. The flotation concentrate will be centrifuged, and the solids will be washed to remove brine and then sent to the leach reactor. The next step is SOP leaching and crystallization, where the SOP crystals will be recovered from the brine by a combination of cyclones and centrifuges. Potassium chloride will react with the magnesium sulfate in solution to form additional SOP and magnesium chloride. The last steps are drying, handling, and shipping. The processing facility is also exploring the opportunity to produce de-sulfated magnesium chloride (MgCl2) brine and bischofite flakes after SOP production is established and running. NSR Classification Minor Modification at Minor Source Source Classification Located in Attainment Area Millard County Airs Source Size: SM Applicable Federal Standards NSPS (Part 60), A: General Provisions NSPS (Part 60), Dc: Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units NSPS (Part 60), IIII: Standards of Performance for Stationary Compression 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 Description Peak Minerals is requesting approval to construct and operate the previously permitted potash mining project. This modification is a review and revision of the previously proposed operations. Since the previous NOI, process changes, including the addition of magnesium chloride processing and shipping over rail transport, have been included. Emissions from this operation are generated from material handling and heating. The majority of pre-process operations are done under wet conditions. DAQE-AN144290009-24 Page 5 SUMMARY OF EMISSIONS The emissions listed below are an estimate of the total potential emissions from the source. Some rounding of emissions is possible. Criteria Pollutant Change (TPY) Total (TPY) CO2 Equivalent -15192 10689.00 Carbon Monoxide -82.35 15.00 Nitrogen Oxides -13.72 12.00 Particulate Matter - PM10 -153.74 17.00 Particulate Matter - PM10 (Fugitives) -20.56 95.00 Particulate Matter - PM2.5 -36.03 16.00 Particulate Matter - PM2.5 (Fugitives) 1.33 17.00 Sulfur Dioxide -0.11 0.05 Volatile Organic Compounds -5.12 1.10 Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr) Generic HAPs (CAS #GHAPS) 42 110 Change (TPY) Total (TPY) Total HAPs -0.28 0.06 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] DAQE-AN144290009-24 Page 6 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 every 18 months from the date of this AO until construction is completed to demonstrate reasonable construction progress. This AO may become invalid if construction is not commenced within 18 months from the date of this AO or if construction is discontinued for 18 months or more. To ensure proper credit when notifying the Director, send the documentation to the Director, attn.: NSR Section. [R307-401-18] SECTION II: PERMITTED EQUIPMENT II.A THE APPROVED EQUIPMENT II.A.1 Sevier Playa Potash Project II.A.2 MgCl2 Steam Boiler Rating: 15 MMBtu/hr Fuel: Propane NSPS Applicability: Subpart Dc II.A.3 Drying and sizing fluid bed dryer Heat Input Rating: 4.4 MMBtu/hr Fuel: Propane Control: Main Dryer Baghouse II.A.4 Glazing Fluid Bed Dryer Heat Input Rating: 2 MMBtu/hr Fuel: Propane Control: Glazing Dryer Baghouse II.A.5 Compaction Baghouse Flow Rate: 35,000 acfm Description: Controls emissions from all compaction operations, including crushers, screens, and material handling (conveyors, bucket elevators, magnetic chutes, diverters, compactor, flake breakers, and bins) II.A.6 Main Dryer Baghouse Flow Rate: 14,125 acfm Description: Controls emissions from the Fluid Bed Dryer II.A.7 Glazing Dryer Baghouse Flow Rate: 6,769 acfm Description: Controls emissions from drop points, conveyors, chute, bucket elevator, and the Glazing Fluid Bed Dryer II.A.8 Loadout Silo #1 Baghouse Flow Rate: 1,500 acfm Description: Controls emissions from loadout silo II.A.9 MOP Silo Dust Collector Flow Rate: 1,900 acfm Description: Controls MOP silo DAQE-AN144290009-24 Page 7 II.A.10 Bagging Plant Buffer Silo Baghouse Flow Rate: 1,500 acfm Description: Controls bagging operations, such as conveyors, silo, bucket elevator, and bagging filling station II.A.11 Quick Lime Silo Bin Vent Flow Rate: 1,900 acfm II.A.12 50 Lb. Bischofite Silo Bin Vent 1,900 acfm II.A.13 One (1) Ton Bischofite Silo Vent 1,900 acfm II.A.14 Material Handling Equipment Various material handling equipment, including conveyors, bucket elevators, chutes, six (6) silos, feeder hoppers, diverter, flake breaker, bin, compactor, drum, drier/cooler, filling station, and apron feeder II.A.15 Screens and Crushers Controlled by Wet Process Screens: Mixed Salts Screen Capacity 307 TPH Controlled by Compaction Baghouse and Glazing Dryer Baghouse Crushers Dryer Oversize Roll Crusher Capacity: 20.4 TPH Compaction Flake Breaker Capacity: 95 TPH Compaction Double Roll Crusher Capacity: 25 TPH Screens Product Screen Capacity: 107 TPH Compaction Screen Capacity:118 TPH Granular Product Glazing Screen Capacity: 39 TPH DAQE-AN144290009-24 Page 8 II.A.16 Eight (8) Generator Sets Fuel: Diesel Certified Tier 4 NSPS Applicability: Subpart IIII MACT Applicability: Subpart ZZZZ Generator Set 1, 2, and 3 Rating: 53 hp Each Generator Set 4 Rating:139 hp Generator Set 5 and 6 Rating: 59 hp Each Generator Set 7 Rating: 111 hp Generator Set 8 Rating: 78 hp II.A.17 One (1) Fire Pump Engine Rating: 100 hp Fuel: Diesel MACT Applicability: Subpart ZZZZ II.A.18 Two (2) Emergency Generator Engines Fuel: Diesel Certified Tier 4 Rating: 1,342 hp NSPS Applicability: Subpart IIII MACT Applicability: Subpart ZZZZ II.A.19 Three (3) Mobile Pumps Fuel: Diesel Rating: 20 hp II.A.20 Supporting Equipment Supporting equipment, including a diesel dispensing facility and diesel storage tanks SECTION II: SPECIAL PROVISIONS II.B REQUIREMENTS AND LIMITATIONS II.B.1 Site-Wide Requirements II.B.1.a The owner/operator shall not produce more than 215,000 tons per year of sulfates of potash and 300,000 tpy of magnesium chloride and other associated minerals per rolling 12-month period. [R307-401-8] DAQE-AN144290009-24 Page 9 II.B.1.a.1 Compliance with the production limitation shall be determined on a rolling 12-month total. A new 12-month total shall be calculated using data from the previous 12 months. Monthly calculations shall be made no later than 20 days after the end of each calendar month. Records of production shall be kept for all periods when the plant is in operation. Production shall be determined by examination of production records, which will be maintained by Peak Minerals and housed in the administrative offices onsite. The records of production shall be kept on a daily basis. [R307-401-8] II.B.1.b Unless otherwise specified in this AO, visible emissions from any stationary and fugitive dust source shall not exceed 20% opacity. [R307-401-8] II.B.1.b.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. [R307-205] II.B.1.c The owner/operator shall comply with the latest version of the FDCP approved by the Director. The FDCP shall address the control of all fugitive dust sources at this source. [R307-401-8] II.B.2 Haul Road and Disturbed Area Requirements II.B.2.a Visible emissions in disturbed areas and unpaved haul roads from haul trucks and mobile equipment and windblown dust in operational areas shall not exceed 20% opacity at any point. [R307-205-4, R307-401-8] II.B.2.a.1 Visible emission determinations for fugitive dust from operationally disturbed areas shall use Method 9. However, with respect to emissions from mobile or intermittent sources, the normal requirement for observations to be made at 15-second intervals over a six-minute period shall not apply. Visible emissions shall be observed at the densest point of the plume, but at a point not less than one-half vehicle length behind the vehicle and not less than one-half the height of the vehicle. [R307-201-3, R307-205-4] II.B.2.b The owner/operator shall limit disturbed areas to the following: A. On-Playa Disturbed Areas - 4.6 acres per day. B. Production Ponds Disturbed Areas - 1.8 acres per day. Disturbed areas include berms, playa surfaces, and all areas disturbed by operational activities, such as bulldozing, scraping, grading, etc. [R307-401-8] II.B.2.b.1 To determine compliance with the maximum daily limits for disturbed areas, the owner/operator shall perform daily visual inspections. Records of daily visual inspections shall be maintained for all periods when the plant is in operation. The Director may require a survey of disturbed areas at any time. [R307-401-8] DAQE-AN144290009-24 Page 10 II.B.2.c All operationally disturbed areas and haul roads shall be sprayed with water, brine, or a chemical suppressant to control fugitive dust and maintain the opacity limit listed in this AO. The owner/operator may stop applying water when the temperature is below freezing or when the area is wet from precipitation. Records of water and/or chemical treatment shall be kept for all periods when the plant is in operation. The records shall include the following items: A. Date B. Location of treatment C. Rainfall received, if any, and approximate amount D. Records of temperature if the temperature is below freezing. [R307-401-8] II.B.3 Material Handling and Processing Equipment Requirements II.B.3.a All material handling and processing equipment used for non-slurried material shall be controlled by baghouses, full enclosures, or partial enclosures. All material handling and processing equipment not controlled by baghouses shall be controlled by enclosed or partially enclosed structures or located within buildings. Partial enclosures include conveyor covers for conveyors and socks/retractable chutes for transfer points. [R307-401-8] II.B.3.b Visible emissions from material handling and processing equipment located outdoors shall not exceed 20% opacity. [R307-401-8] II.B.3.b.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. [R307-205-4, R307-401-8] II.B.3.c The owner/operator shall allow no visible emissions from tailings material stored at the Waste Product Storage Area. [R307-401-8] II.B.4 Emergency and Non-Emergency Engine Requirements II.B.4.a Visible emissions from diesel-fired emergency and non-emergency generator engines shall not exceed 20% opacity. [R307-401-8] II.B.4.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. [R307-205, R307-401-8] II.B.4.b Each emergency generator engine shall not exceed 100 hours of operation for testing and maintenance per rolling 12-month period. The 100 hours of operation for testing and maintenance purposes may include up to 50 hours per calendar year for operation in non- emergency situations, as provided in 40 CFR 60.4211(f). To determine the duration of operation, the owner/operator shall install a non-resettable hour meter for each emergency engine. [40 CFR 60 Subpart IIII, 40 CFR 60 Subpart ZZZZ, R307-401-8] DAQE-AN144290009-24 Page 11 II.B.4.b.1 Compliance with the limit of the hours of operation shall be determined by the installation of an hour meter on the emergency generator engine or by recording the hours of operation in an operations log. Records documenting the operation of the emergency generator engine shall be kept in a log and shall include the following: A. The date the emergency generator engine was used; B. The duration of the operation each day in hours; and C. The reason for the emergency generator engine usage. [R307-401-8] II.B.4.b.2 To determine compliance with the rolling 12-month total, the owner/operator shall calculate a new 12-month total by the twentieth day of each month using data from the previous 12 months. [R307-401-8] II.B.4.c The owner/operator shall install emergency and non-emergency generator engines certified to meet Tier 4 emission standards. [R307-401-8] II.B.4.c.1 The owner/operator shall keep a record of the manufacturer's emission rate certification for the life of the equipment. [R307-401-8] II.B.5 Baghouse Requirements II.B.5.a Visible emissions from baghouses shall not exceed the following opacity limits: A. Main Dryer Baghouse - 10%. B. Glazing Dryer Baghouse - 10%. C. All Other Baghouses - 7%. [R307-401-8] II.B.5.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. [R307-205, R307-401-8] II.B.5.b Each baghouse shall operate within the static pressure range recommended by the manufacturer for normal operations. Manometers or magnehelic pressure gauges shall be installed to measure the differential pressure across each of the baghouses. The monitoring device shall be accurate within plus or minus one (1) inch of the water column. The pressure gauges shall be located such that an inspector/operator can safely read the indicator at any time. [R307-401-8] II.B.5.b.1 Pressure drop readings shall be recorded at least once during each week of operation. Records documenting these inspections shall be kept in a log and shall include the following: A. Unit identification; B. Manufacturer recommended pressure drop for the unit; C. Weekly pressure drop readings; and D. Date of bag replacement, if applicable. [R307-401-8] DAQE-AN144290009-24 Page 12 II.B.5.b.2 The instrument shall be calibrated in accordance with the manufacturer's instructions or recommendations. Documentation of calibrations shall be maintained. [R307-401-8] II.B.5.c Emissions of PM10 and PM2.5 from the baghouses to the atmosphere shall not exceed the following rates and concentrations, based on an average of three (3) test runs: Processing Facility Baghouses PM10 and PM2.5 Emission Point Emission Rate (lb/hr) Concentration 68 degrees F, 29.92 in Hg (grains/dscf) Compaction Baghouse 1.5** 0.005** Main Dryer Baghouse 1.2* 0.010* Glazing Dryer Baghouse 0.6* 0.010* *Includes both filterable and condensable particulates **Includes filterable particulates only. [R307-401-8] II.B.5.c.1 Testing Frequency A. Initial compliance testing is required on all above listed emission sources. The initial test shall be performed as soon as possible and in no case later than 180 days after the startup of each unit. B. Subsequent compliance tests shall be done on each emission source at least once every five (5) years subsequent to the initial compliance test. The Director may require testing at any time. If an existing source is modified, a compliance test is required on the modified emission point that has an emission rate limit. [R307-401-8] II.B.5.c.2 Notification The Director shall be notified at least 30 days prior to conducting any required emission testing. A source test protocol shall be submitted to DAQ. The source test protocol shall be approved by the Director prior to performing the test(s). The source test protocol shall outline the proposed test methodologies, stack to be tested, and procedures to be used. A pretest conference shall be held, if directed by the Director. [R307-165] II.B.5.c.3 Sample Location The emission point shall be designed to conform to the requirements of 40 CFR 60, Appendix A, Method 1, or other EPA-approved methods acceptable to the Director. Occupational Safety and Health Administration (OSHA) or Mine Safety and Health Administration (MSHA)-approved access shall be provided to the test location. [R307-165] II.B.5.c.4 Calculations To determine mass emission rates (lb/hr, etc.), the pollutant concentration as determined by the appropriate methods herein shall be multiplied by the volumetric flow rate and any necessary conversion factors determined by the Director, to give the results in the specified units of the emission limitation. [R307-165] DAQE-AN144290009-24 Page 13 II.B.5.c.5 New Source Operation For a new source/emission point, the production rate during all compliance testing shall be no less than 90% of the production rate listed in this AO. If the maximum AO allowable production rate has not been achieved at the time of the test, the following procedure shall be followed: 1) Testing shall be at no less than 90% of the production rate achieved to date. 2) If the test is passed, the new maximum allowable production rate shall be 110% of the tested achieved rate, but not more than the maximum allowable production rate. This new allowable maximum production rate shall remain in effect until successfully tested at a higher rate. 3) The owner/operator shall request a higher production rate when necessary. Testing at no less than 90% of the higher rate shall be conducted. A new maximum production rate (110% of the new rate) will then be allowed if the test is successful. This process may be repeated until the maximum AO production rate is achieved. [R307-165] II.B.5.c.6 Existing Source Operation For an existing source/emission point, the production rate during all compliance testing shall be no less than 90% of the maximum production achieved in the previous three (3) years. [R307-165] II.B.5.c.7 Volumetric Flow Rate 40 CFR 60, Appendix A, Method 2, or other EPA-approved testing methods acceptable to the Director. [R307-165] II.B.5.c.8 PM10/PM2.5 For baghouse stacks in which no liquid drops are present, the following methods shall be used: 40 CFR 51, Appendix M, Methods 201 or 201a, or other EPA-approved testing method, as acceptable by the Director. The back half condensable particulate emissions shall also be tested (where applicable) using 40 CFR 51, Appendix M Method 202, or another EPA-approved testing method acceptable to the Director. All particulate captured using Method 202 shall be considered PM2.5. The only baghouse sources that will emit condensables are the Main Dryer Baghouse and the Glazing Dryer Baghouse. For baghouse stacks in which liquid drops are present, methods to eliminate the liquid drops should be explored. If no reasonable method to eliminate the drops exists, then the following methods shall be used: 40 CFR 60, Appendix A, Method 5, 5a, 5d, 5i, or others as appropriate. Using Method 5, all filterable particulate emissions shall be considered PM10, unless otherwise approved by the Director. The portion of the filterable particulate emissions considered PM2.5 shall be based on information in Appendix B of the fifth addition of the EPA document, AP-42, or other data acceptable to the Director. The back half condensable particulate emissions shall also be tested using 40 CFR 51, Appendix M Method 202, or another EPA-approved testing method acceptable to the Director. All particulate captured using Method 202 shall be considered PM2.5. [R307-165] II.B.5.c.9 Reporting The results of stack testing shall be submitted to the Director within 60 days of completion of the testing. Reports shall clearly identify results as compared to permit limits and indicate compliance status. [R307-165] II.B.6 Dryer and steam Boiler Requirements II.B.6.a The owner/operator shall use only propane and natural gas as a fuel in the dryers. [R307-401-8] DAQE-AN144290009-24 Page 14 II.B.6.b The owner/operator shall install: A. Dryers that are certified to meet a NOx emission rate of 25 ppmvd or less, and; B. The steam boiler is certified to meet a NOx emission rate of 13 ppmvd or less. [R307-401-8] II.B.6.b.1 The owner/operator shall keep a record of the manufacturer's certification of the emission rate for each unit. The record shall be kept for the life of the equipment. [R307-401-8] II.B.6.c The owner/operator shall route emissions from each Dryer through a baghouse prior to venting to the atmosphere. [R307-401-8] II.B.7 Engine Fuel Requirements II.B.7.a The owner/operator shall only use diesel fuel (e.g., fuel oil #1, #2, or diesel fuel oil additives) as fuel in the emergency engines, fire pumps, pond pumps, and Generator Sets. [R307-401-8] II.B.7.a.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.7.a.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-AN144290005A-19 dated August 13, 2019 Is Derived From NOI dated October 31, 2023 Incorporates Additional Information dated December 1, 2023 Incorporates Additional Information dated December 11, 2023 Incorporates Additional Information dated February 29, 2024 DAQE-AN144290009-24 Page 15 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-IN144290009-24 April 4, 2024 Michael LeBaron Peak Minerals Incorporated 10808 South River Front Parkway, Suite 343 South Jordan, UT 84095 mike@peakminerals.com Dear Mr. LeBaron: Re: Intent to Approve: Minor Modification to Approval Order DAQE-AN144290005A-19 for the Sevier Playa Potash Project Project Number: N144290009 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, John Jenks, as well as the DAQE number as shown on the upper right-hand corner of this letter. John Jenks, can be reached at (385) 306- 6510 or jjenks@utah.gov, if you have any questions. Sincerely, {{$s }} Jon L. Black, Manager New Source Review Section JLB:JJ:jg cc: Central Utah Health Department 195 North 1950 West • Salt Lake City, UT Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820 Telephone (801) 536-4000 • Fax (801) 536-4099 • T.D.D. (801) 536-4414 www.deq.utah.gov Printed on 100% recycled paper State of Utah SPENCER J. COX Governor DEIDRE HENDERSON Lieutenant Governor Department of Environmental Quality Kimberly D. Shelley Executive Director DIVISION OF AIR QUALITY Bryce C. Bird Director * ) ' & — + - A v A ? A C @ C w ? C ˜ STATE OF UTAH Department of Environmental Quality Division of Air Quality INTENT TO APPROVE DAQE-IN144290009-24 Minor Modification to Approval Order DAQE-AN144290005A-19 for the Sevier Playa Potash Project Prepared By John Jenks, Engineer (385) 306-6510 jjenks@utah.gov Issued to Peak Minerals Incorporated - Sevier Playa Potash Project Issued On April 4, 2024 {{$s }} New Source Review Section Manager Jon L. Black {{#s=Sig_es_:signer1:signature}} * ) ' & — + - A v A ? A C @ C w ? C ˜ TABLE OF CONTENTS TITLE/SIGNATURE PAGE ....................................................................................................... 1 GENERAL INFORMATION ...................................................................................................... 3 CONTACT/LOCATION INFORMATION ............................................................................... 3 SOURCE INFORMATION ........................................................................................................ 3 General Description ................................................................................................................ 3 NSR Classification .................................................................................................................. 4 Source Classification .............................................................................................................. 4 Applicable Federal Standards ................................................................................................. 4 Project Description.................................................................................................................. 4 SUMMARY OF EMISSIONS .................................................................................................... 4 PUBLIC NOTICE STATEMENT............................................................................................... 5 SECTION I: GENERAL PROVISIONS .................................................................................... 5 SECTION II: PERMITTED EQUIPMENT .............................................................................. 6 SECTION II: SPECIAL PROVISIONS ..................................................................................... 9 PERMIT HISTORY ................................................................................................................... 15 ACRONYMS ............................................................................................................................... 16 DAQE-IN144290009-24 Page 3 GENERAL INFORMATION CONTACT/LOCATION INFORMATION Owner Name Source Name Peak Minerals Incorporated Peak Minerals Incorporated - Sevier Playa Potash Project Mailing Address Physical Address 10808 South River Front Parkway, Suite 343 South Jordan, UT 84095 Sevier Playa Lakeview Yard 36200 West Crystal Peak Spur Road Delta, UT 84624 Source Contact UTM Coordinates Name: Michael LeBaron 314,505 m Easting Phone: (801) 920-4421 4,313,105 m Northing Email: mike@peakminerals.com Datum NAD83 UTM Zone 12 SIC code 1474 (Potash, Soda, & Borate Minerals) SOURCE INFORMATION General Description Peak Minerals Incorporated (Peak Minerals) will operate a potash mining project, the Sevier Playa Potash Project, in Millard County. Peak Minerals will produce potash in the form of potassium sulfate (K2SO4), also known as sulfate of potash (SOP), and magnesium chloride from salts present in the brines of the playa. The site will consist of the following major features: 1) a brine extraction system consisting of canals, trenches, and wells; 2) a recharge system consisting of canals and trenches. Fresh water is introduced to the extraction system to maintain the hydraulic head. 3) evaporation ponds consisting of preconcentration and production ponds. This will concentrate the brine to the saturation point. Salts will precipitate within each of the ponds. At the pre-concentration ponds, sodium chloride (NaCl) wet harvesting will occur via a dredge, and solid NaCl storage areas (salt pads) allow for additional potassium recovery. 4) Waste Product Storage Area; and 5) Processing Facility. Brines will be extracted from below the surface of the Sevier Playa and concentrated by solar evaporation in a series of preconcentration ponds. The potassium-rich salts harvested from the production ponds will be windrowed and then hauled to the processing facility for final treatment. Process tailings will be loaded and hauled to the tailing’s management area. MOP will be imported to the processing facility, where it will be reacted with the residual brine containing magnesium sulfate to increase SOP production. In the processing facility, muriate of potash (MOP) reacts with the residual brine containing magnesium sulfate to increase SOP production. Raw potash salts in the processing facility will go through the process feed. This step will convey salts from a hopper into a crusher to be sized. A crushed salt slurry DAQE-IN144290009-24 Page 4 will then enter the conversion circuit. In this step, high-sulfate brine from the halite leach step will cause the mixed potassium pond salts to form schoenite. Along with schoenite, halite and magnesium sulfate are also expected to be present. Then the slurry will enter conditioning and flotation to remove insolubles. Insolubles are then conveyed to the tailing management area. Schoenite will be separated from other salts and slimes by adding flotation reagents and oils to the potash salt slurry. The flotation concentrate will be centrifuged, and the solids will be washed to remove brine and then sent to the leach reactor. The next step is SOP leach and crystallization, where the SOP crystals will be recovered from the brine by a combination of cyclones and centrifuges. Potassium chloride will react with the magnesium sulfate in solution to form additional SOP and magnesium chloride. The last steps are drying, handling, and shipping. The processing facility is also exploring the opportunity to produce de-sulfated magnesium chloride (MgCl2) brine and bischofite flakes after SOP production is established and running. NSR Classification Minor Modification at Minor Source Source Classification Located in Attainment Area Millard County Airs Source Size: SM Applicable Federal Standards NSPS (Part 60), A: General Provisions NSPS (Part 60), Dc: Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units NSPS (Part 60), IIII: Standards of Performance for Stationary Compression 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 Description Peak Minerals is requesting approval to construct and operate the previously permitted potash mining project. This modification is a review and revision of the previously proposed operations. Since the previous NOI, process changes, include the addition of magnesium chloride processing and shipping over rail transport, have been included. Emissions from this operation are generated from material handling and heating. The majority of pre-process operations are done under wet conditions. 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 -15192 10689.00 Carbon Monoxide -82.35 15.00 DAQE-IN144290009-24 Page 5 Nitrogen Oxides -13.72 12.00 Particulate Matter - PM10 -153.74 17.00 Particulate Matter - PM10 (Fugitives) -20.56 95.00 Particulate Matter - PM2.5 -36.03 16.00 Particulate Matter - PM2.5 (Fugitives) 1.33 17.00 Sulfur Dioxide -0.11 0.05 Volatile Organic Compounds -5.12 1.10 Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr) Generic HAPs (CAS #GHAPS) 42 110 Change (TPY) Total (TPY) Total HAPs -0.28 0.06 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 Millard County Chronicle Progress on April 10, 2024. During the public comment period the proposal and the evaluation of its impact on air quality will be available for the public to review and provide comment. If anyone so requests a public hearing within 15 days of publication, it will be held in accordance with UAC R307-401-7. The hearing will be held as close as practicable to the location of the source. Any comments received during the public comment period and the hearing will be evaluated. The proposed conditions of the AO may be changed as a result of the comments received. SECTION I: GENERAL PROVISIONS The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the AO. I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions refer to those rules. [R307-101] I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401] I.3 Modifications to the equipment or processes approved by this AO that could affect the emissions covered by this AO must be reviewed and approved. [R307-401-1] 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] DAQE-IN144290009-24 Page 6 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 every 18 months from the date of this AO until construction is completed to demonstrate reasonable construction progress. This AO may become invalid if construction is not commenced within 18 months from the date of this AO or if construction is discontinued for 18 months or more. To ensure proper credit when notifying the Director, send the documentation to the Director, attn.: NSR Section. [R307-401-18] SECTION II: PERMITTED EQUIPMENT The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the AO. II.A THE APPROVED EQUIPMENT II.A.1 Sevier Playa Potash Project II.A.2 MgCl2 Steam Boiler Rating: 15 MMBtu/hr Fuel: Propane NSPS Applicability: Subpart Dc II.A.3 Drying and sizing fluid bed dryer Heat Input Rating: 4.4 MMBtu/hr Fuel: Propane Control: Main Dryer Baghouse II.A.4 Glazing Fluid Bed Dryer Heat Input Rating: 2 MMBtu/hr Fuel: Propane Control: Glazing Dryer Baghouse II.A.5 Compaction Baghouse Flow Rate: 35,000 acfm Description: Controls emissions from all compaction operations including crushers, screens, and material handling (conveyors, bucket elevators, magnetic chutes, diverters, compactor, flake breaker, and bin) DAQE-IN144290009-24 Page 7 II.A.6 Main Dryer Baghouse Flow Rate: 14,125 acfm Description: Controls emissions from the Fluid Bed Dryer II.A.7 Glazing Dryer Baghouse Flow Rate: 6,769 acfm Description: Controls emissions from drop points, conveyors, chute, bucket elevator, and the Glazing Fluid Bed Dryer II.A.8 Loadout Silo #1 Baghouse Flow Rate: 1,500 acfm Description: Controls emissions from loadout silo II.A.9 MOP Silo Dust Collector Flow Rate: 1,900 acfm Description: Controls MOP silo II.A.10 Bagging Plant Buffer Silo Baghouse Flow Rate: 1,500 acfm Description: Controls bagging operations, such as conveyors, silo, bucket elevator, and bagging filling station II.A.11 Quick Lime Silo Bin Vent Flow Rate: 1,900 acfm II.A.12 50 Lb Bischofite Silo Bin Vent 1,900 acfm II.A.13 1 Ton Bischofite Silo Vent 1,900 acfm II.A.14 Material Handling Equipment Various material handling equipment, including conveyors, bucket elevators, chutes, six (6) silos, feeder hoppers, diverter, flake breaker, bin, compactor, drum, drier/cooler, filling station, and apron feeder. DAQE-IN144290009-24 Page 8 II.A.15 Screens and Crushers Controlled by Wet Process Screens: Mixed Salts Screen Capacity 307 TPH Controlled by Compaction Baghouse and Glazing Dryer Baghouse Crushers Dryer Oversize Roll Crusher Capacity: 20.4 TPH Compaction Flake Breaker Capacity: 95 TPH Compaction Double Roll Crusher Capacity: 25 TPH Screens Product Screen Capacity: 107 TPH Compaction Screen Capacity:118 TPH Granular Product Glazing Screen Capacity: 39 TPH II.A.16 Eight (8) Generator Sets Fuel: Diesel Certified Tier 4 NSPS Applicability: Subpart IIII MACT Applicability: Subpart ZZZZ Generator Set 1, 2, and 3 Rating: 53 hp Each Generator Set 4 Rating:139 hp Generator Set 5 and 6 Rating: 59 hp Each Generator Set 7 Rating: 111 hp Generator Set 8 Rating: 78 hp II.A.17 One (1) Fire Pump Engine Rating: 100 hp Fuel: Diesel MACT Applicability: Subpart ZZZZ DAQE-IN144290009-24 Page 9 II.A.18 Two (2) Emergency Generator Engines Fuel: Diesel Certified Tier 4 Rating: 1,342 hp NSPS Applicability: Subpart IIII MACT Applicability: Subpart ZZZZ II.A.19 Three (3) Mobile Pumps Fuel: Diesel Rating: 20 hp II.A.20 Supporting Equipment Supporting equipment including diesel dispensing facility, diesel storage tanks 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 Site-Wide Requirements II.B.1.a The owner/operator shall not produce more than 215,000 tons per year of sulfates of potash and 300,000 tpy of magnesium chloride and other associated minerals per rolling 12-month period. [R307-401-8] II.B.1.a.1 Compliance with the production limitation shall be determined on a rolling 12-month total. A new 12-month total shall be calculated using data from the previous 12 months. Monthly calculations shall be made no later than 20 days after the end of each calendar month. Records of production shall be kept for all periods when the plant is in operation. Production shall be determined by examination of production records, which will be maintained by Peak Minerals and housed in the administrative offices onsite. The records of production shall be kept on a daily basis. [R307-401-8] II.B.1.b Unless otherwise specified in this AO, visible emissions from any stationary and fugitive dust source shall not exceed 20% opacity. [R307-401-8] II.B.1.b.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. [R307-205] II.B.1.c The owner/operator shall comply with the latest version of the FDCP approved by the Director. The FDCP shall address the control of all fugitive dust sources at this source. [R307-401-8] II.B.2 Haul Road and Disturbed Areas Requirements II.B.2.a Visible emissions in disturbed areas and unpaved haul roads from haul trucks and mobile equipment and windblown dust in operational areas shall not exceed 20% opacity at any point. [R307-205-4, R307-401-8] DAQE-IN144290009-24 Page 10 II.B.2.a.1 Visible emission determinations for fugitive dust from operational disturbed areas shall use Method 9. However, with respect to emissions from mobile or intermittent sources, the normal requirement for observations to be made at 15-second intervals over a six-minute period shall not apply. Visible emissions shall be observed at the densest point of the plume but at a point not less than one-half vehicle length behind the vehicle and not less than one-half the height of the vehicle. [R307-201-3, R307-205-4] II.B.2.b The owner/operator shall limit disturbed areas to the following: A. On-Playa Disturbed Areas - 4.6 acres per day B. Production Ponds Disturbed Areas - 1.8 acres per day Disturbed areas include berms, playa surfaces, and all areas disturbed by operational activities, such as bulldozing, scraping, grading, etc. [R307-401-8] II.B.2.b.1 To determine compliance with the maximum daily limits for disturbed areas, the owner/operator shall perform daily visual inspections. Records of daily visual inspections shall be maintained for all periods when the plant is in operation. The Director may require a survey of disturbed areas at any time. [R307-401-8] II.B.2.c All operational disturbed areas and haul roads shall be sprayed with water, brine, or a chemical suppressant to control fugitive dust and maintain the opacity limit listed in this AO. The owner/operator may stop applying water when the temperature is below freezing or when the area is wet from precipitation. Records of water and/or chemical treatment shall be kept for all periods when the plant is in operation. The records shall include the following items: A. Date. B. Location of treatment. C. Rainfall received, if any, and approximate amount. D. Records of temperature if the temperature is below freezing. [R307-401-8] II.B.3 Material Handling and Processing Equipment Requirements II.B.3.a All material handling and processing equipment used for non-slurried material shall be controlled by baghouses, full enclosures, or partial enclosures. All material handling and processing equipment not controlled by baghouses shall be controlled by enclosed or partially enclosed structures or located within buildings. Partial enclosures include conveyor covers for conveyors and socks/retractable chutes for transfer points. [R307-401-8] II.B.3.b Visible emissions from material handling and processing equipment located outdoors shall not exceed 20% opacity. [R307-401-8] II.B.3.b.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. [R307-205-4, R307-401-8] II.B.3.c The owner/operator shall allow no visible emissions from tailings material stored at the Waste Product Storage Area. [R307-401-8] DAQE-IN144290009-24 Page 11 II.B.4 Emergency and Non-Emergency Engine Requirements II.B.4.a Visible emissions from diesel-fired emergency and non-emergency generator engines shall not exceed 20% opacity. [R307-401-8] II.B.4.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. [R307-205, R307-401-8] II.B.4.b Each emergency generator engine shall not exceed 100 hours of operation for testing and maintenance per rolling 12-month period. The 100 hours of operation for testing and maintenance purposes may include up to 50 hours per calendar year for operation in nonemergency situations as provided in 40 CFR 60.4211(f). To determine the duration of operation, the owner/operator shall install a non-resettable hour meter for each emergency engine. [40 CFR 60 Subpart IIII, 40 CFR 60 Subpart ZZZZ, R307-401-8] II.B.4.b.1 Compliance with the limit of the hours of operation shall be determined by installation of an hour meter on the emergency generator engine or by recording hours of operation in an operations log. Records documenting the operation of the emergency generator engine shall be kept in a log and shall include the following: A. The date the emergency generator engine was used; B. The duration of operation each day in hours; and C. The reason for the emergency generator engine usage. [R307-401-8] II.B.4.b.2 To determine compliance with the rolling 12-month total, the owner/operator shall calculate a new 12-month total by the twentieth day of each month using data from the previous 12 months. [R307-401-8] II.B.4.c The owner/operator shall install emergency and non-emergency generator engines certified to meet Tier 4 emission standards. [R307-401-8] II.B.4.c.1 The owner/operator shall keep a record of the manufacturer's emission rate certification for the life of the equipment. [R307-401-8] II.B.5 Baghouse Requirements II.B.5.a Visible emissions from baghouses shall not exceed the following opacity limits: A. Main Dryer Baghouse - 10%. B. Glazing Dryer Baghouse - 10%. C. All Other Baghouses - 7%. [R307-401-8] II.B.5.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. [R307-205, R307-401-8] DAQE-IN144290009-24 Page 12 II.B.5.b Each baghouse shall operate within the static pressure range recommended by the manufacturer for normal operations. Manometer or magnehelic pressure gauges shall be installed to measure the differential pressure across each of the baghouses. The monitoring device shall be accurate within plus or minus one (1) inch of water column. The pressure gauges shall be located such that an inspector/operator can safely read the indicator at any time. [R307-401-8] II.B.5.b.1 Pressure drop readings shall be recorded at least once during each week of operation. Records documenting these inspections shall be kept in a log and shall include the following: A. Unit identification; B. Manufacturer recommended pressure drop for the unit; C. Weekly pressure drop readings; and D. Date of bag replacement, if applicable. [R307-401-8] II.B.5.b.2 The instrument shall be calibrated in accordance with the manufacturer's instructions or recommendations. Documentation of calibrations shall be maintained. [R307-401-8] II.B.5.c Emissions of PM10 and PM2.5 from the baghouses to the atmosphere shall not exceed the following rates and concentrations, based on an average of three (3) test runs: Processing Facility Baghouses PM10 and PM2.5 Emission Point Emission Rate (lb/hr) Concentration 68 degrees F, 29.92 in Hg (grains/dscf) Compaction Baghouse 1.5** 0.005** Main Dryer Baghouse 1.2* 0.010* Glazing Dryer Baghouse 0.6* 0.010* *Includes both filterable and condensable particulates **Includes filterable particulates only. [R307-401-8] II.B.5.c.1 Testing Frequency A. Initial compliance testing is required on all above listed emission sources. The initial test shall be performed as soon as possible and in no case later than 180 days after the startup of each unit. B. Subsequent compliance tests shall be done on each emission source at least once every five (5) years subsequent to the initial compliance test. The Director may require testing at any time. If an existing source is modified, a compliance test is required on the modified emission point that has an emission rate limit. [R307-401-8] II.B.5.c.2 Notification The Director shall be notified at least 30 days prior to conducting any required emission testing. A source test protocol shall be submitted to DAQ. The source test protocol shall be approved by the Director prior to performing the test(s). The source test protocol shall outline the proposed test methodologies, stack to be tested, and procedures to be used. A pretest conference shall be held, if directed by the Director. [R307-165] DAQE-IN144290009-24 Page 13 II.B.5.c.3 Sample Location The emission point shall be designed to conform to the requirements of 40 CFR 60, Appendix A, Method 1, or other EPA-approved methods acceptable to the Director. An Occupational Safety and Health Administration (OSHA) or Mine Safety and Health Administration (MSHA) approved access shall be provided to the test location. [R307-165] II.B.5.c.4 Calculations To determine mass emission rates (lb/hr, etc.) the pollutant concentration as determined by the appropriate methods herein shall be multiplied by the volumetric flow rate and any necessary conversion factors determined by the Director, to give the results in the specified units of the emission limitation. [R307-165] II.B.5.c.5 New Source Operation For a new source/emission point, the production rate during all compliance testing shall be no less than 90% of the production rate listed in this AO. If the maximum AO allowable production rate has not been achieved at the time of the test, the following procedure shall be followed: 1) Testing shall be at no less than 90% of the production rate achieved to date. 2) If the test is passed, the new maximum allowable production rate shall be 110% of the tested achieved rate, but not more than the maximum allowable production rate. This new allowable maximum production rate shall remain in effect until successfully tested at a higher rate. 3) The owner/operator shall request a higher production rate when necessary. Testing at no less than 90% of the higher rate shall be conducted. A new maximum production rate (110% of the new rate) will then be allowed if the test is successful. This process may be repeated until the maximum AO production rate is achieved. [R307-165] II.B.5.c.6 Existing Source Operation For an existing source/emission point, the production rate during all compliance testing shall be no less than 90% of the maximum production achieved in the previous three (3) years. [R307-165] II.B.5.c.7 Volumetric Flow Rate 40 CFR 60, Appendix A, Method 2 or other EPA-approved testing methods acceptable to the Director. [R307-165] DAQE-IN144290009-24 Page 14 II.B.5.c.8 PM10/PM2.5 For baghouse stacks in which no liquid drops are present, the following methods shall be used: 40 CFR 51, Appendix M, Methods 201 or 201a, or other EPA-approved testing method, as acceptable by the Director. The back half condensable particulate emissions shall also be tested (where applicable) using 40 CFR 51, Appendix M Method 202, or other EPA-approved testing method, acceptable to the Director. All particulate captured using Method 202 shall be considered PM2.5. The only baghouse sources that will emit condensables are the Main Dryer Baghouse and the Glazing Dryer Baghouse. For baghouse stacks in which liquid drops are present, methods to eliminate the liquid drops should be explored. If no reasonable method to eliminate the drops exists, then the following methods shall be used: 40 CFR 60, Appendix A, Method 5, 5a, 5d, 5i, or other as appropriate. Using Method 5, all filterable particulate emissions shall be considered PM10, unless otherwise approved by the Director. The portion of the filterable particulate emissions considered PM2.5 shall be based on information in Appendix B of the fifth addition of the EPA document, AP-42, or other data acceptable to the Director. The back half condensable particulate emissions shall also be tested using 40 CFR 51, Appendix M Method 202, or other EPA-approved testing method, acceptable to the Director. All particulate captured using Method 202 shall be considered PM2.5. [R307-165] II.B.5.c.9 Reporting The results of stack testing shall be submitted to the Director within 60 days of completion of the testing. Reports shall clearly identify results as compared to permit limits and indicate compliance status. [R307-165] II.B.6 Dryer and steam Boiler Requirements II.B.6.a The owner/operator shall use only propane and natural gas as a fuel in the dryers. [R307-401-8] II.B.6.b The owner/operator shall install: A. Dryers that are certified to meet a NOx emission rate of 25 ppmvd or less, and; B. The steam boiler is certified to meet a NOx emission rate of 13 ppmvd or less. [R307-401-8] II.B.6.b.1 The owner/operator shall keep a record of the manufacturer's certification of the emission rate for each unit. The record shall be kept for the life of the equipment. [R307-401-8] II.B.6.c The owner/operator shall route emissions from each Dryer through a baghouse prior to venting to the atmosphere. [R307-401-8] II.B.7 Engine Fuel Requirements II.B.7.a The owner/operator shall only use diesel fuel (e.g. fuel oil #1, #2, or diesel fuel oil additives) as fuel in the emergency engines, fire pumps, pond pumps, and Generator Sets. [R307-401-8] II.B.7.a.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.7.a.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] DAQE-IN144290009-24 Page 15 PERMIT HISTORY This Approval Order shall supersede (if a modification) or will be based on the following documents: Supersedes AO DAQE-AN144290005A-19 dated August 13, 2019 Is Derived From NOI dated October 31, 2023 Incorporates Additional Information dated December 1, 2023 Incorporates Additional Information dated December 11, 2023 Incorporates Additional Information dated February 29, 2024 DAQE-IN144290009-24 Page 16 ACRONYMS The following lists commonly used acronyms and associated translations as they apply to this document: 40 CFR Title 40 of the Code of Federal Regulations AO Approval Order BACT Best Available Control Technology CAA Clean Air Act CAAA Clean Air Act Amendments CDS Classification Data System (used by 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-NN144290009-24 April 4, 2024 Millard County Chronicle Progress Legal Advertising Dept P.O. Box 249 Delta (Millard), UT 84624 RE: Legal Notice of Intent to Approve This letter will confirm the authorization to publish the attached NOTICE in the Millard County Chronicle Progress on April 10, 2024. Please mail the invoice and affidavit of publication to the Utah State Department of Environmental Quality, Division of Air Quality, P.O. Box 144820, Salt Lake City, Utah 84114-4820. If you have any questions, contact Jeree Greenwood, who may be reached at (385) 306-6514. Sincerely, {{$s }} Jeree Greenwood Office Technician Enclosure cc: Six County Association of Governments cc: Millard County 195 North 1950 West • Salt Lake City, UT Mailing Address: P.O. Box 144820 • Salt Lake City, UT 84114-4820 Telephone (801) 536-4000 • Fax (801) 536-4099 • T.D.D. (801) 903-3978 www.deq.utah.gov Printed on 100% recycled paper State of Utah SPENCER J. COX Governor DEIDRE HENDERSON Lieutenant Governor Department of Environmental Quality Kimberly D. Shelley Executive Director DIVISION OF AIR QUALITY Bryce C. Bird Director DAQE-NN144290009-24 Page 2 NOTICE A Notice of Intent for the following project submitted in accordance with R307-401-1, Utah Administrative Code (UAC), has been received for consideration by the Director: Company Name: Peak Minerals Incorporated Location: Peak Minerals Incorporated - Sevier Playa Potash Project – Sevier Playa Lakeview Yard, 36200 West Crystal Peak Spur Road, Delta, UT Project Description: Peak Minerals Incorporated, dba Crystal Peak Minerals (CPM), is requesting approval to construct and operate a potash mining project, the Sevier Playa Potash Project, in Millard County. CPM will produce approximately 372,000 tons per year of potash in the form of potassium sulfate (K2SO4), also known as sulfate of potash (SOP), and other associated minerals from salts present in the brines of the playa. 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 May 10, 2024 will be considered in making the final decision on the approval/disapproval of the proposed project. Email comments will also be accepted at jjenks@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: April 10, 2024 {{#s=Sig_es_:signer1:signature}} 4/11/24, 11:17 AM utahlegals.com/(S(mwuuvwhoafczu2kxq5ozyevq))/DetailsPrint.aspx?SID=mwuuvwhoafczu2kxq5ozyevq&ID=182591 https://www.utahlegals.com/(S(mwuuvwhoafczu2kxq5ozyevq))/DetailsPrint.aspx?SID=mwuuvwhoafczu2kxq5ozyevq&ID=182591 1/2 Millard County Chronicle Progress Publication Name: Millard County Chronicle Progress Publication URL: Publication City and State: Delta, UT Publication County: Millard Notice Popular Keyword Category: Notice Keywords: peak Notice Authentication Number: 202404111216596123173 1761527914 Notice URL: Public Notice: Peak Minerals Inc Back Notice Publish Date: Wednesday, April 10, 2024 Notice Content 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: Peak Minerals Incorporated Location: Peak Minerals Incorporated - Sevier Playa Potash Project – Sevier Playa Lakeview Yard, 36200 West Crystal Peak Spur Road, Delta, UT Project Description: Peak Minerals Incorporated, dba Crystal Peak Minerals (CPM), is requesting approval to construct and operate a potash mining project, the Sevier Playa Potash Project, in Millard County. CPM will produce approximately 372,000 tons per year of potash in the form of potassium sulfate (K2SO4), also known as sulfate of potash (SOP), and other associated minerals from salts present in the brines of the playa. 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 May 10, 2024 will be considered in making the final decision on the approval/disapproval of the proposed project. Email comments will also be accepted at jjenks@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 4/11/24, 11:17 AM utahlegals.com/(S(mwuuvwhoafczu2kxq5ozyevq))/DetailsPrint.aspx?SID=mwuuvwhoafczu2kxq5ozyevq&ID=182591 https://www.utahlegals.com/(S(mwuuvwhoafczu2kxq5ozyevq))/DetailsPrint.aspx?SID=mwuuvwhoafczu2kxq5ozyevq&ID=182591 2/2 Director to fully consider the substance and significance of the issue. Published in the Millard County Chronicle Progress April 10, 2024. Back DAQE- RN144290009 March 26, 2024 Michael LeBaron Peak Minerals Inc. 10808 South River Front Parkway Suite 343 South Jordan, UT 84095 mike@peakminerals.com Dear Michael LeBaron, Re: Engineer Review: Minor Modification to AO DAQE-AN144290005A-19 for the Sevier Playa Potash Project Project Number: N144290009 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. Peak Minerals Inc. should complete this review within 10 business days of receipt. Peak Minerals Inc. should contact John Jenks at (385) 306-6510 if there are questions or concerns with the review of the draft permit conditions. Upon resolution of your concerns, please email John Jenks at jjenks@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 Peak Minerals Inc. does not respond to this letter within 10 business days, the project will move forward without source concurrence. If Peak Minerals Inc. 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 N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 1 UTAH DIVISION OF AIR QUALITY ENGINEER REVIEW SOURCE INFORMATION Project Number N144290009 Owner Name Peak Minerals Inc. Mailing Address 10808 South River Front Parkway Suite 343 South Jordan, UT, 84095 Source Name Peak Minerals Inc. - Sevier Playa Potash Project Source Location Sevier Playa Lakeview Yard 36200 West Crystal Peak Spur Road Delta, UT 84624 UTM Projection 314,505 m Easting, 4,313,105 m Northing UTM Datum NAD83 UTM Zone UTM Zone 12 SIC Code 1474 (Potash, Soda, & Borate Minerals) Source Contact Michael LeBaron Phone Number (801) 920-4421 Email mike@peakminerals.com Billing Contact Blake Measom Phone Number 801-913-3754 Email blake@peakminerals.com Project Engineer John Jenks, Engineer Phone Number (385) 306-6510 Email jjenks@utah.gov Notice of Intent (NOI) Submitted November 1, 2023 Date of Accepted Application January 15, 2024 Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 2 SOURCE DESCRIPTION General Description Peak Minerals Inc. (Peak Minerals), will operate a potash mining project, the Sevier Playa Potash Project, in Millard County. Peak Minerals will produce potash in the form of potassium sulfate (K2SO4), also known as sulfate of potash (SOP), and magnesium chloride from salts present in the brines of the playa. The site will consist of the following major features: 1) brine extraction system consisting of canals, trenches, and wells; 2) recharge system consisting of canals and trenches. Fresh water is introduced to the extraction system to maintain hydraulic head; 3) evaporation ponds consisting of preconcentration and production ponds. This will concentrate the brine to the saturation point. salts will precipitate within each of the ponds. At the pre- concentration ponds, sodium chloride (NaCl) wet harvesting will occur via a dredge, and solid NaCl storage areas (salt pads) allow for additional potassium recovery.; 4) Waste Product Storage Area; and 5) Processing Facility. Brines will be extracted from below the surface of the Sevier Playa and concentrated by solar evaporation in a series of preconcentration ponds. The potassium-rich salts harvested from the production ponds will be windrowed and then hauled to the processing facility for final treatment. Process tailings will be loaded and hauled to the tailings management area. MOP will be imported to the processing facility where it will be reacted with the residual brine containing magnesium sulfate to increase SOP production. In the processing facility muriate of potash (MOP) reacts with the residual brine containing magnesium sulfate to increase SOP production. Raw potash salts in the processing facility will go through the process feed. This step will convey salts from a hopper into a crusher to be sized. A crushed salt slurry will then enter the conversion circuit. In this step, high-sulfate brine from the halite leach step will cause the mixed potassium pond salts to form schoenite. Along with schoenite, halite and magnesium sulfate are expected to be present. Then the slurry will enter conditioning and flotation to remove insolubles. Insolubles are then conveyed to the tailing management area. Schoenite will be separated from other salts and slimes by adding flotation reagents and oils to the potash salt slurry. Flotation concentrate will be centrifuged, and the solids will be washed to remove brine and then sent to the leach reactor. The next step is SOP leach and crystallization where the SOP crystals will be recovered from the brine by a combination of cyclones and centrifuges. Potassium chloride will react with the magnesium sulfate in solution to form additional SOP and magnesium chloride. The last steps are drying, handling, and shipping. The processing facility is also exploring the opportunity to produce de-sulfated magnesium chloride (MgCl2) brine and bischofite flakes, after SOP production is established and running. NSR Classification: Minor Modification at Minor Source Source Classification Located in Attainment Area, Millard County Airs Source Size: SM Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 3 Applicable Federal Standards NSPS (Part 60), A: General Provisions NSPS (Part 60), Dc: Standards of Performance for Small Industrial-Commercial-Institutional Steam Generating Units NSPS (Part 60), IIII: Standards of Performance for Stationary Compression 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 Minor Modification to AO DAQE-AN144290005A-19 for the Sevier Playa Potash Project Project Description Peak Minerals is requesting approval to construct and operate the previously permitted potash mining project. This modification is a review and revision of the previously proposed operations. Since the previous NOI, process changes include the addition of magnesium chloride processing and shipping over rail transport have been included. Emissions from this operation are generated from material handling and heating. The majority of pre-process operations are done under wet conditions. EMISSION IMPACT ANALYSIS The modeling analysis can be found in DAQE-MN144290009-24, which is attached to the project file. The results of the modeling show predicted impacts below each of the relevant NAAQS for the modeled pollutants. No additional requirements are suggested by modeling. For the specifics of the modeling, please see the modeling memorandum. [Last updated February 27, 2024] Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 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 -15192 10689.00 Carbon Monoxide -82.35 15.00 Nitrogen Oxides -13.72 12.00 Particulate Matter - PM10 -153.74 17.00 Particulate Matter - PM10 (Fugitives) -20.56 95.00 Particulate Matter - PM2.5 -36.03 16.00 Particulate Matter - PM2.5 (Fugitives) 1.33 17.00 Sulfur Dioxide -0.11 0.05 Volatile Organic Compounds -5.12 1.10 Hazardous Air Pollutant Change (lbs/yr) Total (lbs/yr) Generic HAPs (CAS #GHAPS) 42 110 Change (TPY) Total (TPY) Total HAPs -0.28 0.06 Note: Change in emissions indicates the difference between previous AO and proposed modification. Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 5 Review of BACT for New/Modified Emission Units 1. BACT review regarding New Equipment and Operations The source evaluated BACT for each operation and pollutant, UDAQ reviewed the submitted BACT analysis and agrees with the following conclusions: Fluidized Bed Dryers PM10, PM2.5: Use of a baghouse and maintaining visible emissions at or below 10% opacity NOx: Good Design/Combustion Practices, Low NOx Burners (25 ppmv or less) VOC, CO, SO2: Good Combustion Practices, Propane Fuel Propane Boiler PM10, PM2.5: Good Combustion Practices, Propane Fuel and maintaining visible emissions at or below 10% opacity NOx: Good Design/Combustion Practices, Ultra-Low NOx (13 ppmv or less) Stationary Non-Emergency Engines PM10, PM2.5, NOx, VOC, and CO Tier 4-Certified Engine, SO2 controlled with Ultra-Low Sulfur Diesel (15 ppm sulfur maximum) and maintaining visible emissions at or below 20% Stationary Emergency Engines PM10, PM2.5, NOX, VOC and, CO Tier 4-Certified Engine, SO2 controlled with Ultra-Low Sulfur Diesel and maintaining visible emissions at or below 20% Baghouse-Controlled Material Handling and Processing Equipment PM10, PM2.5 Use of a baghouse and maintaining visible emissions at or below 7% opacity limit Enclosed Material Handling and Processing Equipment PM10, PM2.5: Enclosing processes and maintain visible emissions at or below 20% opacity limit Fugitive Dust Sources PM10, PM2.5: Use of chemical suppressants and water on disturbed areas and haul roads to maintain visible emissions at or below 20% opacity. Maintain and update the Fugitive Dust Control Plan. [Last updated February 27, 2024] SECTION I: GENERAL PROVISIONS The intent is to issue an air quality AO authorizing the project with the following recommended conditions and that failure to comply with any of the conditions may constitute a violation of the AO. (New or Modified conditions are indicated as “New” in the Outline Label): I.1 All definitions, terms, abbreviations, and references used in this AO conform to those used in the UAC R307 and 40 CFR. Unless noted otherwise, references cited in these AO conditions refer to those rules. [R307-101] I.2 The limits set forth in this AO shall not be exceeded without prior approval. [R307-401] Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 6 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 every 18 months from the date of this AO until construction is completed to demonstrate reasonable construction progress. 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 Sevier Playa Potash Project II.A.2 NEW MgCl2 Steam Boiler Rating: 15 MMBtu/hr Fuel: Propane NSPS Applicability: Subpart Dc Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 7 II.A.3 Drying and sizing fluid bed dryer Heat Input Rating: 4.4 MMBtu/hr Fuel: Propane Control: Main Dryer Baghouse II.A.4 Glazing Fluid Bed Dryer Heat Input Rating: 2 MMBtu/hr Fuel: Propane Control: Glazing Dryer Baghouse II.A.5 Compaction Baghouse Flow Rate: 35,000 acfm Description: Controls emissions from all compaction operations including crushers, screens, and material handling (conveyors, bucket elevators, magnetic chutes, diverters, compactor, flake breaker, and bin) II.A.6 Main Dryer Baghouse Flow Rate: 14,125 acfm Description: Controls emissions from the Fluid Bed Dryer II.A.7 Glazing Dryer Baghouse Flow Rate: 6,769 acfm Description: Controls emissions from drop points, conveyors, chute, bucket elevator, and the Glazing Fluid Bed Dryer II.A.8 Loadout Silo #1 Baghouse Flow Rate: 1,500 acfm Description: Controls emissions from loadout silo II.A.9 MOP Silo Dust Collector Flow Rate: 1,900 acfm Description: Controls MOP silo II.A.10 Bagging Plant Buffer Silo Baghouse Flow Rate: 1,500 acfm Description: Controls bagging operations, such as conveyors, silo, bucket elevator, and bagging filling station II.A.11 Quick Lime Silo Bin Vent Flow Rate: 1,900 acfm II.A.12 NEW 50 Lb Bischofite Silo Bin Vent 1,900 acfm II.A.13 NEW 1 Ton Bischofite Silo Vent 1,900 acfm Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 8 II.A.14 Material Handling Equipment Various material handling equipment, including conveyors, bucket elevators, chutes, six silos, feeder hoppers, diverter, flake breaker, bin, compactor, drum, drier/cooler, filling station, and apron feeder. II.A.15 Screens and Crushers Controlled by Wet Process Screens: Mixed Salts Screen Capacity 307 TPH Controlled by Compaction Baghouse and Glazing Dryer Baghouse Crushers Dryer Oversize Roll Crusher Capacity: 20.4 TPH Compaction Flake Breaker Capacity: 95 TPH Compaction Double Roll Crusher Capacity: 25 TPH Screens Product Screen Capacity: 107 TPH Compaction Screen Capacity:118 TPH Granular Product Glazing Screen Capacity: 39 TPH Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 9 II.A.16 Eight Generator Sets Fuel: Diesel Certified Tier 4 NSPS Applicability: Subpart IIII MACT Applicability: Subpart ZZZZ Generator Set 1, 2, and 3 Rating: 53 hp Each Generator Set 4 Rating:139 hp Generator Set 5 and 6 Rating: 59 hp Each Generator Set 7 Rating: 111 hp Generator Set 8 Rating: 78 hp II.A.17 One Fire Pump Engine Rating: 100 hp Fuel: Diesel MACT Applicability: Subpart ZZZZ II.A.18 Two Emergency Generator Engines Fuel: Diesel Certified Tier 4 Rating: 1,342 hp NSPS Applicability: Subpart IIII MACT Applicability: Subpart ZZZZ II.A.19 NEW Three Mobile Pumps Fuel: Diesel Rating: 20 hp II.A.20 Supporting Equipment Supporting equipment including diesel dispensing facility, diesel storage tanks 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): Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 10 II.B REQUIREMENTS AND LIMITATIONS II.B.1 Site-Wide Requirements II.B.1.a NEW The owner/operator shall not produce more than 215,000 tons per year of sulfates of potash and 300,000 tpy of magnesium chloride and other associated minerals per rolling 12-month period. [R307-401-8] II.B.1.a.1 NEW Compliance with the production limitation shall be determined on a rolling 12-month total. A new 12-month total shall be calculated using data from the previous 12 months. Monthly calculations shall be made no later than 20 days after the end of each calendar month. Records of production shall be kept for all periods when the plant is in operation. Production shall be determined by examination of production records, which will be maintained by Peak Minerals and housed in the administrative offices onsite. The records of production shall be kept on a daily basis. [R307-401-8] II.B.1.b Unless otherwise specified in this AO, visible emissions from any stationary and fugitive dust source shall not exceed 20% opacity. [R307-401-8] II.B.1.b.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. [R307-205] II.B.1.c The owner/operator shall comply with the latest version of the FDCP approved by the Director. The FDCP shall address the control of all fugitive dust sources at this source. [R307- 401-8] II.B.2 Haul Road and Disturbed Areas Requirements II.B.2.a Visible emissions in disturbed areas and unpaved haul roads from haul trucks and mobile equipment and windblown dust in operational areas shall not exceed 20% opacity at any point. [R307-205-4, R307-401-8] II.B.2.a.1 Visible emission determinations for fugitive dust from operational disturbed areas shall use Method 9. However, with respect to emissions from mobile or intermittent sources, the normal requirement for observations to be made at 15-second intervals over a six-minute period shall not apply. Visible emissions shall be observed at the densest point of the plume but at a point not less than one-half vehicle length behind the vehicle and not less than one-half the height of the vehicle. [R307-201-3, R307-205-4] II.B.2.b NEW The owner/operator shall limit disturbed areas to the following: A. On-Playa Disturbed Areas - 4.6 acres per day B. Production Ponds Disturbed Areas - 1.8 acres per day Disturbed areas include berms, playa surfaces, and all areas disturbed by operational activities, such as bulldozing, scraping, grading, etc. [R307-401-8] II.B.2.b.1 To determine compliance with the maximum daily limits for disturbed areas, the owner/operator shall perform daily visual inspections. Records of daily visual inspections shall be maintained for all periods when the plant is in operation. The Director may require a survey of disturbed areas at any time. [R307-401-8] Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 11 II.B.2.c NEW All operational disturbed areas and haul roads shall be sprayed with water, brine, or a chemical suppressant to control fugitive dust and maintain the opacity limit listed in this AO. The owner/operator may stop applying water when the temperature is below freezing or when the area is wet from precipitation. Records of water and/or chemical treatment shall be kept for all periods when the plant is in operation. The records shall include the following items: A. Date B. Location of treatment C. Rainfall received, if any, and approximate amount D. Records of temperature if the temperature is below freezing. [R307-401-8] II.B.3 Material Handling and Processing Equipment Requirements II.B.3.a All material handling and processing equipment used for non-slurried material shall be controlled by baghouses, full enclosures, or partial enclosures. All material handling and processing equipment not controlled by baghouses shall be controlled by enclosed or partially enclosed structures or located within buildings. Partial enclosures include conveyor covers for conveyors and socks/retractable chutes for transfer points. [R307-401-8] II.B.3.b Visible emissions from material handling and processing equipment located outdoors shall not exceed 20% opacity. [R307-401-8] II.B.3.b.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. [R307-205-4, R307-401-8] II.B.3.c The owner/operator shall allow no visible emissions from tailings material stored at the Waste Product Storage Area. [R307-401-8] II.B.4 Emergency and Non-Emergency Engine Requirements II.B.4.a Visible emissions from diesel-fired emergency and non-emergency generator engines shall not exceed 20% opacity. [R307-401-8] II.B.4.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. [R307-205, R307-401-8] II.B.4.b NEW Each emergency generator engine shall not exceed 100 hours of operation for testing and maintenance per rolling 12-month period. The 100 hours of operation for testing and maintenance purposes may include up to 50 hours per calendar year for operation in nonemergency situations as provided in 40 CFR 60.4211(f). To determine the duration of operation, the owner/operator shall install a non-resettable hour meter for each emergency engine. [40 CFR 60 Subpart IIII, 40 CFR 60 Subpart ZZZZ, R307- 401-8] Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 12 II.B.4.b.1 Compliance with the limit of the hours of operation shall be determined by installation of an hour meter on the emergency generator engine or by recording hours of operation in an operations log. Records documenting the operation of the emergency generator engine shall be kept in a log and shall include the following: A. The date the emergency generator engine was used; B. The duration of operation each day in hours; and C. The reason for the emergency generator engine usage. [R307-401-8] II.B.4.b.2 To determine compliance with the rolling 12-month total, the owner/operator shall calculate a new 12-month total by the twentieth day of each month using data from the previous 12 months. [R307-401-8] II.B.4.c The owner/operator shall install emergency and non-emergency generator engines certified to meet Tier 4 emission standards. [R307-401-8] II.B.4.c.1 The owner/operator shall keep a record of the manufacturer's emission rate certification for the life of the equipment. [R307-401-8] II.B.5 Baghouse Requirements II.B.5.a Visible emissions from baghouses shall not exceed the following opacity limits: A. Main Dryer Baghouse - 10% B. Glazing Dryer Baghouse - 10% C. All Other Baghouses - 7%. [R307-401-8] II.B.5.a.1 Opacity observations of emissions from stationary sources shall be conducted in accordance with 40 CFR 60, Appendix A, Method 9. [R307-205, R307-401-8] II.B.5.b Each baghouse shall operate within the static pressure range recommended by the manufacturer for normal operations. Manometer or magnehelic pressure gauges shall be installed to measure the differential pressure across each of the baghouses. The monitoring device shall be accurate within plus or minus one inch of water column. The pressure gauges shall be located such that an inspector/operator can safely read the indicator at any time. [R307-401-8] II.B.5.b.1 Pressure drop readings shall be recorded at least once during each week of operation. Records documenting these inspections shall be kept in a log and shall include the following: A. Unit identification; B. Manufacturer recommended pressure drop for the unit; C. Weekly pressure drop readings; and D. Date of bag replacement, if applicable. [R307-401-8] II.B.5.b.2 The instrument shall be calibrated in accordance with the manufacturer's instructions or recommendations. Documentation of calibrations shall be maintained. [R307-401-8] Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 13 II.B.5.c NEW Emissions of PM10 and PM2.5 from the baghouses to the atmosphere shall not exceed the following rates and concentrations, based on an average of three (3) test runs: Processing Facility Baghouses PM10 and PM2.5 Emission Point Emission Rate (lb/hr) Concentration 68 degrees F, 29.92 in Hg (grains/dscf) Compaction Baghouse 1.5** 0.005** Main Dryer Baghouse 1.2* 0.010* Glazing Dryer Baghouse 0.6* 0.010* *Includes both filterable and condensable particulates **Includes filterable particulates only. [R307-401-8] II.B.5.c.1 Testing Frequency A. Initial compliance testing is required on all above listed emission sources. The initial test shall be performed as soon as possible and in no case later than 180 days after the start up of each unit. B. Subsequent compliance tests shall be done on each emission source at least once every five years subsequent to the initial compliance test. The Director may require testing at any time. If an existing source is modified, a compliance test is required on the modified emission point that has an emission rate limit. [R307-401-8] II.B.5.c.2 Notification The Director shall be notified at least 30 days prior to conducting any required emission testing. A source test protocol shall be submitted to DAQ. The source test protocol shall be approved by the Director prior to performing the test(s). The source test protocol shall outline the proposed test methodologies, stack to be tested, and procedures to be used. A pretest conference shall be held, if directed by the Director. [R307-165] II.B.5.c.3 Sample Location The emission point shall be designed to conform to the requirements of 40 CFR 60, Appendix A, Method 1, or other EPA approved methods acceptable to the Director. An Occupational Safety and Health Administration (OSHA) or Mine Safety and Health Administration (MSHA) approved access shall be provided to the test location. [R307-165] II.B.5.c.4 Calculations: To determine mass emission rates (lb/hr, etc.) the pollutant concentration as determined by the appropriate methods herein shall be multiplied by the volumetric flow rate and any necessary conversion factors determined by the Director, to give the results in the specified units of the emission limitation. [R307-165] Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 14 II.B.5.c.5 New Source Operation: For a new source/emission point, the production rate during all compliance testing shall be no less than 90% of the production rate listed in this AO. If the maximum AO allowable production rate has not been achieved at the time of the test, the following procedure shall be followed: 1) Testing shall be at no less than 90% of the production rate achieved to date. 2) If the test is passed, the new maximum allowable production rate shall be 110% of the tested achieved rate, but not more than the maximum allowable production rate. This new allowable maximum production rate shall remain in effect until successfully tested at a higher rate. 3) The owner/operator shall request a higher production rate when necessary. Testing at no less than 90% of the higher rate shall be conducted. A new maximum production rate (110% of the new rate) will then be allowed if the test is successful. This process may be repeated until the maximum AO production rate is achieved. [R307-165] II.B.5.c.6 Existing Source Operation: For an existing source/emission point, the production rate during all compliance testing shall be no less than 90% of the maximum production achieved in the previous three (3) years. [R307-165] II.B.5.c.7 Volumetric Flow Rate: 40 CFR 60, Appendix A, Method 2 or other EPA approved testing methods acceptable to the Director. [R307-165] II.B.5.c.8 NEW PM10/PM2.5 For baghouse stacks in which no liquid drops are present, the following methods shall be used: 40 CFR 51, Appendix M, Methods 201 or 201a, or other EPA-approved testing method, as acceptable by the Director. The back half condensable particulate emissions shall also be tested (where applicable) using 40 CFR 51, Appendix M Method 202, or other EPA-approved testing method, acceptable to the Director. All particulate captured using Method 202 shall be considered PM2.5. The only baghouse sources that will emit condensables are the Main Dryer Baghouse and the Glazing Dryer Baghouse. For baghouse stacks in which liquid drops are present, methods to eliminate the liquid drops should be explored. If no reasonable method to eliminate the drops exists, then the following methods shall be used: 40 CFR 60, Appendix A, Method 5, 5a, 5d, 5i, or other as appropriate. Using Method 5, all filterable particulate emissions shall be considered PM10, unless otherwise approved by the Director. The portion of the filterable particulate emissions considered PM2.5 shall be based on information in Appendix B of the fifth addition of the EPA document, AP- 42, or other data acceptable to the Director. The back half condensable particulate emissions shall also be tested using 40 CFR 51, Appendix M Method 202, or other EPA-approved testing method, acceptable to the Director. All particulate captured using Method 202 shall be considered PM2.5. [R307-165] Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 15 II.B.5.c.9 Reporting The results of stack testing shall be submitted to the Director within 60 days of completion of the testing. Reports shall clearly identify results as compared to permit limits and indicate compliance status. [R307-165] II.B.6 NEW Dryer and steam Boiler Requirements II.B.6.a The owner/operator shall use only propane and natural gas as a fuel in the dryers. [R307-401- 8] II.B.6.b NEW The owner/operator shall install: A. Dryers that are certified to meet a NOx emission rate of 25 ppmvd or less, and; B. The steam boiler is certified to meet a NOx emission rate of 13 ppmvd or less. [R307-401- 8] II.B.6.b.1 The owner/operator shall keep a record of the manufacturer's certification of the emission rate for each unit. The record shall be kept for the life of the equipment. [R307-401-8] II.B.6.c NEW The owner/operator shall route emissions from each Dryer through a baghouse prior to venting to the atmosphere. [R307-401-8] II.B.7 NEW Engine Fuel Requirements II.B.7.a NEW The owner/operator shall only use diesel fuel (e.g. fuel oil #1, #2, or diesel fuel oil additives) as fuel in the emergency engines, fire pumps, pond pumps, and Generator Sets. [R307-401-8] II.B.7.a.1 NEW 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.7.a.2 NEW 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 N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 16 PERMIT HISTORY When issued, the approval order shall supersede (if a modification) or will be based on the following documents: Supersedes DAQE-AN144290005A-19 dated August 13, 2019 Is Derived From NOI dated October 31, 2023 Incorporates Additional Information dated December 1, 2023 Incorporates Additional Information dated December 11, 2023 Incorporates Additional Information dated February 29, 2024 REVIEWER COMMENTS 1. Comment regarding Emission Estimates: Emissions were estimated for the following sources: material handling and processing equipment, product dryers, stationary internal combustion engines, fugitive dust sources, and other supporting equipment (storage tanks). Material Handling and Processing Equipment Material handling and processing equipment emissions were estimated for both the Processing Facility. These include material drop points to conveyors, transfer equipment, storage bin and silos, product screens, and crushers. All these units were assumed to generate emissions unless the equipment only handles slurried material. Emissions from all the product screens and crushers and many of the material drop points will be controlled by baghouses. Emissions points not controlled by baghouses will be either fully or partially enclosed. A 70% control efficiency was applied to PM10 and PM2.5 for partial enclosures and a 90% control efficiency was applied to full enclosures, consistent with the TCEQ BACT guidelines and guidance for rock crushing operations. Emission factors for material transferred not controlled by baghouses were estimated using Equation 1 of EPA's AP-42 Section 13.2.4. This equation accounts for wind speed and moisture content of material being transferred. Wind speed of 0.1 meters/second (m/s) (0.22 miles per hour [mph]) for indoor sources was used, in accordance with Appendix D.2.4 to EPA's Risk Management Program Guidance for Offsite Consequence Analysis. For outdoor sources (i.e. uncontrolled enclosed material transfer points) a wind speed of 8.1 mph was used. This is based on the annual average of site- specific wind speed data. Moisture contents changes as material passes through the Processing Facility operation. The anticipated moisture contents are: 1.5 % at the compactor feed; 0.2% at the main SOP dryer outlet; 1.5% at the glazing outlet; and 0.2% at the dryer/cooler outlet (0.2%). For a conservative estimate, 0.2% was used for all internal Processing Facility material handling calculations. Moisture contents of 20% and 15% were used for material coming from the Production Ponds or insoluble tailing materials. As the screens and crushers will be controlled by baghouses, they were not estimated as stand-alone sources. Emissions for the sources controlled by baghouses were estimated based on the baghouse flow rate and the exhaust grain loadings. Baghouses controlling product dryers were assumed to have an exhaust grain loading of 0.01 gr/dscf for PM10 and PM2.5 (filterable + condensable). Baghouses controlling material handling sources were assumed to have an exhaust grain loading of 0.005 Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 17 gr/dscf for PM10 and PM2.5 (filterable only, since there are no expected condensable PM emissions from material drop points, screens, and crushers). Product Dryers and Steam Boiler Emissions were estimated from two propane-fired dryers and steam boiler. Criteria pollutant emissions from combustion were estimated based on the emission factors from EPA's AP-42 Section 1.5. HAPs emissions from combustion were estimated using the emission factors from San Joaquin Valley Air Pollution Control District (SJVAPCD). Emissions from the drying process were estimated based on the baghouse flow rates of 0.01 gr/dscf and the baghouse flow rates. Greenhouse gas emissions were based on emission factors in 40 CFR 98 Subpart C and global warming potentials in 40 CFR 98 Subpart A. [Last updated February 27, 2024] 2. Comment regarding Engine MACT & NSPS Applicability: 40 CFR 60 NSPS Subpart IIII applies to owners and operators of stationary compression ignition (CI) internal combustion engines (ICE) that commenced construction after July 11, 2005, where the CI ICE were manufactured after April 1, 2006, or owners and operators of stationary CI ICE that are modified or reconstructed after July 11, 2005. NSPS Subpart IIII contains requirements for emergency engines based on the maximum engine power, displacement, and model year of the engine. The emergency generator engine is required to meet Tier 2 emission standards for engines with a rated power kW > 560 found in 40 CFR 89.112 and 40 CFR 89.113. The 100 hp fire pump engine are required to meet emission standards in Table 4 for engines with a rated power <=100 hp <175 hp). The non-emergency engines will have a displacement of less than 10 liters per cylinder and will be subject to the emission standards in 40 CFR 1039.101. In addition, NSPS Subpart IIII contains other testing, monitoring, recordkeeping, and reporting requirements. 40 CFR 63 MACT Subpart ZZZZ applies to owners and operators of a stationary reciprocating internal combustion engine (RICE) at a major or area source of HAP emissions. Because the new engines are stationary RICE at an area source of HAP emissions, MACT Subpart ZZZZ will apply to this facility. A new or reconstructed stationary CI RICE located at an area source must meet the requirements of MACT Subpart ZZZZ by meeting the requirements of 40 CFR 60 Subpart IIII. No further requirements apply for such engines under MACT Subpart ZZZZ. [Last updated February 27, 2024] 3. Comment regarding Dryer MACT & NSPS Applicability: 40 CFR 60 NSPS Subpart Dc (Standards of Performance for Small Industrial-Commercial- Institutional Steam Generating Units) applies to each new steam generating unit that has a maximum design heat input capacity greater than or equal to 10 MMBtu/hr and less than 100 MMBtu/hr. The applicability date for NSPS Subpart Dc is June 9, 1989. Steam generating unit means a device that combusts any fuel and produces steam or heats water or heats any heat transfer medium. The source will operate one steam boiler that is within the definition; thus, 40 CFR 60 Subpart Dc applies to this boiler. The two dryers are smaller than 10 MMBtu/hr, thus they are not subject. 40 CFR 63 MACT Subpart JJJJJJ (National Emission Standards for Hazardous Air Pollutants for Industrial, Commercial, and Institutional Boilers Area Sources) applies to industrial, commercial, or institutional boilers located at an area source of HAP emissions. The dryers and steam boiler at this source do not meet the definition of a boiler as they are not producing steam or heating water. Therefore, 40 CFR 63 Subpart JJJJJJ does not apply. [Last updated February 27, 2024] Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 18 4. Comment regarding Mineral Processing Plant MACT & NSPS Applicability: "_40 CFR Part 60 Subpart OOO applies to select equipment at nonmetallic mineral processing plants that commenced construction, modification, or reconstruction after August 31, 1983. A nonmetallic mineral is defined in 60.671 as any of the eighteen listed minerals under this regulation or a mixture of which the majority is any of the listed minerals. SOP, or potassium sulfate, is not one of the listed minerals in this Subpart. The source will not be processing any sodium compounds, including sodium carbonate, sodium chloride, or sodium sulfate. Furthermore, in a 1998 applicability determination, EPA determined that NSPS Subparts OOO does not apply to potash facilities. Therefore, 40 CFR 60 Subpart OOO will not apply. 40 CFR Part 60 Subpart UUU applies to each calciner and dryer at a mineral processing plant. Mineral processing plant is defined as "any facility that processes or produces any of the following minerals, their concentrates or any mixture of which the majority (>50 percent) is any of the following minerals or a combination of these minerals: alumina, ball clay, bentonite, diatomite, feldspar, fire clay, fuller's earth, gypsum, industrial sand, kaolin, lightweight aggregate, magnesium compounds, perlite, roofing granules, talc, titanium dioxide, and vermiculite" SOP, or potassium sulfate, is not one of the listed minerals in this Subpart. Therefore, 40 CFR 60 Subpart UUU will not apply. [Last updated February 27, 2024] 5. 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. The Sevier Playa Potash Site will be subject to NSPS Subpart IIII under Section 111 and MACT Subpart ZZZZ under Section 112. However, these Subparts exempt sources from the obligation to obtain a permit under 40 CFR part 70 (Title V permit) if the source is not otherwise required by law to obtain a Title V permit. Therefore, Title V does not apply to this facility. [Last updated February 27, 2024] Engineer Review N144290009: Peak Minerals Inc. - Sevier Playa Potash Project March 26, 2024 Page 19 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 1/2/24, 11:35 PM State of Utah Mail - Peak Minerals NOI Package https://mail.google.com/mail/u/0/?ik=b363bbe9c3&view=pt&search=all&permmsgid=msg-f:1784106729683212219&simpl=msg-f:1784106729683212219 1/2 Sarah Foran <sforan@utah.gov> Peak Minerals NOI Package Ross Beardsley <rbeardsley@ramboll.com>Fri, Dec 1, 2023 at 11:52 AM To: Sarah Foran <sforan@utah.gov> Cc: mike <mike@peakminerals.com>, Woods Silleroy <woods@peakminerals.com>, dean <dean@peakminerals.com>, "adam.sarman@peakminerals.com" <adam.sarman@peakminerals.com>, "blake@peakminerals.com" <blake@peakminerals.com>, "Jon Black (jlblack@utah.gov)" <jlblack@utah.gov>, Megan Neiderhiser <mneiderhiser@ramboll.com>, Rei Zhang <RZHANG@ramboll.com>, Brandon Yee <BYEE@ramboll.com> Hi Sarah, The NOI application with all appendices has been uploaded at the link below. Appendix C contains the potential emissions calculations (starting on page 152) and Appendix D provides the supporting information for BACT (starting on page 197). Please confirm receipt and let me know if you have trouble accessing the file. SPP NOI Application Full - 31Oct2023.pdf We will follow up with additional information from the manufacturer on the ultra-low NOx burners as soon as possible. Please don’t hesitate to reach out with any other comments or questions. Thanks! Ross Ross Beardsley Managing Consultant D +1 415 899-0753 M +1 407 619-7740 rbeardsley@ramboll.com Classification: Confidential 1/2/24, 11:35 PM State of Utah Mail - Peak Minerals NOI Package https://mail.google.com/mail/u/0/?ik=b363bbe9c3&view=pt&search=all&permmsgid=msg-f:1784106729683212219&simpl=msg-f:1784106729683212219 2/2 From: Megan Neiderhiser <mneiderhiser@ramboll.com> Sent: Friday, December 1, 2023 9:21 AM To: Sarah Foran <sforan@utah.gov> [Quoted text hidden] [Quoted text hidden] 1/2/24, 11:36 PM State of Utah Mail - Peak Minerals NOI Package https://mail.google.com/mail/u/0/?ik=b363bbe9c3&view=pt&search=all&permmsgid=msg-f:1785032227017793165&simpl=msg-f:1785032227017793165 1/2 Sarah Foran <sforan@utah.gov> Peak Minerals NOI Package Ross Beardsley <rbeardsley@ramboll.com>Mon, Dec 11, 2023 at 5:02 PM To: Sarah Foran <sforan@utah.gov> Cc: mike <mike@peakminerals.com>, Woods Silleroy <woods@peakminerals.com>, dean <dean@peakminerals.com>, "adam.sarman@peakminerals.com" <adam.sarman@peakminerals.com>, "blake@peakminerals.com" <blake@peakminerals.com>, jlblack <jlblack@utah.gov>, Megan Neiderhiser <mneiderhiser@ramboll.com>, Rei Zhang <RZHANG@ramboll.com>, Brandon Yee <BYEE@ramboll.com> Hi Sarah, See attached for the technical justification for the 13 ppm NOx burners for the propane boiler. Please let us know if this addresses your comment and if you have any other questions or comments. Thanks, Ross Ross Beardsley Managing Consultant D +1 415 899-0753 M +1 407 619-7740 rbeardsley@ramboll.com Classification: Confidential From: Ross Beardsley <rbeardsley@ramboll.com> Sent: Friday, December 1, 2023 10:52 AM To: Sarah Foran <sforan@utah.gov> Cc: mike <mike@peakminerals.com>; Woods Silleroy <woods@peakminerals.com>; dean <dean@peakminerals.com>; adam.sarman@peakminerals.com; blake@peakminerals.com; Jon Black (jlblack@utah.gov) <jlblack@utah.gov>; Megan Neiderhiser <mneiderhiser@ramboll.com>; Rei Zhang <RZHANG@ramboll.com>; Brandon Yee <BYEE@ramboll.com> Subject: RE: Peak Minerals NOI Package Hi Sarah, 1/2/24, 11:36 PM State of Utah Mail - Peak Minerals NOI Package https://mail.google.com/mail/u/0/?ik=b363bbe9c3&view=pt&search=all&permmsgid=msg-f:1785032227017793165&simpl=msg-f:1785032227017793165 2/2 The NOI application with all appendices has been uploaded at the link below. Appendix C contains the potential emissions calculations (starting on page 152) and Appendix D provides the supporting information for BACT (starting on page 197). Please confirm receipt and let me know if you have trouble accessing the file. SPP NOI Application Full - 31Oct2023.pdf We will follow up with additional information from the manufacturer on the ultra-low NOx burners as soon as possible. Please don’t hesitate to reach out with any other comments or questions. Thanks! Ross Ross Beardsley Managing Consultant D +1 415 899-0753 M +1 407 619-7740 rbeardsley@ramboll.com From: Megan Neiderhiser <mneiderhiser@ramboll.com> [Quoted text hidden] [Quoted text hidden] Dept of Air Quality_letter of explanation_NOx emission propane and nat gas.pdf 99K DAQE-MN144290009-24 M E M O R A N D U M TO: John Jenks, NSR Engineer FROM: Jason Krebs, Air Quality Modeler DATE: January 22, 2024 SUBJECT: Modeling Analysis Review for the Notice of Intent for Crystal Peak Minerals – Sevier Playa Potash Project, Millard County, Utah _____________________________________________________________________________________ This is not a Major Prevention of Significant Deterioration (PSD) Source. I. OBJECTIVE Crystal Peak Minerals (Applicant) is seeking an approval order for their Sevier Playa Potash Project located in Millard County, Utah. The Applicant is requesting approval to construct and operate a potash mining project, the Sevier Playa Potash Project, in Millard County. The Applicant will produce approximately 215,000 tons per year of Sulfate of Potash (SOP) and 300,000 tons of other associated minerals from salts present in the brines of the playa. The site will consist of the following major components: 1) brine extraction system consisting of canals, trenches, and wells; 2) recharge system consisting of canals and trenches; 3) evaporation ponds consisting of preconcentration and production ponds; 4) Waste Product Storage Area; and 5) Processing Facilit y. The brines extracted from below the surface of the Sevier Playa are concentrated by solar evaporation in a series of preconcentration ponds. The potassium-rich salts precipitated in the production ponds will be harvested and transported to an on-lease Processing Facility, where the salts will be processed to produce saleable SOP, as well as other associated mineral products. The Rail Loadout Facility receives SOP from the Processing Facility for storage, screening, and loading for off-site shipment. 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 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 0 0 JK DAQE- MN144290009-24 Page 2 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 PM10 and PM2.5 triggered the requirement to model under R307-410. Modeling was performed by the Applicant. B. Assumptions 1. Topography/Terrain The Plant is at an elevation 4560 feet with distant terrain features that have little affect on concentration predictions. a. Zone: 12 b. Approximate Location: UTM (NAD83): 308800 meters East 4288000 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 On-site surface and offsite upper air data were used in the analysis consisting of the following: Surface – Onsite 10-meter tower: December 2011 thru November 2012 Upper Air – NWS Desert Rock, NV: December 2011 thru November 2012 DAQE- MN144290009-24 Page 3 6. Background Background concentrations were estimated based on ambient monitoring data collected onsite for PM10 and PM2.5. 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. 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 EMISSIONS Source UTM Coordinates Modeled Emission Rates Easting Northing PM10 (m) (m) (lb/hr) (tons/yr) hrs/year COMPACBH 308710 4288081 1.5 6.6 8760 MAINDRYBH 308709 4288093 1.2 5.2 8760 GLAZDRBH 308710 4288077 0.6 2.5 8760 LOSILOBV 308737 4288011 0.1 0.3 8760 BPSILOBV 308705 4288059 0.1 0.3 8760 QLSILOBV 308779 4288044 0.1 0.3 8760 BOILS 308759 4288037 0.1 0.5 8760 MOPSILOBV 308819 4288081 0.1 0.3 8760 FP1 308828 4288134 3.3E-03 1.6E-04 100 PMP1 308813 4289835 1.3E-02 1.0E-02 1488 PMP2 308814 4289505 1.3E-02 1.0E-02 1488 PMP3 306685 4289479 1.3E-02 1.0E-02 1488 EGEN1 308784 4288231 2.8E-03 1.4E-04 100 EGEN2 308790 4288231 2.8E-03 1.4E-04 100 GENSET1 313567 4302944 2.6E-03 1.1E-02 8760 GENSET2 313878 4296370 2.6E-03 1.1E-02 8760 GENSET3 313851 4291844 2.6E-03 1.1E-02 8760 GENSET4 317398 4311511 4.6E-03 2.0E-02 8760 DAQE- MN144290009-24 Page 4 GENSET5 318594 4315345 2.9E-03 5.4E-03 3648 GENSET6 319151 4317462 2.9E-03 5.4E-03 3648 GENSET7 311914 4290010 3.7E-03 6.7E-03 3648 GENSET8 306488 4289349 2.5E-03 4.6E-03 3648 URDA* 21.4 93.9 8760 Windblown Fugitives 857.5 102.9 240 Mobile Equip Fugitives 4.6 20.2 8760 Total 887.3 233.2 Source UTM Coordinates Modeled Emission Rates Easting Northing PM2.5 (m) (m) (lb/hr) (tons/yr) hrs/year COMPACBH 308710 4288081 1.5080 6.605 8760 MAINDRYBH 308709 4288093 1.1905 5.214 8760 GLAZDRBH 308710 4288077 0.5794 2.538 8760 LOSILOBV 308737 4288011 0.0643 0.282 8760 BPSILOBV 308705 4288059 0.0643 0.282 8760 QLSILOBV 308779 4288044 0.0794 0.348 8760 BOILS 308759 4288037 0.1111 0.487 8760 MOPSILOBV 308819 4288081 0.0794 0.348 8760 FP1 308828 4288134 0.0033 0.000 100 PMP1 308813 4289835 0.0135 0.010 1488 PMP2 308814 4289505 0.0135 0.010 1488 PMP3 306685 4289479 0.0135 0.010 1488 EGEN1 308784 4288231 0.0028 0.000 100 EGEN2 308790 4288231 0.0028 0.000 100 GENSET1 313567 4302944 0.0026 0.011 8760 GENSET2 313878 4296370 0.0026 0.011 8760 GENSET3 313851 4291844 0.0026 0.011 8760 GENSET4 317398 4311511 0.0046 0.020 8760 GENSET5 318594 4315345 0.0029 0.005 3648 GENSET6 319151 4317462 0.0029 0.005 3648 GENSET7 311914 4290010 0.0037 0.007 3648 GENSET8 306488 4289349 0.0025 0.005 3648 URDAF* 13.0470 57.146 8760 Windblown Fugitives 857.4790 102.897 240 Mobile Equip Fugitives 4.6072 20.179 8760 DAQE- MN144290009-24 Page 5 Total 878.8832 196.4318 *Unpaved Roads Disturbed Area Fugitives (truck traffic) 10. Source Location and Parameters See Appendix A for Source Parameters. 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 PM10 24- Hour 42.10 5 97.4 0.0 139.5 150 93.00% 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 PM2.5 24- Hour 10.60 5 11.8 0.00 22.4 35 64.00% 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 PM2.5 Annual 3.60 5 4.1 0.00 7.7 12 64.17% JK:jg DAQE- MN144290009-24 Page 6 Appendix A Source Type Source Parameters Elev, Ht Temp Flow Dia Sigma- Y Sigma- Z X-Dim Y- Dim Area (ft) (m) (ft) (K) (m/s) (ft) (m) (m) (m) (m) (m^2) COMPACBH POINT 4645.7 25.3 83.0 0 12.52 0.61 1 MAINDRYBH POINT 4645.7 25.3 83.0 400 12.02 0.61 1 GLAZDRBH POINT 4645.7 25.3 83.0 350 11.42 0.61 1 LOSILOBV POINT 4642.4 23.8 78.1 0 10.00 0.30 1 BPSILOBV POINT 4616.1 16.1 52.8 0 3.61 0.50 1 QLSILOBV POINT 4616.1 15.5 50.8 0 2.00 0.20 1 BOILS POINT 4616.1 15.2 49.9 380 2.00 0.46 1 MOPSILOBV POINT 4616.1 16.1 52.8 0 2.30 0.30 1 FP1 POINT 4573.2 3.0 9.8 948 9.20 0.20 1 PMP1 POINT 4534.4 3.0 9.8 713 84.90 0.10 1 PMP2 POINT 4535.4 3.0 9.8 713 84.90 0.10 1 PMP3 POINT 4535.4 3.0 9.8 713 84.90 0.10 1 EGEN1 POINT 4568.9 3.0 9.8 713 90.70 0.20 1 EGEN2 POINT 4568.9 3.0 9.8 713 90.70 0.20 1 GENSET1 POINT 4528.9 3.0 9.8 713 84.90 0.10 1 GENSET2 POINT 4530.8 3.0 9.8 713 84.90 0.10 1 GENSET3 POINT 4533.1 3.0 9.8 713 84.90 0.10 1 GENSET4 POINT 4532.2 3.0 9.8 713 84.90 0.10 1 GENSET5 POINT 4532.2 3.0 9.8 713 84.90 0.10 1 GENSET6 POINT 4533.1 3.0 9.8 713 84.90 0.10 1 GENSET7 POINT 4535.1 3.0 9.8 713 84.90 0.10 1 GENSET8 POINT 4536.1 3.0 9.8 713 84.90 0.10 1 TRPF001 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF002 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF003 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF004 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF005 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF006 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF007 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF008 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF009 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF010 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF011 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF012 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 7 TRPF013 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF014 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF015 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF016 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF017 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF018 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF019 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF020 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF021 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF022 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF023 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF024 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF025 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF026 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF027 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF028 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF029 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF030 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF031 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF032 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF033 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF034 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF035 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF036 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF037 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF038 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF039 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF040 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF041 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF042 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF043 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF044 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF045 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF046 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF047 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF048 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF049 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF050 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF051 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF052 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 8 TRPF053 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF054 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF055 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF056 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF057 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF058 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF059 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF060 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF061 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF062 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF063 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF064 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF065 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF066 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF067 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF068 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF069 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF070 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF071 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF072 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF073 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF074 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF075 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF076 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF077 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF078 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF079 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF080 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF081 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF082 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF083 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF084 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF085 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF086 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF087 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF088 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF089 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF090 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF091 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF092 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 9 TRPF093 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF094 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF095 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF096 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF097 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF098 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF099 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF100 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF101 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF102 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF103 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF104 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF105 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF106 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF107 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF108 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF109 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF110 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF111 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF112 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF113 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF114 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF115 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF116 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF117 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF118 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF119 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF120 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF121 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF122 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF123 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF124 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF125 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF126 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF127 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF128 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF129 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF130 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF131 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF132 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 10 TRPF133 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF134 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF135 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF136 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF137 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF138 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF139 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF140 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF141 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF142 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF143 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF144 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF145 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF146 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF147 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF148 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF149 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF150 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF151 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF152 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF153 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF154 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF155 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF156 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF157 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF158 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF159 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF160 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF161 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF162 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF163 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF164 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF165 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF166 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF167 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF168 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF169 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF170 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF171 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF172 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 11 TRPF173 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF174 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF175 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF176 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF177 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF178 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF179 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF180 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF181 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF182 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF183 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF184 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF185 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF186 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF187 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF188 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF189 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF190 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF191 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF192 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF193 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF194 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF195 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF196 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF197 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF198 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF199 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF200 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF201 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF202 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF203 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF204 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF205 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF206 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF207 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF208 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF209 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF210 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF211 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF212 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 12 TRPF213 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF214 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF215 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF216 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF217 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF218 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF219 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF220 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF221 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF222 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF223 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF224 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF225 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF226 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF227 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF228 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF229 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF230 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF231 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF232 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF233 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF234 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF235 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF236 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF237 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF238 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF239 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF240 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF241 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF242 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF243 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF244 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF245 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF246 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF247 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF248 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF249 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF250 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF251 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF252 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 13 TRPF253 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF254 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF255 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF256 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF257 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF258 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF259 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF260 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF261 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF262 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF263 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF264 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF265 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF266 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF267 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF268 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF269 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF270 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF271 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF272 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF273 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF274 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF275 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF276 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF277 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF278 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF279 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF280 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF281 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF282 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF283 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF284 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF285 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF286 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF287 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF288 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF289 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF290 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF291 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF292 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 14 TRPF293 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF294 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF295 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF296 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF297 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF298 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF299 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF300 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF301 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF302 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF303 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF304 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF305 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF306 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF307 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF308 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF309 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF310 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF311 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF312 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF313 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF314 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF315 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF316 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF317 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF318 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF319 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF320 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF321 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF322 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF323 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF324 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF325 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF326 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF327 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF328 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF329 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF330 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF331 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF332 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 15 TRPF333 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF334 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF335 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF336 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF337 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF338 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF339 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF340 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF341 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF342 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF343 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF344 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF345 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF346 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF347 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF348 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF349 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF350 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF351 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF352 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF353 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF354 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF355 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF356 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF357 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF358 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF359 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF360 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF361 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF362 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF363 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF364 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF365 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF366 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF367 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF368 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF369 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF370 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF371 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF372 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 16 TRPF373 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF374 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF375 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF376 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF377 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF378 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF379 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF380 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF381 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF382 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF383 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF384 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF385 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF386 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF387 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF388 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF389 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF390 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF391 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF392 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF393 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF394 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF395 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF396 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF397 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF398 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF399 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF400 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF401 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF402 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF403 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF404 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF405 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF406 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF407 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF408 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF409 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF410 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF411 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF412 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 17 TRPF413 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF414 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF415 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF416 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF417 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF418 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF419 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF420 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF421 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF422 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF423 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF424 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF425 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF426 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF427 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF428 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF429 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF430 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF431 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF432 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF433 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF434 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF435 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF436 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF437 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF438 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF439 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF440 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF441 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF442 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF443 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF444 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF445 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF446 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF447 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF448 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF449 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF450 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF451 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF452 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 18 TRPF453 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF454 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF455 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF456 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF457 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF458 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF459 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF460 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF461 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF462 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF463 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF464 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF465 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF466 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF467 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF468 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF469 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF470 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF471 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF472 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF473 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF474 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF475 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF476 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF477 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF478 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF479 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF480 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF481 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF482 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF483 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF484 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF485 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF486 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF487 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF488 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF489 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF490 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF491 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF492 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 19 TRPF493 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF494 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF495 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF496 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF497 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF498 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF499 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF500 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF501 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF502 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF503 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF504 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF505 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF506 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF507 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF508 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF509 VOLUME 4526.6 2.5 8.2 5.06 2.37 21.758 1 TRPF510 VOLUME 4527.1 2.5 8.2 5.06 2.37 21.758 1 TRPF511 VOLUME 4528.0 2.5 8.2 5.06 2.37 21.758 1 TRPF512 VOLUME 4527.7 2.5 8.2 5.06 2.37 21.758 1 TRPF513 VOLUME 4526.9 2.5 8.2 5.06 2.37 21.758 1 TRPF514 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF515 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF516 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF517 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF518 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF519 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF520 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF521 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF522 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF523 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF524 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF525 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF526 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF527 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF528 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF529 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF530 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF531 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF532 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 20 TRPF533 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF534 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF535 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF536 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRPF537 VOLUME 4526.7 2.5 8.2 5.06 2.37 21.758 1 TRPF538 VOLUME 4526.9 2.5 8.2 5.06 2.37 21.758 1 TRPF539 VOLUME 4527.1 2.5 8.2 5.06 2.37 21.758 1 TRPF540 VOLUME 4527.5 2.5 8.2 5.06 2.37 21.758 1 TRPF541 VOLUME 4527.7 2.5 8.2 5.06 2.37 21.758 1 TRPF542 VOLUME 4528.1 2.5 8.2 5.06 2.37 21.758 1 TRPF543 VOLUME 4528.5 2.5 8.2 5.06 2.37 21.758 1 TRPF544 VOLUME 4528.8 2.5 8.2 5.06 2.37 21.758 1 TRPF545 VOLUME 4529.1 2.5 8.2 5.06 2.37 21.758 1 TRPF546 VOLUME 4529.6 2.5 8.2 5.06 2.37 21.758 1 TRPF547 VOLUME 4530.1 2.5 8.2 5.06 2.37 21.758 1 TRPF548 VOLUME 4530.7 2.5 8.2 5.06 2.37 21.758 1 TRPF549 VOLUME 4531.3 2.5 8.2 5.06 2.37 21.758 1 TRPF550 VOLUME 4531.7 2.5 8.2 5.06 2.37 21.758 1 TRPF551 VOLUME 4532.2 2.5 8.2 5.06 2.37 21.758 1 TRPF552 VOLUME 4532.8 2.5 8.2 5.06 2.37 21.758 1 TRPF553 VOLUME 4533.4 2.5 8.2 5.06 2.37 21.758 1 TRPF554 VOLUME 4534.1 2.5 8.2 5.06 2.37 21.758 1 TRPF555 VOLUME 4534.8 2.5 8.2 5.06 2.37 21.758 1 TRPF556 VOLUME 4535.5 2.5 8.2 5.06 2.37 21.758 1 TRPF557 VOLUME 4536.2 2.5 8.2 5.06 2.37 21.758 1 TRPF558 VOLUME 4536.7 2.5 8.2 5.06 2.37 21.758 1 TRPF559 VOLUME 4537.3 2.5 8.2 5.06 2.37 21.758 1 TRPF560 VOLUME 4538.0 2.5 8.2 5.06 2.37 21.758 1 TRPF561 VOLUME 4538.8 2.5 8.2 5.06 2.37 21.758 1 TRPF562 VOLUME 4539.6 2.5 8.2 5.06 2.37 21.758 1 TRPF563 VOLUME 4540.3 2.5 8.2 5.06 2.37 21.758 1 TRPF564 VOLUME 4541.2 2.5 8.2 5.06 2.37 21.758 1 TRPF565 VOLUME 4542.0 2.5 8.2 5.06 2.37 21.758 1 TRPF566 VOLUME 4542.7 2.5 8.2 5.06 2.37 21.758 1 TRPF567 VOLUME 4543.1 2.5 8.2 5.06 2.37 21.758 1 TRPF568 VOLUME 4543.8 2.5 8.2 5.06 2.37 21.758 1 TRPF569 VOLUME 4544.5 2.5 8.2 5.06 2.37 21.758 1 TRPF570 VOLUME 4545.1 2.5 8.2 5.06 2.37 21.758 1 TRPF571 VOLUME 4545.6 2.5 8.2 5.06 2.37 21.758 1 TRPF572 VOLUME 4546.3 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 21 TRPF573 VOLUME 4546.9 2.5 8.2 5.06 2.37 21.758 1 TRPF574 VOLUME 4547.4 2.5 8.2 5.06 2.37 21.758 1 TRPF575 VOLUME 4548.2 2.5 8.2 5.06 2.37 21.758 1 CPR001 VOLUME 4592.2 2.5 8.2 7.33 2.37 31.519 1 CPR002 VOLUME 4591.5 2.5 8.2 7.33 2.37 31.519 1 CPR003 VOLUME 4590.6 2.5 8.2 7.33 2.37 31.519 1 CPR004 VOLUME 4589.9 2.5 8.2 7.33 2.37 31.519 1 CPR005 VOLUME 4588.9 2.5 8.2 7.33 2.37 31.519 1 CPR006 VOLUME 4588.0 2.5 8.2 7.33 2.37 31.519 1 CPR007 VOLUME 4587.2 2.5 8.2 7.33 2.37 31.519 1 CPR008 VOLUME 4586.3 2.5 8.2 7.33 2.37 31.519 1 CPR009 VOLUME 4585.4 2.5 8.2 7.33 2.37 31.519 1 CPR010 VOLUME 4584.6 2.5 8.2 7.33 2.37 31.519 1 CPR011 VOLUME 4583.5 2.5 8.2 7.33 2.37 31.519 1 CPR012 VOLUME 4582.1 2.5 8.2 7.33 2.37 31.519 1 CPR013 VOLUME 4580.5 2.5 8.2 7.33 2.37 31.519 1 CPR014 VOLUME 4578.9 2.5 8.2 7.33 2.37 31.519 1 CPR015 VOLUME 4577.1 2.5 8.2 7.33 2.37 31.519 1 CPR016 VOLUME 4575.4 2.5 8.2 7.33 2.37 31.519 1 CPR017 VOLUME 4573.9 2.5 8.2 7.33 2.37 31.519 1 CPR018 VOLUME 4572.4 2.5 8.2 7.33 2.37 31.519 1 CPR019 VOLUME 4571.2 2.5 8.2 7.33 2.37 31.519 1 CPR020 VOLUME 4569.7 2.5 8.2 7.33 2.37 31.519 1 CPR021 VOLUME 4568.6 2.5 8.2 7.33 2.37 31.519 1 CPR022 VOLUME 4567.6 2.5 8.2 7.33 2.37 31.519 1 CPR023 VOLUME 4566.5 2.5 8.2 7.33 2.37 31.519 1 CPR024 VOLUME 4565.5 2.5 8.2 7.33 2.37 31.519 1 CPR025 VOLUME 4564.4 2.5 8.2 7.33 2.37 31.519 1 CPR026 VOLUME 4563.7 2.5 8.2 7.33 2.37 31.519 1 CPR027 VOLUME 4563.2 2.5 8.2 7.33 2.37 31.519 1 CPR028 VOLUME 4562.7 2.5 8.2 7.33 2.37 31.519 1 CPR029 VOLUME 4562.1 2.5 8.2 7.33 2.37 31.519 1 CPR030 VOLUME 4561.4 2.5 8.2 7.33 2.37 31.519 1 CPR031 VOLUME 4561.0 2.5 8.2 7.33 2.37 31.519 1 CPR032 VOLUME 4560.5 2.5 8.2 7.33 2.37 31.519 1 CPR033 VOLUME 4560.1 2.5 8.2 7.33 2.37 31.519 1 CPR034 VOLUME 4559.7 2.5 8.2 7.33 2.37 31.519 1 CPR035 VOLUME 4559.2 2.5 8.2 7.33 2.37 31.519 1 CPR036 VOLUME 4558.9 2.5 8.2 7.33 2.37 31.519 1 CPR037 VOLUME 4558.6 2.5 8.2 7.33 2.37 31.519 1 DAQE- MN144290009-24 Page 22 CPR038 VOLUME 4558.3 2.5 8.2 7.33 2.37 31.519 1 CPR039 VOLUME 4558.2 2.5 8.2 7.33 2.37 31.519 1 CPR040 VOLUME 4557.8 2.5 8.2 7.33 2.37 31.519 1 CPR041 VOLUME 4557.6 2.5 8.2 7.33 2.37 31.519 1 CPR042 VOLUME 4557.5 2.5 8.2 7.33 2.37 31.519 1 CPR043 VOLUME 4557.3 2.5 8.2 7.33 2.37 31.519 1 CPR044 VOLUME 4557.0 2.5 8.2 7.33 2.37 31.519 1 CPR045 VOLUME 4556.9 2.5 8.2 7.33 2.37 31.519 1 CPR046 VOLUME 4556.6 2.5 8.2 7.33 2.37 31.519 1 CPR047 VOLUME 4556.5 2.5 8.2 7.33 2.37 31.519 1 CPR048 VOLUME 4556.2 2.5 8.2 7.33 2.37 31.519 1 CPR049 VOLUME 4556.0 2.5 8.2 7.33 2.37 31.519 1 CPR050 VOLUME 4555.8 2.5 8.2 7.33 2.37 31.519 1 CPR051 VOLUME 4555.5 2.5 8.2 7.33 2.37 31.519 1 PPHR001 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR002 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR003 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR004 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR005 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR006 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR007 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR008 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR009 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR010 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR011 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR012 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR013 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR014 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR015 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR016 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR017 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR018 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR019 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR020 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR021 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR022 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR023 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR024 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR025 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR026 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 DAQE- MN144290009-24 Page 23 PPHR027 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR028 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR029 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR030 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR031 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR032 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR033 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR034 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR035 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR036 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR037 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR038 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR039 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR040 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR041 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR042 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR043 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR044 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR045 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR046 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR047 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR048 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR049 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR050 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR051 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR052 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR053 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR054 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR055 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR056 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR057 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR058 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR059 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR060 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR061 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR062 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR063 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR064 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR065 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR066 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 DAQE- MN144290009-24 Page 24 PPHR067 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR068 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR069 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR070 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR071 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR072 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR073 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR074 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR075 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR076 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR077 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR078 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR079 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR080 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR081 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR082 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR083 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR084 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR085 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR086 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR087 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR088 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR089 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR090 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR091 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR092 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR093 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR094 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR095 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR096 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR097 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR098 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR099 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR100 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR101 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR102 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR103 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR104 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR105 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR106 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 DAQE- MN144290009-24 Page 25 PPHR107 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR108 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR109 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR110 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR111 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR112 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR113 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR114 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR115 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR116 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR117 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR118 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR119 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR120 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR121 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR122 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR123 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR124 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR125 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR126 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR127 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR128 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR129 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR130 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR131 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR132 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR133 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR134 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR135 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR136 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR137 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR138 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR139 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR140 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR141 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR142 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR143 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR144 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR145 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR146 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 DAQE- MN144290009-24 Page 26 PPHR147 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR148 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR149 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR150 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR151 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR152 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR153 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR154 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR155 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR156 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR157 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR158 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR159 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR160 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR161 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR162 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR163 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR164 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR165 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR166 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR167 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR168 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR169 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR170 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR171 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR172 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR173 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR174 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR175 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR176 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR177 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR178 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR179 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR180 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR181 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR182 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR183 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR184 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR185 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR186 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 DAQE- MN144290009-24 Page 27 PPHR187 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR188 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR189 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR190 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR191 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR192 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR193 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR194 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR195 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR196 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR197 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR198 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR199 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR200 VOLUME 4527.2 2.5 8.2 7.33 2.37 31.519 1 PPHR201 VOLUME 4527.9 2.5 8.2 7.33 2.37 31.519 1 PPHR202 VOLUME 4526.9 2.5 8.2 7.33 2.37 31.519 1 PPHR203 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR204 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR205 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR206 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR207 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR208 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR209 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR210 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR211 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR212 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR213 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR214 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR215 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR216 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR217 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR218 VOLUME 4526.5 2.5 8.2 7.33 2.37 31.519 1 PPHR219 VOLUME 4526.9 2.5 8.2 7.33 2.37 31.519 1 PPHR220 VOLUME 4527.1 2.5 8.2 7.33 2.37 31.519 1 PPHR221 VOLUME 4527.6 2.5 8.2 7.33 2.37 31.519 1 PPHR222 VOLUME 4528.1 2.5 8.2 7.33 2.37 31.519 1 PPHR223 VOLUME 4528.7 2.5 8.2 7.33 2.37 31.519 1 PPHR224 VOLUME 4529.0 2.5 8.2 7.33 2.37 31.519 1 PPHR225 VOLUME 4529.8 2.5 8.2 7.33 2.37 31.519 1 PPHR226 VOLUME 4530.6 2.5 8.2 7.33 2.37 31.519 1 DAQE- MN144290009-24 Page 28 PPHR227 VOLUME 4531.4 2.5 8.2 7.33 2.37 31.519 1 PPHR228 VOLUME 4532.0 2.5 8.2 7.33 2.37 31.519 1 PPHR229 VOLUME 4532.9 2.5 8.2 7.33 2.37 31.519 1 PPHR230 VOLUME 4533.8 2.5 8.2 7.33 2.37 31.519 1 PPHR231 VOLUME 4534.8 2.5 8.2 7.33 2.37 31.519 1 PPHR232 VOLUME 4535.9 2.5 8.2 7.33 2.37 31.519 1 PPHR233 VOLUME 4536.6 2.5 8.2 7.33 2.37 31.519 1 PPHR234 VOLUME 4537.6 2.5 8.2 7.33 2.37 31.519 1 PPHR235 VOLUME 4538.7 2.5 8.2 7.33 2.37 31.519 1 PPHR236 VOLUME 4539.8 2.5 8.2 7.33 2.37 31.519 1 PPHR237 VOLUME 4541.0 2.5 8.2 7.33 2.37 31.519 1 PPHR238 VOLUME 4542.1 2.5 8.2 7.33 2.37 31.519 1 PPHR239 VOLUME 4542.9 2.5 8.2 7.33 2.37 31.519 1 PPHR240 VOLUME 4543.8 2.5 8.2 7.33 2.37 31.519 1 PPHR241 VOLUME 4544.9 2.5 8.2 7.33 2.37 31.519 1 PPHR242 VOLUME 4545.6 2.5 8.2 7.33 2.37 31.519 1 PPHR243 VOLUME 4546.6 2.5 8.2 7.33 2.37 31.519 1 PPHR244 VOLUME 4547.4 2.5 8.2 7.33 2.37 31.519 1 PPHR245 VOLUME 4548.4 2.5 8.2 7.33 2.37 31.519 1 TRBMP001 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP002 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP003 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP004 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP005 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP006 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP007 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP008 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP009 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP010 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP011 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP012 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP013 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP014 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP015 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP016 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP017 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP018 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP019 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP020 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP021 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 29 TRBMP022 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP023 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP024 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP025 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP026 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP027 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP028 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP029 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP030 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP031 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP032 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP033 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP034 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP035 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP036 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP037 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP038 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP039 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP040 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP041 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP042 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP043 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP044 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP045 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP046 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP047 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP048 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP049 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP050 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP051 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP052 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP053 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP054 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP055 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP056 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP057 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP058 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP059 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP060 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP061 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 30 TRBMP062 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP063 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP064 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP065 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP066 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP067 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP068 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP069 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP070 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP071 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP072 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP073 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP074 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP075 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP076 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP077 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP078 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP079 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP080 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP081 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP082 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP083 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP084 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP085 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP086 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP087 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP088 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP089 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP090 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP091 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP092 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP093 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP094 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP095 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP096 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP097 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP098 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP099 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP100 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP101 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 31 TRBMP102 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP103 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP104 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP105 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP106 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP107 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP108 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP109 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP110 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP111 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP112 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP113 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP114 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP115 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP116 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP117 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP118 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP119 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP120 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP121 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP122 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP123 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP124 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP125 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP126 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP127 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP128 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP129 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP130 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP131 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP132 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP133 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP134 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP135 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP136 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP137 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP138 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP139 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP140 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP141 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 32 TRBMP142 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP143 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP144 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP145 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP146 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP147 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP148 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP149 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP150 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP151 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP152 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP153 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP154 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP155 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP156 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP157 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP158 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP159 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP160 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP161 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP162 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP163 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP164 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP165 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP166 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP167 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP168 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP169 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP170 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP171 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP172 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP173 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP174 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP175 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP176 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP177 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP178 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP179 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP180 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP181 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 DAQE- MN144290009-24 Page 33 TRBMP182 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP183 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP184 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP185 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP186 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP187 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP188 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP189 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP190 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP191 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP192 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP193 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP194 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP195 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP196 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP197 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP198 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP199 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP200 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP201 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP202 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP203 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP204 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP205 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP206 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP207 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP208 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP209 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP210 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP211 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP212 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP213 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP214 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP215 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 TRBMP216 VOLUME 4526.5 2.5 8.2 5.06 2.37 21.758 1 UNCPF VOLUME 4546.3 9.1 29.9 43.69 8.49 187.87 1 PPNDMX AREA_POLY 4526.5 2.6 8.4 2.37 270040 OPP AREA_POLY 4526.5 2.6 8.4 2.37 812308 PPNDB1 AREA_POLY 4526.5 2.6 8.4 2.37 82887 TMA AREA_POLY 4526.5 2.6 8.4 2.37 706677 DAQE- MN144290009-24 Page 34 OPCP AREA_POLY 4526.6 2.6 8.4 2.37 2240712 PFFUG AREA_POLY 4546.3 2.6 8.4 2.37 92912.7 ARD001 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD002 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD003 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD004 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD005 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD006 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD007 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD008 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD009 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD010 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD011 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD012 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD013 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD014 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD015 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD016 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD017 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD018 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD019 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD020 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD021 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD022 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD023 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD024 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD025 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD026 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD027 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD028 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD029 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD030 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD031 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD032 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD033 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD034 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD035 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD036 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD037 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD038 LINE 4526.5 2.0 6.4 1.82 4.88 1 DAQE- MN144290009-24 Page 35 ARD039 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD040 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD041 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD042 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD043 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD044 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD045 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD046 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD047 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD048 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD049 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD050 LINE 4526.5 2.0 6.4 1.82 4.88 1 ARD051 LINE 4526.6 2.0 6.4 1.82 4.88 1 ARD052 LINE 4526.6 2.0 6.4 1.82 4.88 1 ARD053 LINE 4526.6 2.0 6.4 1.82 4.88 1 ARD054 LINE 4526.6 2.0 6.4 1.82 4.88 1 ARD055 LINE 4526.6 2.0 6.4 1.82 4.88 1 ARD056 LINE 4526.6 2.0 6.4 1.82 4.88 1 ARD057 LINE 4526.6 2.0 6.4 1.82 4.88 1 ARD058 LINE 4526.6 2.0 6.4 1.82 4.88 1 ARD059 LINE 4526.6 2.0 6.4 1.82 4.88 1 ARD060 LINE 4526.6 2.0 6.4 1.82 4.88 1 ARD061 LINE 4526.6 2.0 6.4 1.82 4.88 1 ARD062 LINE 4526.6 2.0 6.4 1.82 4.88 1 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414.359.0600 cleaverbrooks.com December 8, 2023 : Department of Air Quality 10808 S. River Front Parkway, Suite 343 South Jordan, UT 84095 Subject: Combustion of propane compared to natural gas Mr. Dean Pekeski: This correspondence is written in response to your inquiry regarding the combustion of fuel, specifically propane compared to natural gas in Cleaver Brooks boiler equipment. When propane is burned it produces more oxides of nitrogen (NOx) than compared to natural gas. The following table illustrates NOx emission from various fuels . With the use of flue gas recirculation (FGR), the level of NOx exhaust emission from our boiler equipment can be reduced significantly. However, FGR has its limitations. During testing we have observed after applying FGR the NOx emission for propane is approximately 40% greater than when burning natural gas. Therefore, the Cleaver Brooks equipment can reduce NOx emission when firing natural gas to 9 ppm and when firing propane ,13 ppm is achieved. Please do not hesitate to contact me if you desire additional information. Respectfully, Donald Betts Donald Betts Product Manager – Packaged Firetube Boiler dbetts@cleaverbrooks.com 1/1 October 31, 2023 Ramboll 50 West Broadway Suite 300 Salt Lake City, UT 84101 USA T +1 385 295 9969 www.ramboll.com Via Electronic Mail Mr. Bryce Bird Director, Division of Air Quality Utah Department of Environmental Quality bbird@utah.gov RE: PEAK MINERALS, INC. – SEVIER PLAYA POTASH PROJECT NOTICE OF INTENT APPLICATION Dear Mr. Bird, Ramboll Americas Engineering Solutions, Inc. (Ramboll) is submitting the enclosed Notice of Intent (NOI) application to the Utah Department of Environmental Quality –Division of Air Quality (UDAQ) on behalf of our client, Peak Minerals Inc. (Peak). Peak is proposing to construct and operate a potash mining project on the Sevier Playa in southwestern Utah’s Millard County. The proposed Sevier Playa Potash Project (the “Project”) is designed to produce up to approximately 215,000 tons per year of potash and 300,000 tpy of magnesium chloride and related products. The proposed Project will be classified as a minor source of air emissions with respect to both the Title V and federal New Source Review permitting programs. The primary stationary sources of air emissions at the proposed Project include fluidized bed dryers, crushers, screens, material transfers, non-emergency and emergency stationary internal combustion engines, and fugitive dust sources. CPM is submitting this NOI application to request an Approval Order for these operations in accordance with the requirements of Utah Administrative Code Rule R307-401-8. Included with this letter are the electronic application files and the NOI Form 2 signed by the responsible official. We appreciate UDAQ’s review of this NOI application. If you have any questions regarding the information presented, please contact us using the phone numbers and email addresses below. Yours sincerely, Megan Neiderhiser, PE Ross Beardsley Krish Vijayaraghavan Principal Managing Consultant Principal D +1 801 883 8311 D +1 415 899 0753 D +1 415 899 0726 mneiderhiser@ramboll.com rbeardsley@ramboll.com kvijayaraghavan@ramboll.com cc: Dean Pekeski (Peak) Michael LeBaron (Peak) Thomas Suchoski (Stantec) Intended for Utah Department of Environmental Quality Division of Air Quality Prepared by Ramboll Date October 2023 Project No. 1690030346-001 PEAK MINERALS INC. SEVIER PLAYA POTASH PROJECT NOTICE OF INTENT APPLICATION NOI Application Ramboll i CONTENTS 1. INTRODUCTION 1 2. SITE DESCRIPTION 2 3. SOURCES AND EMISSIONS CALCULATIONS 4 3.1 Material Handling and Processing Equipment 4 3.2 Product Dryers 5 3.3 Steam Boiler 5 3.4 Stationary Internal Combustion Engines 5 3.5 Fugitive Dust Sources 6 3.6 Supporting Equipment 7 3.7 Emissions Summary 7 4. FEDERAL AND STATE REGULATORY APPLICABILITY 9 4.1 New Source Review 9 4.2 Title V Operating Permits 9 4.3 New Source Performance Standards 9 4.3.1 40 CFR 60 Subpart A – General Provisions 9 4.3.2 40 CFR 60 Subpart Db – Industrial-Commercial-Institutional Steam Generating Units 10 4.3.3 40 CFR 60 Subpart Dc – Small Industrial-Commercial-Institutional Steam Generating Units 10 4.3.4 40 CFR 60 Subpart Kb – Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels) 11 4.3.5 40 CFR 60 Subpart OOO – Nonmetallic Mineral Processing Plants 11 4.3.6 40 CFR 60 Subpart UUU – Calciners and Dryers in Mineral Industries 11 4.3.7 40 CFR 60 Subpart IIII – Stationary Compression Ignition Internal Combustion Engines 12 4.3.8 40 CFR 60 Subpart JJJJ – Stationary Spark Ignition Internal Combustion Engines 14 4.4 National Emission Standards for Hazardous Air Pollutants 14 4.4.1 40 CFR 63 Subpart A – General Provisions 14 4.4.2 40 CFR 63 Subpart EEEE – Organic Liquids Distribution 14 4.4.3 40 CFR 63 Subpart ZZZZ – Stationary Reciprocating Internal Combustion Engines 14 4.4.4 40 CFR 63 Subpart DDDDD – Industrial, Commercial, and Institutional Boilers and Process Heaters 14 4.4.5 40 CFR 63 Subpart JJJJJJ – Industrial, Commercial, and Institutional Boilers Area Sources 14 4.4.6 40 CFR 63 Subpart CCCCCC – Gasoline Dispensing Facilities 15 4.5 Chemical Accident Prevention Provisions 15 4.6 Utah Administrative Code, Title R307 – Environmental Quality, Air Quality 15 4.6.1 R307-201 – Emission Standards: General Emission Standards 15 4.6.2 R307-203 – Emission Standards: Sulfur Content of Fuels 15 4.6.3 R307-205 – Emission Standards: Fugitive Emissions and Fugitive Dust 16 4.6.4 R307-410 – Emissions Impact Analysis 16 5. EVALUATION OF BEST AVAILABLE CONTROL TECHNOLOGY 17 NOI Application Ramboll ii 5.1 BACT Analysis Process 17 5.1.1 “Top-Down” BACT Approach 18 5.1.2 Information Relied Upon 19 5.2 Summary of Selected BACT 20 5.3 BACT Analysis for Fluidized Bed Dryers 20 5.3.1 PM10 and PM2.5 BACT Analysis for Fluidized Bed Dryers 21 5.3.2 NOX BACT Analysis for Fluidized Bed Dryers 23 5.3.3 VOC BACT Analysis for Fluidized Bed Dryers 25 5.3.4 CO BACT Analysis for Fluidized Bed Dryers 28 5.3.5 SO2 BACT Analysis for Fluidized Bed Dryers 30 5.4 BACT Analysis for Propane Boiler 31 5.4.1 PM10 and PM2.5 BACT Analysis for Propane Boiler 31 5.4.2 NOX BACT Analysis for Propane Boiler 31 5.4.3 VOC BACT Analysis for Propane Boiler 34 5.4.4 CO BACT Analysis for Propane Boiler 36 5.4.5 SO2 BACT Analysis for Boiler 37 5.5 BACT Analysis for Stationary Non-Emergency Engines 38 5.5.1 PM10 and PM2.5 BACT Analysis for Stationary Non-Emergency Engines 38 5.5.2 NOX BACT Analysis for Stationary Non-Emergency Engines 39 5.5.3 VOC BACT Analysis for Stationary Non-Emergency Engines 39 5.5.4 CO BACT Analysis for Stationary Non-Emergency Engines 40 5.5.5 SO2 BACT Analysis for Stationary Non-Emergency Engines 41 5.6 BACT Analysis for Stationary Emergency Engines 42 5.6.1 PM10 and PM2.5 BACT Analysis for Stationary Emergency Engines 42 5.6.2 NOX BACT Analysis for Stationary Emergency Engines 43 5.6.3 VOC BACT Analysis for Stationary Emergency Engines 44 5.6.4 CO BACT Analysis for Stationary Emergency Engines 45 5.6.5 SO2 BACT Analysis for Stationary Emergency Engines 46 5.7 BACT Analysis for Baghouse-Controlled Material Handling and Equipment 46 5.7.1 PM10 and PM2.5 BACT Analysis for Baghouse-Controlled Material Handling and Processing Equipment 47 5.8 BACT Analysis for Enclosed Material Handling and Processing Equipment 48 5.8.1 PM10 and PM2.5 BACT Analysis for Enclosed Material Handling and Processing Equipment 48 5.9 BACT Analysis for Fugitive Dust Sources 50 5.9.1 PM10 and PM2.5 BACT Analysis for Fugitive Dust Sources 51 TABLES Table 1. Maximum Annual Controlled Project Emissions (tons per year) .......................................... 8 Table 2. Summary of Selected BACT for the Site .........................................................................20 Table 3. Summary of Potential VOC Control Technology Costs for Fluidized Bed Dryers ....................28 Table 4. Summary of Potential CO Control Technology Costs for Fluidized Bed Dryers ......................30 Table 5. Summary of Potential VOC Control Technology Costs for Boiler ........................................36 NOI Application Ramboll iii Table 6. Summary of Potential CO Control Technology Costs for Boiler ..........................................37 Table 7. Summary of Potential CO Control Technology Costs for Non-Emergency Engines ................41 Table 8. Summary of Potential PM10 and PM2.5 Control Technology Costs for Enclosed Material Handling and Processing Sources ..................................................................................50 Table 9. Summary of Cyclone Incremental Cost Effectiveness Values for Enclosed Material Handling and Processing Sources ...............................................................................................50 Table 10. Summary of Potential PM10 and PM2.5 Control Technology Costs for Fugitive Dust Sources ..52 APPENDICES Appendix A Facility Maps and Diagrams Appendix B UDAQ Air Permit Application Forms Appendix C Potential Emissions Calculations Appendix D BACT Supporting Documentation Appendix E HAP Screening Summary Appendix F Detailed Process Flow Diagrams Appendix G EPA 1998 Determination of Non-Applicability of Potash Processing Operations to 40 CFR 60 Subparts OOO and UUU NOI Application Ramboll iv ACRONYMS AND ABBREVIATIONS AERMOD Atmospheric Dispersion Modeling System AP-42 Compilation of Air Pollutant Emission Factors AO Approval Order BACT Best Available Control Technology bhp Brake Horsepower BLM Bureau of Land Management BMUs Brine Mining Units BSFC Brake-Specific Fuel Consumption CH4 Methane CI Compression Ignition CO Carbon Monoxide CO2 Carbon Dioxide CO2e Carbon Dioxide Equivalent EPA Environmental Protection Agency ESP Electrostatic Precipitator FGD Flue Gas Desulfurization GACT Generally Available Control Technology GDF Gasoline Dispensing Facilities GHGs Greenhouse Gases gr/dscf Grains Per Dry Standard Cubic Foot H2O Water Vapor HAPs Hazardous Air Pollutants ICE Internal Combustion Engine K2SO4 Potassium Sulfate kPa Kilopascal m3 Cubic Meters m/s Meters Per Second MACT Maximum Available Control Technology MDAQMD Mojave Desert Air Quality Management District MEE Multiple Effect Evaporator MMBtu/hr Million British Thermal Unit Per Hour MOP Muriate of Potash mph Miles Per Hour N2 Nitrogen Gas NOI Application Ramboll v NAAQS National Ambient Air Quality Standards NESHAP National Emission Standards for Hazardous Air Pollutants NMHC Non-Methane Hydrocarbons NNSR Nonattainment New Source Review NOI Notice of Intent N2O Nitrous Oxide NOX Nitrogen Oxides (NO + NO2) NSPS New Source Performance Standards NSR New Source Review Peak Peak Minerals Inc. PFD Process Flow Diagram PM Particulate Matter PM2.5 Particulate Matter Less Than 2.5 Micrometers in Aerodynamic Diameter PM10 Particulate Matter Less Than 10 Micrometers in Aerodynamic Diameter ppm Parts Per Million PSD Prevention of Significant Deterioration psia Pounds Per Square Inch Absolute RBLC RACT/BACT/LAER Clearinghouse RCO Regenerative Catalytic Oxidizer RICE Reciprocating Internal Combustion Engine RMP Risk Management Plan RTO Regenerative Thermal Oxidizer SCR Selective Catalytic Reduction SI Spark Ignition SIP State Implementation Plan SJVAPCD San Joaquin Valley Air Pollution Control District SNCR Selective Non-Catalytic Reduction SO2 Sulfur Dioxide SOP Sulfate of Potash TCEQ Texas Commission on Environmental Quality TO Thermal Oxidizer tpy Tons Per Year UAC Utah Administrative Code UDAQ Utah Department of Air Quality VOC Volatile Organic Compounds VOL Volatile Organic Liquid NOI Application Ramboll 1 of 52 1. INTRODUCTION Peak Minerals Inc. (Peak) is submitting this Notice of Intent (NOI) to the Utah Department of Environmental Quality – Division of Air Quality (UDAQ) to request approval to construct and operate a potash mining project on the Sevier Playa in southwestern Utah’s Millard County (the “Site”). The playa is a semi-dry undeveloped playa lakebed located in southwestern Utah, approximately 30 miles southwest of Delta and 25 miles north-northwest of Milford. The proposed Sevier Playa Potash Project (the “Project”) is designed to produce up to approximately 215,000 tons per year of potash in the form of potassium sulfate (K2SO4), also known as sulfate of potash (SOP), 300,000 tons per year of magnesium chloride (MgCl2), as well as other associated mineral products. The proposed Project will be classified as a minor source of air emissions with respect to both the Title V and federal New Source Review (NSR) permitting programs. Peak owns, as lessee or through agreement controls, the right to develop and operate potassium mineral leases on approximately 118,000 acres of land administered by the U.S. Bureau of Land Management (BLM) and controls through agreement potash mineral leases on an additional approximately 6,400 acres of state lands administered by School and Institutional Trust Lands Administration (SITLA). A site location map is provided in Appendix A. In general, the on-lease mining design for the Project will consist of the following five major features: 1) a brine extraction system consisting of canals and trenches; 2) a recharge system consisting of canals and trenches; 3) a series of evaporation ponds consisting of preconcentration and production ponds; 4) tailings management area; and 5) processing facility. The brines extracted from below the surface of the Sevier Playa would be concentrated by solar evaporation in a series of preconcentration ponds. The potassium-rich salts precipitated in the production ponds will be harvested and transported to an on-lease processing facility. The salts will be processed at the processing facility where muriate of potash (MOP), also known as potassium chloride, will be added for beneficiation, producing saleable SOP. Magnesium chloride brine produced as part of the process will be used to produce de-sulphated MgCl2 brine and bischofite flake. Infrastructure to support the Project will include 1) access roads; 2) communication towers; 3) power and communications lines; 4) water supply facilities; and 5) waste production storage area. All of these components will be located on off-lease lands. Peak is submitting this NOI application to request an Approval Order (AO) in accordance with the requirements of the Utah Administrative Code (UAC) Rule R307-401-8. This project was previously approved under DAQE-AN144290005-19 but has yet to be constructed. This NOI application supersedes the previous application, approved in July 2019. The NOI application forms are included in Appendix B of this report. NOI Application Ramboll 2 of 52 2. SITE DESCRIPTION The Site will be located in Millard County, Utah, generally between the towns of Delta, approximately 30 miles northeast, and Milford, approximately 25 miles to the south- southeast. Figure A1 in Appendix A shows the Site location within the county and within the larger western Utah region. Millard County has been designated as attainment or unclassifiable with the National Ambient Air Quality Standards (NAAQS) for all criteria pollutants.1 The mining method for the production of SOP and MOP will consist of the following five major components: 1) a brine extraction system consisting of canals and trenches; 2) a recharge system consisting of canals and trenches; and 3) a series of evaporation ponds; 4) tailings management area; and 5) processing facility. The proposed layout of the Site facilities is shown in Figure A2. After the extraction and recharge system construction, there will be an initial brine accumulation and transfer to the evaporation ponds. Recharge trenches introduce fresh water to the extraction system, which will be used to help drive the brine into the extraction trenches by maintaining hydraulic head in the playa sediments. Concentrated brine will then be transferred to the ponds. Brine will be pumped into a series of preconcentration ponds and production ponds. The ponds will be staged in series to allow the playa brine to concentrate from the in-situ grade to a saturation point. During this process, salts will precipitate within each of the ponds. At the pre-concentration ponds, sodium chloride (NaCl) wet harvesting will occur via a dredge, and solid NaCl storage areas (salt pads) allow for additional potassium recovery. The potassium-rich salts harvested from the production ponds will be windrowed and then hauled to the processing facility for final treatment. Process tailings will be loaded and hauled to the tailings management area. Recharge of the brine aquifer will occur by way of precipitation, groundwater, local runoff, and inflow from the Sevier River. Recharge will be managed and conveyed to specific areas of the playa through the use of recharge canals and trenches to maintain flow as brine is continually extracted. MOP will be imported to the processing facility where it will be reacted with the residual brine containing magnesium sulfate to increase SOP production. Once the raw potash salts enter the processing facility, they will be subjected to a series of processes designed to separate and produce SOP, as outlined below. • Process feed: The raw salts from the ponds will be deposited into a hopper-feeder which will convey salts into a crusher where salts are reduced in size for conversion. • Conversion reactor: The crushed salts slurry will be fed directly to the conversion circuit. A high-sulfate brine from the halite leach step will cause the mixed potassium pond salts to form schoenite. Along with schoenite, halite and magnesium sulfate are expected to be present. • Conditioning and flotation: Insolubles, such as gypsum, clays, and silicates originating from lake mud and natural-occurring windblown dust, will be removed and conveyed to the tailings management area. These insolubles are known as filter cake tailings, or Type 3 tailings. Schoenite will be separated from other salts and slimes by adding flotation reagents and oils to the potash salt slurry. Flotation concentrate will be centrifuged, and 1 EPA. 2023. Current Nonattainment Counties for All Criteria Pollutants. May. Available at: https://www3.epa.gov/airquality/greenbook/ancl.html#UT NOI Application Ramboll 3 of 52 the solids will be washed to remove brine and then sent to the leach reactor. Tailings slurry will be pumped to the tailings circuit. To ensure no schoenite is lost to tailings, the tailing slurry will be pumped to leach tanks where it will be mixed with playa brine. After leaching, the process recycle brine will be sent back to the production ponds to be evaporated while the remaining halite and epsomite will be sent to the tailings management area. • SOP leach and crystallization: Flotation concentrate slurry will be leached with (hot) SOP mother liquor, cooled, and sent to the SOP crystallizer. Schoenite will be converted to SOP through crystallization. Water and MOP will be added to the schoenite crystals to dissolve the magnesium sulfate and produce SOP product. The SOP crystals will be recovered from the brine by a combination of cyclones and centrifuges. Potassium chloride will react with the magnesium sulfate in solution to form additional SOP and magnesium chloride. • Product drying, handling and shipping: The SOP exiting the crystallization circuit will be dried using fluid bed dryers and screened to produce the desired products. The dried product will be cooled and sent to product sizing and storage through a series of conveyors. The fertilizer-grade SOP will be produced as standard, soluble, and granular grades. The sizing area will separate the SOP into oversize product, coarse product, fine product, and fines. The oversize product will be sent to an impact crusher whereas undersize and on-size product will be conveyed to a compactor to be cured, crushed, and screened. The product will then be conveyed to the glazing circuit to be heated, dried, cooled, and sent to a final screening. The coarse and fine products will be sent to product storage silos by a combination of bucket elevators and screw conveyors. The solids in the silos will be loaded into trucks using spouts fitted with chutes to ensure dust-tight material transfer. MOP will be added to the crystallizer vessel directly in the form of MOP brine. MOP delivered to the processing facility will be dissolved in a heated process water tank and stored until it is needed at the processing facility. The processing facility will also produce de-sulfated magnesium chloride (MgCl2) brine and bischofite flakes. The bischofite processing system is described below: • Process feed - excess bitterns brine generated at the outlet of the harvest ponds is pumped to the plant where slaked lime is added to remove the sulfate from the brine. • Evaporation and concentration: de-sulfated brine is sent for evaporation in a Multiple Effect Evaporator (MEE). MEE uses steam to evaporate water in the brine, further concentrating the MgCl2 in the brine. The concentrated MgCl2 brine is then sent to twin flaking systems to crystallize the brine through cooling. • Product drying, handling, and shipping: de-sulfated brine is either sold as is or processed into solid bischofite flakes. Bischofite flakes are bagged and shipped directly to market. Excess MgCl2 will be used for local de-dusting of unpaved roads or will remain in the bitterns pond indefinitely. Processed SOP, bischofite, and associated products will be transported from the processing facility via truck for shipment. NOI Application Ramboll 4 of 52 3. SOURCES AND EMISSIONS CALCULATIONS Pollutants emitted from the Site’s operations will include carbon monoxide (CO), nitrogen oxides (NOX), sulfur dioxide (SO2), volatile organic compounds (VOCs), particulate matter (PM), greenhouse gases (GHGs), and hazardous air pollutants (HAPs). The following sections provide background on the methodology used to estimate potential emissions from the Site’s operations. Detailed potential emissions calculations are included in Appendix C. 3.1 Material Handling and Processing Equipment The processing facility will involve material handling and processing equipment, including material drop points to conveyors, transfer equipment, storage bins and silos; product screens; and crushers. A summary of all of the processing facility material handling and processing equipment can be found in the detailed process flow diagrams (PFDs) provided in Appendix F. All pieces of equipment presented in Appendix F are assumed to generate emissions unless that equipment handles slurried/wet material or operates in a non-emitting capacity (i.e., does not have any associated material drop points or crushing/screening activity). Emissions from all of the crushers, in addition to many of the product screens and material drop points, will be controlled by baghouses. The material drop points not controlled by baghouses will be fully or partially enclosed to minimize emissions of fugitive dust. The potential pre-control emissions of particulate matter less than 10 microns in diameter (PM10) and particulate matter less than 2.5 microns in diameter (PM2.5) for material drop points were estimated using Equation 1 of the United States Environmental Protection Agency’s (EPA’s) AP-42, Section 13.2.4, Aggregate Handling and Storage Piles.2 This equation accounts for the material moisture content and the wind speed in estimating the PM10 and PM2.5 emission factors. A wind speed of 0.1 meters per second [m/s] (0.22 miles per hour [mph]) was used for indoor sources, consistent with Appendix D.2.4 to EPA’s Risk Management Program Guidance for Offsite Consequence Analysis.3 For outdoor sources, an annual emission factor was developed based on the annual average wind speed from site - specific meteorological data, and a maximum daily average emission factor was developed using site-specific hourly wind speeds.4 The potential pre-controlled PM10 and PM2.5 emissions for screening and crushing were estimated using emission factors for dry screening and tertiary crushing, respectively, from Section VI.F of the Mojave Desert Air Quality Management District (MDAQMD) Emissions Inventory Guidance for Mineral Handling and Process Industries.5 The potential post-control PM10 and PM2.5 emissions for the sources controlled by baghouses were estimated using the baghouse exhaust flow rate and an assumed exhaust gas PM10 and PM2.5 concentration in units of grains per dry standard cubic foot (gr/dscf). An exhaust grain loading of 0.010 gr/dscf PM10 and PM2.5 (filterable + condensable) was used for baghouses controlling product dryers. A grain loading of 0.005 gr/dscf PM10 and PM2.5 (filterable only) was used for baghouses controlling material handling sources. There are no expected condensable PM emissions from material drop points, screens, or crushers. All material drop points at the Site that are not controlled by baghouses will be either fully or partially enclosed to minimize fugitive dust emissions. Emissions from the Site were estimated assuming all material drop points located inside a building will be fully enclosed 2 U.S. EPA AP-42 Section 13.2.4, Aggregate Handling and Storage Piles (11/06). Available at: https://www3.epa.gov/ttn/chief/ap42/ch13/final/c13s0204.pdf 3 https://www.epa.gov/sites/production/files/2017-05/documents/oca-apds.pdf 4 Site-specific meteorological data collected for December 2011 through November 2012. 5 http://www.mdaqmd.ca.gov/home/showdocument?id=768 NOI Application Ramboll 5 of 52 and all drop points outdoors will be partially enclosed, such as via covered conveyors. A 70% control efficiency was applied to PM10 and PM2.5 emissions for partial enclosures, consistent with Texas Commission on Environmental Quality (TCEQ) Best Available Control Technology (BACT) Guidelines,6 and a 90% control efficiency was used for full/building enclosures, in accordance with TCEQ emissions guidance for rock crushing operations.7 3.2 Product Dryers The processing facility will have two (2) product fluid bed dryers, each controlled by a baghouse. Each dryer will be equipped with a propane-fired burner which will provide direct heating to the material being dried. The drying and sizing fluid bed dryer is rated at 4.4 million British thermal units per hour (MMBTu/hr), and the glazing fluid bed dryer is rated at 2.0 MMBTu/hr. Except for PM, the criteria pollutant potential emissions from propane combustion we re estimated using emission factors from EPA’s AP-42, Section 1.5, Liquefied Petroleum Gas Combustion.8 Emissions of PM10 and PM2.5 were based on an assumed exhaust gas concentration of 0.010 gr/dscf and the baghouse exhaust gas flow rate, as discussed in Section 3.1 of this report. Since AP-42 Section 1.5 does not provide HAP emission factors for propane combustion, potential HAP emissions were estimated using propane combustion emission factors from the San Joaquin Valley Air Pollution Control District (SJVAPCD).9 Lastly, potential emissions of carbon dioxide equivalent (CO2e) were estimated using the emission factors for each GHG from 40 CFR 98 Subpart C and the global warming potentials from 40 CFR 98 Subpart A. 3.3 Steam Boiler The processing facility will have one (1) propane-fueled 14.7 MMBtu boiler, used in bischofite processing. The criteria pollutant potential emissions from propane combustion were estimated using emission factors from EPA’s AP-42, Section 1.5, Liquefied Petroleum Gas Combustion.10 Potential HAP emissions were estimated using propane combustion emission factors from the San Joaquin Valley Air Pollution Control District (SJVAPCD).11 Lastly, potential emissions of carbon dioxide equivalent (CO2e) were estimated using the emission factors for each GHG from 40 CFR 98 Subpart C and the global warming potentials from 40 CFR 98 Subpart A. 3.4 Stationary Internal Combustion Engines The Site will include eight (8) stationary non-emergency generator sets powered by diesel- fired internal combustion engines to provide electricity for the pumps. The rating for the engines will range from 53 brake horsepower (bhp) to 139 bhp. These generator sets will operate between project years 1 and 2. The Site will also include three (3) stationary diesel- 6 https://www.tceq.texas.gov/permitting/air/nav/air_bact_mechsource.html 7 https://www.tceq.texas.gov/assets/public/permitting/air/Guidance/NewSourceReview/emiss-calc-rock1.xlsx 8 U.S. EPA AP-42 Section 1.5 Liquefied Petroleum Gas Production, (7/08). Available at: https://www3.epa.gov/ttnchie1/ap42/ch01/final/c01s05.pdf 9 San Joaquin Valley Air Pollution Control District (SJVAPCD). 2015. LPG-Fired External Combustion - HAP Emission Factors. May 11. Available online at: http://www.valleyair.org/busind/pto/emission_factors/Criteria/Toxics/External%20Combustion/LPG%20External %20Combustion.xls 10 U.S. EPA AP-42 Section 1.5 Liquefied Petroleum Gas Production, (7/08). Available at: https://www3.epa.gov/ttnchie1/ap42/ch01/final/c01s05.pdf 11 San Joaquin Valley Air Pollution Control District (SJVAPCD). 2015. LPG-Fired External Combustion - HAP Emission Factors. May 11. Available online at: http://www.valleyair.org/busind/pto/emission_factors/Criteria/Toxics/External%20Combustion/LPG%20External %20Combustion.xls NOI Application Ramboll 6 of 52 fired emergency internal combustion engines, including one (1) emergency fire water pump engine rated at 100 bhp and two emergency generators rated at 1,342 bhp each. The emergency engines will be in use throughout the Site’s operational life. Each of the proposed stationary non-emergency and emergency engines will be certified to EPA’s Tier 4 final emission standards.12 The potential emissions of NOX, CO, VOC, PM10, and PM2.5 were estimated using the rated capacity for each engine and the corresponding emission standards for those pollutants. It was assumed that the PM10 emissions are equivalent to the PM emission standards and that PM2.5 emissions are 97% of PM10 emissions, per EPA’s MOVES NONROAD model assumptions. VOC emissions were based on a ratio of 1.07 VOC to non-methane hydrocarbons (NMHC), in accordance with the MOVES NONROAD model. For engine sizes with a combined emission standard for NOX + NMHC, it was assumed that 95% of the standard is NOX and the remaining 5% is NMHC. Emission factors for SO2 were estimated based on a maximum diesel fuel sulfur content of 15 part per million (ppm) and either fuel consumption data for the specific engine, if available, or default brake-specific fuel consumption (BSFC) values from the MOVES NONROAD model to estimate an approximate fuel consumption value. HAP emission factors for diesel engines less than 600 bhp were taken from EPA’s AP-42, Section 3.3, Gasoline and Diesel Industrial Engines,13 and HAP emission factors for diesel engines greater than 600 bhp were taken from AP-42, Section 3.4, Large Stationary Diesel and All Stationary Dual-Fuel Engines.14 Carbon dioxide (CO2) emission factors were calculated using the default methodology in the MOVES NONROAD model. Methane (CH4) emission factors were based on the VOC emission factors and the hydrocarbon conversions from the MOVES NONROAD model. The nitrous oxide (N2O) emission factor was taken from EPA’s 2018 Inventory of U.S. Greenhouse Gas Emissions and Sinks.15 The potential emissions for each GHG pollutant were then estimated using either engine-specific fuel consumption data, if available, or the default BSFC values from the MOVES NONROAD model. CO2e emissions were calculated based on the global warming potential for each GHG from 40 CFR 98 Subpart A. The potential annual emissions for the stationary non-emergency pump generators were calculated based on the maximum operating hours per day and operating days per year. The potential annual emissions for the stationary emergency engines were based on a maximum of 100 hours of operation per year, in accordance with the maximum allowable hours of non- emergency operations per calendar year for emergency engines under 40 CFR 60 Subpart IIII (see Section 4.3.7 of this report). 3.5 Fugitive Dust Sources Fugitive sources at the Site will include: • Dust formation from the use of off-road equipment for operational activities on disturbed areas, such as bulldozing, scraping, and grading of materials; • Windblown dust from areas recently disturbed by operational activities and spoils/berms; and 12 40 CFR 1039.101 13 U.S. EPA AP-42 Section 3.3, Gasoline and Diesel Industrial Engines, (10/96). Available at: https://www3.epa.gov/ttnchie1/ap42/ch03/final/c03s03.pdf 14 U.S. EPA AP-42 Section 3.4, Large Stationary Diesel and All Stationary Dual-fuel Engines, (10/96). Available at: https://www3.epa.gov/ttnchie1/ap42/ch03/final/c03s04.pdf 15 https://www.epa.gov/ghgemissions/inventory-us-greenhouse-gas-emissions-and-sinks-1990-2016 NOI Application Ramboll 7 of 52 • Haul trucks, worker vehicles, propane deliveries, and off-road equipment traveling on unpaved haul roads. Fugitive PM emissions from the use of off-road equipment were estimated using the equation from Section VI.D of the MDAQMD’s Emissions Inventory Guidance for Mineral Handling and Process Industries.16 A conservative default soil silt content of 30% was used per the MDAQMD guidance after approval by UDAQ.17 The soil moisture content, 23%, was based on the most conservative moisture content analyzed from on-site sampling of the proposed Site location. Windblown dust emissions were calculated for recently disturbed areas with surface areas of up to 4.6 acres per day for on-playa activities and up to 1.8 acres per day for production pond harvesting. Emission factors, in units of tons emissions per disturbed acre, were calculated using the equation from Section VI.L of the MDAQMD guidance18 and site-specific wind speed data.19 Fugitive particulate emissions from unpaved haul roads were estimated using Equation 1a of EPA’s AP-42, Section 13.2.2, Unpaved Roads.20 A surface material silt content of 4.8% was used based on the default value in UDAQ’s Guidelines for Emission Factors for Paved and Unpaved Haul Roads.21 Peak’s Fugitive Dust Control Plan outlines measures Peak will undertake during construction, operation, maintenance and decommissioning to protect soils from erosion and minimize fugitive dust from Project activities. This includes chemical suppressant (brine) application for operational areas and both chemical suppressant application and watering for unpaved roads. In accordance with the UDAQ guidelines, a control efficiency of 80% was applied to the emissions estimated for fugitive dust generated by off-road equipment and windblown dust from recently disturbed areas, and a control efficiency of 85% was applied to emissions from unpaved haul roads. 3.6 Supporting Equipment The Site will include additional equipment used to support operations. These sources, which will result in insignificant quantities of air emissions, include two (2) 28,000-gallon diesel storage tanks and diesel dispensing for off-road equipment. Emissions from the diesel storage tanks were calculated using the equations from EPA’s AP-42, Section 7.1, Organic Liquid Storage Tanks.22 Emissions from diesel dispensing were estimated using the submerged loading saturation factor and emission factor equation from AP-42, Section 5.2, Transportation and Marketing of Petroleum Liquids.23 3.7 Emissions Summary Table 1 summarizes the Site’s maximum annual controlled emissions for each pollutant. Documentation of uncontrolled and controlled emissions are provided in Appendix C. As discussed in Sections 4.1 and 4.2, the total emissions (excluding fugitives) are compared to the federal NSR and Title V major source thresholds. 16 http://www.mdaqmd.ca.gov/home/showdocument?id=768 17 As discussed during the February 14, 2018 meeting between Peak and UDAQ. 18 http://www.mdaqmd.ca.gov/home/showdocument?id=768 19 Site-specific meteorological data collected for December 2011 through November 2012. 20 U.S. EPA AP-42 Section 13.2.1, Unpaved Roads, (11/06). Available at: https://www3.epa.gov/ttnchie1/ap42/ch13/final/c13s0202.pdf 21 https://documents.deq.utah.gov/air-quality/permitting/operating-permits/DAQ-2017-006548.pdf 22 U.S. EPA AP-42, Section 7.1, Organic Liquid Storage Tanks, (11/06). Available at: https://www3.epa.gov/ttnchie1/ap42/ch07/final/c07s01.pdf 23 U.S. EPA AP-42, Section 5.2, Transportation and Marketing of Petroleum Liquids, (07/08). Available at: https://www3.epa.gov/ttnchie1/ap42/ch05/final/c05s02.pdf NOI Application Ramboll 8 of 52 Table 1. Maximum Annual Controlled Project Emissions (tons per year) Emissions Source Category PM10 PM2.5 NOX CO VOC SO2 Total HAPs1 CO2e (MT/yr) Unpaved Road and Disturbed Area Travel (Fugitive Dust) 69 6.9 -- -- -- -- -- -- Off-Road Stationary Equipment (Exhaust) -- -- -- 15 -- -- 0.052 -- Off-Road Equipment (Fugitive Dust) 16 4.9 -- -- -- -- -- -- Windblown Dust from Disturbed Areas (Fugitive Dust) 10 4.0 -- -- -- -- -- -- Processing Facility Operations 16 16 -- -- -- -- -- -- Combustion 0.5 0.5 12.47 0.0 1.07 0.051 -- 10,689 Supporting Equipment (Diesel- dispensing and Tanks) -- -- -- -- 0.071 -- -- -- Non-Fugitive Total 17 17 12 15 1.1 0.051 0.055 10,689 Fugitive Total 95 16 -- -- -- -- -- -- Total Emissions 112 33 12 15 1.1 0.051 0.055 10,689 • Maximum annual Total HAP emissions represents the sum of maximum annual individual HAP emissions, which would not necessarily occur during the same year of Project Operation. NOI Application Ramboll 9 of 52 4. FEDERAL AND STATE REGULATORY APPLICABILITY The following sections outline applicability of certain federal and state air regulations to the Site’s proposed operations. Specifically, potentially applicable requirements under federal New Source Review (NSR), Title V of the Clean Air Act Amendments, New Source Performance Standards (NSPS), National Emission Standards for Hazardous Air Pollutants (NESHAP), Chemical Accident Prevention Provisions, and Title R307 of the UAC are discussed herein. 4.1 New Source Review The federal NSR permitting program regulates emissions from major stationary sources of regulated air pollutants. The federal NSR program is comprised of two elements: Nonattainment NSR (NNSR) and Prevention of Significant Deterioration (PSD). NNSR permitting is applicable in areas that have been designated as nonattainment for a regulated pollutant under the NAAQS. PSD permitting applies in areas that have been designated as attainment or unclassifiable. The Project will be located on the Sevier Playa in southwestern Utah’s Millard County, which has been designated as attainment or unclassifiable for all criteria pollutants.24 As such, PSD is the relevant NSR permitting program for all pollutants. The PSD major source threshold for each regulated criteria pollutant is 250 tons per year (tpy), as potash mining operations are not on the list of 28 source categories for which there is a lower PSD major source threshold.25 Further, since the Site’s operations are not one of the listed 28 source categories, fugitive emissions are not included when comparing potential emissions to the PSD major source thresholds. The Site will be classified as a minor source with respect to PSD, as the facility-wide potential emissions will be less than the PSD major source threshold for each regulated pollutant. 4.2 Title V Operating Permits The Title V operating permits program, promulgated in 40 CFR 70, requires a facility to obtain a Title V operating permit if it has potential emissions of a regulated criteria pollutant exceeding 100 tpy, any single HAP exceeding 10 tpy, or total HAP emissions in excess of 25 tpy. Emissions from fugitive sources are not counted toward the Title V major source thresholds since potash mining operations are not on the list of 28 source categories for which fugitive emissions must be included. The facility-wide potential emissions from non-fugitive emissions sources will be less than 100 tpy for each criteria pollutant and potential HAP emissions will be less than the applicable major source thresholds. As such, the Site will be a minor source with respect to the Title V program. 4.3 New Source Performance Standards NSPS, promulgated in 40 CFR 60, provide emissions standards for criteria pollutant emissions from new, modified, and reconstructed sources. The following sections discuss the potentially applicable NSPS standards to the proposed operations at the Site. 4.3.1 40 CFR 60 Subpart A – General Provisions NSPS Subpart A provides generally applicable requirements for testing, monitoring, notifications, and recordkeeping. Any source that is subject to another subpart under 40 CFR 60 is also subject to Subpart A, unless otherwise stated in the specific subpart. 24 40 CFR 81.345 25 40 CFR 52.21(b)(1)(i)(a) NOI Application Ramboll 10 of 52 4.3.2 40 CFR 60 Subpart Db – Industrial-Commercial-Institutional Steam Generating Units Subpart Db regulates steam generating units that were constructed, modified, or reconstructed after June 19, 1984, and that have a heat input capacity greater than 100 MMBtu/hr.26 The Site will involve two fluidized bed dryers, both of which will have heat input capacities less than 100 MMBtu/hr. Further, the dryers will not meet the definition of steam generating units, as the combustion sources will not be used to produce steam or heat a heat transfer medium.27 As such, Subpart Db does not apply. 4.3.3 40 CFR 60 Subpart Dc – Small Industrial-Commercial-Institutional Steam Generating Units Subpart Dc regulates steam generating units that were constructed, modified, or reconstructed after June 9, 1989, and that have a heat input capacity between 10 MMBtu/hr and 100 MMBtu/hr.28 The burners for the two proposed fluidized bed dryers will each have heat input capacities less than 10 MMBtu/hr and will not meet the definition of steam generating units under this regulation.29 Therefore, Subpart Dc does not apply to the fluid bed dryers. Subpart Dc does apply to the proposed steam boiler, which has a heat input capacity of 14.7 MMBtu/hr. 4.3.3.1 Emission Standards 40 CFR 60.42c, 60.44c, and 60.46c set SO2 emission standards, initial performance test requirements, and emissions monitoring requirements, respectively, for a boiler that combusts coal, oil, or coal and oil with any other fuel. 40 CFR 60.43c, 60.45c, and 60.47c set PM emission standards, initial performance test requirements, and emissions monitoring requirements, respectively, for a boiler that combusts coal, oil, wood, a mixture of these fuels, or a mixture of these fuels with any other fuels. As the proposed boiler would be propane-fueled, these sections would not apply. 4.3.3.2 Notifications and Recordkeeping Peak is required to submit an Initial Notification under NSPS Subpart Dc.30 The notification will conform to the requirements in the rule, which include: • The design heat input capacity of the affected facility and identification of fuels to be combusted in the affected facility. • The annual capacity factor at which the owner or operator anticipates operating the affected facility based on all fuels fired and based on each individual fuel fired (propane). • Notification if an emerging technology will be used for controlling SO2 emissions, which is not anticipated. Peak will retain records of the fuel combusted or the fuel delivered to the property each operating month, to fulfill the requirements of 40 CFR 60.48c(g).31 All records required under Subpart Dc shall be maintained for a period of two years following the date of record. 26 40 CFR 60.40b(a) 27 40 CFR 60.41b 28 40 CFR 60.40c(a) 29 40 CFR 60.41c 30 40 CFR 60.48c(a) 31 40 CFR 60.48c(g) NOI Application Ramboll 11 of 52 4.3.4 40 CFR 60 Subpart Kb – Volatile Organic Liquid Storage Vessels (Including Petroleum Liquid Storage Vessels) NSPS Subpart Kb applies to volatile organic liquid (VOL) storage tanks that were constructed after July 23, 1984, have a maximum storage capacity greater than or equal to 75 cubic meters (m3; 19,813 gallon), and meet the following criteria:32 • The storage tank has a storage capacity greater than or equal to 75 m3 (19,813 gallons) but less than 151 m3 (39,890 gallons), and stores a VOL with a maximum true vapor pressure greater than or equal to 15.0 kilopascals (kPa; 2.2 pounds per square inch absolute [psia]); or • The storage tank has a storage capacity greater than or equal to 39,890 gallons and stores a VOL with a maximum true vapor pressure greater than or equal to 3.5 kPa (0.51 psia). The Site will include two VOL storage tanks, each with storage capacities of 28,000 gallons. The tanks will be used to store diesel fuel, which has a maximum true vapor pressure of approximately 0.022 psia.33 Therefore, NSPS Subpart Kb does not apply. 4.3.5 40 CFR 60 Subpart OOO – Nonmetallic Mineral Processing Plants Subpart OOO regulates PM emissions and opacity from facilities operating equipment used to crush or grind nonmetallic minerals.34 A nonmetallic mineral is defined as any of the eighteen listed minerals under this regulation or a mixture of which the majority is any of the listed minerals.35 Potash is not one of the listed minerals for which processing operations are subject to this regulation. In a 1998 applicability determination, EPA determined that NSPS Subparts OOO and UUU (discussed in the following section) do not apply to potash facilities, as the agency’s administrative record had intentionally excluded potash facilities from NSPS applicability.36 A copy of this applicability determination is included in Appendix G. As such, NSPS Subpart OOO will not apply to the Site’s processing operations, since potash is not a listed nonmetallic mineral subject to this rule, and the raw ore mined at the Site will not contain more than 50% of an impurity that would be a subject nonmetallic mineral, such as salt. 4.3.6 40 CFR 60 Subpart UUU – Calciners and Dryers in Mineral Industries Subpart UUU regulates PM emissions and opacity from calciners and dryers at mineral processing plants.37 A mineral processing plant is defined as one processing a listed mineral under this regulation, their concentrates, or a mixture of which the majority is any of the listed minerals.38 Potash is not one of the listed minerals for which processing operations are subject to this regulation, and as previously discussed, EPA found in a 1998 applicability determination that potash facilities are not subject to NSPS Subparts OOO and UUU.39 A copy of this applicability determination is included in Appendix G. 32 40 CFR 60.110b(a)-(b) 33 True vapor pressure for distillate fuel oil No. 2 at 100 °F from U.S. EPA AP-42, Section 7.1, Organic Liquid Storage Tanks, Table 7.1-2 (November 2006). 34 40 CFR 60.670(a)(1), 40 CFR 60.671 35 40 CFR 60.671 36 Rasnic, John B. (October 6, 1998). IMC Kalium Request for New Source Performance Standard Applicability Determination [Memorandum]. Washington, DC: U.S. EPA, Office of Compliance, Manufacturing, Energy and Transportation Division. 37 40 CFR 60.730(a) 38 40 CFR 60.731 39 Rasnic, John B. (October 6, 1998). IMC Kalium Request for New Source Performance Standard Applicability Determination [Memorandum]. Washington, DC: U.S. EPA, Office of Compliance, Manufacturing, Energy and Transportation Division. NOI Application Ramboll 12 of 52 As such, NSPS Subpart UUU will not apply to the Site’s fluidized bed dryers, since potash is not a listed nonmetallic mineral subject to this rule, and the raw ore mined at the Site will not contain more than 50% of an impurity that would be a subject mineral. 4.3.7 40 CFR 60 Subpart IIII – Stationary Compression Ignition Internal Combustion Engines NSPS Subpart IIII applies to new, modified, and reconstructed stationary compression ignition (CI) internal combustion engines (ICE). Applicability for new CI ICE is based on the date construction commenced and the date of manufacture, with separate applicability dates for new CI ICE that are not fire pump engines than for those that are. Specifically, new stationary engines are subject to this regulation if construction of the CI ICE commenced after July 11, 2005, and if the engine was manufactured after April 1, 2006, for CI ICE that are not fire pump engines, or July 1, 2006, for CI ICE that are fire pump engines.40 This rule is applicable to the Site’s proposed stationary CI ICE. Specifically, the Site will include eight (8) stationary diesel-fired engines generating power for the pumps, ranging in size from 53 bhp to 139 bhp; two (2) stationary diesel-fired emergency generators, both rated at 1,342 bhp; three (3) pond mobile pumps, all rated at 20 bhp; and one stationary diesel-fired emergency fire water pump engine, rated at 100 bhp. The eight (8) engines for the pumps, as well as the three (3) Pond Mobile Pumps, will not meet the definition of stationary emergency ICE in 40 CFR 60.4219, as they will be used to provide power to the pumps during normal operations. Note that the eight (8) engines will only be in operation through Year 2 and will not be in place for the Site’s entire operational life. The Pond Mobile Pumps will be moved throughout project operation, but will remain in one pond for upwards of one year – therefore, they are also considered stationary non- emergency ICE. The proposed emergency generators, and emergency fire water pump engines will meet the definition of stationary emergency ICE under this regulation. 4.3.7.1 Emission Standards Each proposed stationary ICE will have a displacement of less than 10 liters per cylinder. The eight (8) non-emergency pump engines will be subject to the applicable Tier 4 emission standards in 40 CFR 1039.101, which are based on the rated power of the engine.41 The two (2) emergency generators will each be subject to the Tier 2 emission standards in 40 CFR 89.112-113 for engines greater than 560 kW in capacity.42 Lastly, the emergency fire water pump engine is subject to the emission standards in Table 4 to Subpart IIII for engines with a maximum power between 11 bhp and 25 bhp.43 Peak will comply by purchasing engines certified by the manufacturer to comply with the emission standards.44 Moreover, Peak has chosen to purchase only stationary ICE that are certified to the Tier 4 emission standards, which are more stringent than the Tier 2 or Table 4 to Subpart IIII emission standards for emergency generators and emergency fire pump engines, respectively. Further, the site will operate and maintain each engine according to the manufacturer’s emission-related written instructions and only change those emission-related settings that are permitted by the manufacturer.45 Peak has not currently made its final selection of the make and model of stationary ICE that will be installed at the Site. As such, it is unknown at this time whether the engi ne 40 40 CFR 60.4200(a)(2) 41 40 CFR 60.4204(b) 42 40 CFR 60.4205(b) 43 40 CFR 60.4205(c) 44 40 CFR 60.4211(c) 45 40 CFR 60.4211(a) NOI Application Ramboll 13 of 52 manufacturer(s) for any of the Site’s stationary ICE will employ the use of add-on controls, such as selective catalytic reduction, to meet the Tier 4 emission standards. If it is determined when final engine selection is made that add-on controls are needed for any of the engines to meet these standards, Peak will submit a revised application to UDAQ to reflect the use of those controls. Additionally, Peak is required to only combust in each of its stationary ICE fuel that complies with the following requirements in 40 CFR 80.510(b) for nonroad diesel fuel:46 • Maximum sulfur content of 15 ppm; and • Either a minimum cetane index of 40 or a maximum aromatic content of 35 volume percent. Peak will comply with these diesel fuel requirements for all its stationary ICE. 4.3.7.2 Monitoring If any of the stationary ICE are equipped with a diesel particulate filter to meet the Tier 4 emission standard for PM, Peak will be subject to the requirement to install a backpressure monitor for that filter to notify the operator when the high backpressure limit of the engine is approached.47 4.3.7.3 Run Time Restrictions for Emergency ICE The emergency generators and emergency fire water pump engine are subject to the run time restrictions in 40 CFR 60.4211(f) to be classified as an emergency ICE under Subpart IIII. There is no restriction on usage of an emergency ICE in emergency situations.48 Each engine is restricted to a maximum of 100 hours per calendar year of operation for maintenance checks and readiness testing.49 Each engine is allowed up to 50 hours per calendar year of non-emergency operation other than maintenance and testing; however, any non-emergency run time must be counted as part of the 100 hours per calendar year for maintenance and testing.50 Any other operations are prohibited. Peak will equip each emergency ICE with a non-resettable hour meter prior to startup of the unit to verify compliance with the run time restrictions for emergency and non-emergency runs.51 There are no run time restrictions for the eight (8) pump engines and three pond mobile pumps; these are classified as non-emergency ICE under NSPS Subpart IIII. 4.3.7.4 Notifications and Recordkeeping Peak is not required to submit an Initial Notification under NSPS Subpart A or maintain records of engine maintenance, as the requirement does not apply for non-emergency ICE with a capacity less than 3,000 hp or for emergency ICE.52 Peak will retain records of the emergency and non-emergency runs for each emergency engine, as recorded through the engine’s non-resettable hour meter. The records will indicate the time of operation of the engine and the reason the engine was in operation during that time. If any stationary ICE is equipped with a diesel particulate filter, records will 46 40 CFR 60.4207(b) 47 40 CFR 60.4209(b) 48 40 CFR 60.4211(f)(1) 49 40 CFR 60.4211(f)(2)(i). The U.S. Court of Appeals for the DC Circuit vacated 40 CFR 60.4211(f)(ii)-(iii) in a May 2015 ruling. https://www.epa.gov/sites/production/files/2016-06/documents/ricevacaturguidance041516.pdf 50 40 CFR 60.4211(f)(3) 51 40 CFR 60.4209(a) 52 40 CFR 60.4214(a)-(b) NOI Application Ramboll 14 of 52 be maintained of any corrective actions taken after the backpressure monitor has notified the operator that the high backpressure limit of the engine is approached.53 4.3.8 40 CFR 60 Subpart JJJJ – Stationary Spark Ignition Internal Combustion Engines NSPS Subpart JJJJ is applicable to new, modified, and reconstructed stationary spark ignition (SI) ICE. The Site’s proposed generators will all be categorized as CI ICE. As such, NSPS Subpart JJJJ does not apply. 4.4 National Emission Standards for Hazardous Air Pollutants NESHAP, promulgated in 40 CFR 63, regulate emissions of HAP from specific source categories. A facility that has potential emissions exceeding 10 tpy for any individual HAP and/or emissions exceeding 25 tpy for the sum of all HAP is classified as a major so urce of HAP emissions. A facility that is not a major source of HAP is classified as an area source. The Site will be an area source, as the potential HAP emissions are less than the major source thresholds. Annual HAP emissions for the Site are presented in Appendix E, Table E-26. The following sections discuss the potentially applicable NESHAP standards to the Site’s operations. 4.4.1 40 CFR 63 Subpart A – General Provisions NESHAP Subpart A provides generally applicable requirements for testing, monitoring, notifications, and recordkeeping. Any source that is subject to another subpart under 40 CFR 63 is also subject to Subpart A, unless otherwise stated in the specific subpart. 4.4.2 40 CFR 63 Subpart EEEE – Organic Liquids Distribution NESHAP Subpart EEEE is applicable to organic liquids distribution operations, including organic liquid storage tanks, located at major sources of HAP emissions.54 This regulation does not apply since the Site will be an area source of HAP emissions. 4.4.3 40 CFR 63 Subpart ZZZZ – Stationary Reciprocating Internal Combustion Engines NESHAP Subpart ZZZZ applies to new and existing stationary reciprocating internal combustion engines (RICE) located at both major and area sources of HAP emissions. Per 40 CFR 63.6590(c), for new or reconstructed stationary RICE located at an area source of HAP emissions, the only requirement under NESHAP Subpart ZZZZ is to meet the requirements of NSPS Subpart IIII for CI ICE and of NSPS Subpart JJJJ for SI ICE. Since the Site’s proposed CI ICE will be in compliance with NSPS Subpart IIII, the units will also be in compliance with NESHAP Subpart ZZZZ. No further requirements apply for these engines under this regulation. 4.4.4 40 CFR 63 Subpart DDDDD – Industrial, Commercial, and Institutional Boilers and Process Heaters Subpart DDDDD, also known as the Boiler Maximum Available Control Technology (MACT), applies to boilers and process heaters located at major sources of HAP emissions.55 This regulation will not apply to the Site’s propane-powered fluidized bed dryers and steam boiler since the site will be an area source of HAP emissions. 4.4.5 40 CFR 63 Subpart JJJJJJ – Industrial, Commercial, and Institutional Boilers Area Sources Subpart JJJJJJ, also known as the Boiler Generally Available Control Technology (GACT), applies to new and existing boilers at area sources of HAP emissions.56 The proposed fluidized bed dryers will not meet the definition of boilers under this regulation, as they will 53 40 CFR 60.4214(c) 54 40 CFR 63.2330 55 40 CFR 63.7485 56 40 CFR 63.11194(a) NOI Application Ramboll 15 of 52 not be used to produce steam for process heat.57,58 The steam boiler will be propane-fueled, and gas-fired boilers are exempt from the Boiler GACT. As such, this regulation does not apply to the fluidized bed dryers nor to the steam boiler. 4.4.6 40 CFR 63 Subpart CCCCCC – Gasoline Dispensing Facilities NESHAP Subpart CCCCCC regulates gasoline dispensing facilities (GDF) located at area sources of HAP emissions.59 While the Site will involve dispensing operations for diesel fuel, it will not dispense gasoline and, therefore, will not meet the definition of a GDF.60 As such, Subpart 6C does not apply. 4.5 Chemical Accident Prevention Provisions The Chemical Accident Prevention Provisions, promulgated in 40 CFR 68, provide requirements for the development of risk management plans (RMP) for regulated substances. Applicability of RMP requirements is based on the types and amounts of chemicals stored at a facility. The Site will have storage of diesel fuel and non-toxic chemicals for fugitive dust suppression (i.e., brine), none of which are regulated substances under Subpart F of this rule. Therefore, Peak is not required to develop an RMP under 40 CFR 68. 4.6 Utah Administrative Code, Title R307 – Environmental Quality, Air Quality In addition to the federal regulations, the Title R307 of the UAC establishes regulations applicable at the emission unit level and at the facility level. The state regulations also include general requirements for facilities, such as the requirement to obtain construction and operating permits. Source-specific standards in R307 that are potentially applicable to the Site’s proposed operations are discussed in the following sections. 4.6.1 R307-201 – Emission Standards: General Emission Standards This regulation sets general emission standards for opacity. Visible emissions from installations constructed after 1971 are limited to no more than 20% opacity for sources that are not diesel engines and no more than 40% for diesel engines.61 These standards cannot be exceeded except for short time periods during startup or shutdown, installation or operation, or unavoidable combustion irregularities which do not exceed three minutes in length. Peak is required to minimize emissions during startup or shutdown, installation, or operation through the use of adequate controls and proper procedures.62 4.6.2 R307-203 – Emission Standards: Sulfur Content of Fuels This regulation provides emission standards for fuel burning equipment that combusts coal, oil, or a mixture thereof. This rule does not apply to sources covered by a NSPS for sulfur emissions.63 This regulation is not applicable to the product dryers, which combust exclusively propane fuel. While the stationary engines are subject to an NSPS, 40 CFR 60 Subpart IIII, that does not specifically regulate sulfur emissions, it does provide a requirement for the fuel sulfur content of the diesel fuel combusted in the engines (maximum sulfur content of 0.0015% by weight). The NSPS Subpart IIII fuel sulfur content 57 40 CFR 63.11237 58 Unlike the Boiler MACT (Subpart DDDDD), the Boiler GACT (Subpart JJJJJJ) only regulates boilers, not boilers and process heaters. However, even if process heaters were regulated under the Boiler GACT, the proposed fluidized bed dryers would not meet the process heater definition under 40 CFR 63.11237, as they will not be used for indirect process heating. Further, even if the dryers did meet the definition of boilers, the dryers will run exclusively on propane gas, and gas-fired boilers are exempt from the Boiler GACT. [40 CFR 63.11195(e)] 59 40 CFR 63.11111(a) 60 40 CFR 63.11132 61 R307-201-3(2) & (6) 62 R307-201-3(7) 63 R307-203-1(1) NOI Application Ramboll 16 of 52 limit is more stringent than that contained in this regulation (i.e., 0.85 lb/MMBtu). Therefore, the NSPS Subpart IIII fuel sulfur content limitation subsumes the R307-203 SO2 emission limit for oil firing. 4.6.3 R307-205 – Emission Standards: Fugitive Emissions and Fugitive Dust R307-205 establishes emission standards for fugitive emissions and fugitive dust sources, including construction activities and roadways. Specifically, R307-205-7 regulates fugitive emissions associated with mining operations, and R307-205-8 regulates fugitive emissions associated with tailing piles and ponds. Peak’s Fugitive Dust Control Plan, submitted to UDAQ and BLM, outlines measures Peak will undertake to minimize emissions of fugitive dust, including chemical suppressant (brine) application for operational areas and both chemical suppressant application and watering for unpaved roads. As such, compliance with this regulation will be achieved by operating in accordance with the procedures in the Fugitive Dust Control Plan. 4.6.4 R307-410 – Emissions Impact Analysis The provisions of R307-410 establish the procedures and requirements for evaluating the emissions impact of new and modified sources that require an approval order under R307- 401 to ensure that the source will not interfere with the attainment or maintenance of any NAAQS in the state of Utah. The PM10 and PM2.5 potential emissions attributable to the Site exceed the annual emission rate thresholds requiring an air dispersion modeling analysis (refer to the thresholds provided under R-307-410-4), thus Peak is providing an air dispersion modeling analysis conducted using EPA’s recommended short -range transport dispersion model (AERMOD). This analysis will be conducted in accordance with the modeling protocol submitted to UDAQ on July 20, 2023 and approved on July 28, 2023. The final modeling report summarizing the results of this analysis will be provided to UDAQ under separate cover. R307-410 also establishes regulatory emission thresholds for HAPs. Potential HAP emissions attributable to the Site do not exceed the emission threshold value (ETV) and therefore a dispersion modeling analysis is not required as part of this NOI. Table E-1 in Appendix E shows the basis for potential HAP emissions being less than the emission thresholds. In Appendix B, Peak has provided UDAQ Form 11 for each stationary non-emergency engine and each stationary emergency engine with a rated power greater than 1,000 bhp. Item #21 on the Form 11 states that all formaldehyde emissions must be modeled using SCREEN3 in accordance with R307-410-5. However, as confirmed by UDAQ, formaldehyde modeling is not required if the potential formaldehyde emissions are less than the associated ETV.64 As such, Peak has not conducted dispersion modeling for formaldehyde, as the Site’s potential formaldehyde emissions are less than this threshold (Appendix E). 64 Email from Catherine Wyffels (UDAQ) to Megan Neiderhiser (Ramboll) on August 30, 2018. NOI Application Ramboll 17 of 52 5. EVALUATION OF BEST AVAILABLE CONTROL TECHNOLOGY New and modified sources of air emissions in an attainment area in Utah are required to implement BACT for control of emissions when applying for an AO.65 Determination of BACT accounts for the technical feasibility of potential air pollution control technologies, as well as factors such as the energy, environmental, and economic impacts of the technology. This section evaluates BACT for emissions of criteria pollutants from the Site’s operations, specifically NOX, CO, VOC, PM10, PM2.5, and SO2. 5.1 BACT Analysis Process Utah air regulations [R307-401-5(2)(d)] require that BACT be used to minimize the emissions of pollutants from proposed new emission sources or modifications to existing emissions sources requiring an AO. BACT is defined as follows:66 [BACT] means an emissions limitation … based on the maximum degree of reduction for each air pollutant which would be emitted from any proposed stationary source or modification which the director, on a case-by-case basis, taking into account energy, environmental, and economic impacts and other costs, determines is achievable for such source or modification through application of production processes or available methods, systems, and techniques, including fuel cleaning or treatment or innovative fuel combustion techniques for control of such pollutant. In no event shall application of best available control technology result in emissions of any pollutant which would exceed the emissions allowed by any applicable standard under 40 CFR parts 60 and 61. If the director determines that technological or economic limitations on the application of measurement methodology to a particular emissions unit would make the imposition of an emissions standard infeasible, a design, equipment, work practice, operational standard or combination thereof, may be prescribed instead to satisfy the requirement for the application of best available control technology. Such standard shall, to the degree possible, set forth the emissions reduction achievable by implementation of such design, equipment, work practice or operation, and shall provide for compliance by means which achieve equivalent results. The BACT analysis is performed on a pollutant-specific, case-by-case basis for each new or modified emission unit. The following emission units and pollutants were considered in the BACT analysis: • Dryers: PM10, PM2.5, NOX, VOC, CO, SO2 • Propane Boiler: PM10, PM2.5, NOX, VOC, CO, SO2 • Stationary Generators: PM10, PM2.5, NOX, VOC, CO, SO2 • Material Handling and Processing Equipment: PM10, PM2.5 • Fugitive Dust Sources: PM10, PM2.5 65 R307-401-5(2)(d) 66 R307-401-2 NOI Application Ramboll 18 of 52 5.1.1 “Top-Down” BACT Approach This BACT analysis generally follows the “top-down” BACT approach outlined by EPA in a 1987 memorandum designed to improve the effectiveness of the federal PSD program.67,68 The top-down BACT approach starts with consideration of the technology that would achieve the maximum degree of emissions limitations, i.e. the lowest emission rate, which can be or has been applied to the specific source type under review or to other similar source types. The top-ranked technology may be eliminated based on costs, economics, environmental or energy impacts. If the top control option is eliminated, the BACT analysis then proceeds to the next most stringent technology and the analysis continues until a BACT conclusion is reached. The following steps provide a general outline of the top-down BACT process. In practice, each step may not apply to each BACT analysis, and the steps may be overlappi ng, combined, or undertaken in a different order depending on the specific emission units and considerations involved. 5.1.1.1 Step 1 – Identify Available Control Technologies The first step in the top-down procedure is to identify all available control technologies and emission reduction options for the emissions unit and pollutant undergoing the BACT analysis. Available control technologies are those with a practical potential for application to the particular pollutant and emission unit under review, which have been demonstrated in practice on full scale operations and are commercially available. Pollutant emission reduction options can be grouped into two categories: • Inherently lower-emitting processes, practices, or designs; and • Add-on control technologies. In addition, emission reduction options can sometimes be used in combination. 5.1.1.2 Step 2 – Eliminate Technically Infeasible Options The second step is to evaluate the technical feasibility of the control options identified in Step 1 and to eliminate any options that are technically infeasible based on engineering evaluation or due to chemical or physical principles. Criteria such as the following may be considered in determining technical feasibility: previous commercial scale demonstrations, precedents based on previous permits, and technology transfer from similar emission units. Technologies which have not yet been applied to full scale operations need not be considered available; an applicant should be able to purchase or construct a process or control device that has already been demonstrated in practice. When evaluating the technical feasibility of a technology that has been operated successfully on a type of source different than the source type under review, EPA has indicated that the “availability” and “applicability” of the technology to the source typ e under review should be considered to eliminate the technology as technically infeasible. EPA has stated that it “considers a technology to be ‘available’ where it can be obtained through commercial channels or is otherwise available within the common meaning of the term.”69 Further, EPA “considers an available technology to be ‘applicable’ if it can reasonably be installed and operated on the source type under consideration.”70 67 Memo dated December 1, 1987, from J. Craig Potter (U.S. EPA Headquarters) to U.S. EPA Regional Administrators, titled “Improving New Source Review Implementation.” 68 US EPA, Office of Air Quality Planning and Standards. 1989. June 3. “Transmittal of Background Statement on Top-Down Best Available Control Technologies”. Available online: https://www.epa.gov/sites/production/files/2015-07/documents/topdawn.pdf 69 U.S. EPA. PSD and Title V Permitting Guidance for Greenhouse Gases, March 2011. https://www.epa.gov/sites/production/files/2015-07/documents/ghgguid.pdf 70 Ibid. NOI Application Ramboll 19 of 52 If any of the control techniques cannot be successfully used on the emission units due to technical difficulties, this finding should be documented, and such control techniques are not considered further in the BACT analysis. 5.1.1.3 Step 3 – Rank Remaining Control Technologies In Step 3, the remaining control technologies are rank-ordered into a control hierarchy from most to least stringent. To the extent practical, this involves an assessment and documentation of the emissions control level or emissions limit achievable with each technically feasible alternative, considering the specific operating constraints of the emission units undergoing review. Generally accepted control efficiencies or ranges of control efficiencies are presented where control efficiencies vary and/or detailed information for the specific emission unit is not available. 5.1.1.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs A top-ranked control option may be rejected as BACT based on a consideration of cost, economic, environmental, and energy impacts. If the top-ranked option is not selected as BACT, the applicant should document the evaluation of the cost, economic, environmental, and/or energy impacts that leads to its rejection. If a control technology is determined to be infeasible based on high cost effectiveness, or to cause adverse economic, energy, or environmental impacts that would outweigh the benefits of the additional emissions reduction as compared to a lower ranked control, then the control technology is rejected as BACT, and the next most stringent control technique is considered in turn. Both average cost effectiveness and incremental cost effectiveness may be considered for the control options. Cost effectiveness is the annualized cost of control [in dollars ($)] divided by the mass of emissions (in tons) reduced or eliminated by that control. For a specific control technology, average cost effectiveness is the cost ($ per ton) that would be incurred compared with baseline conditions. Incremental cost effectiveness is the difference in cost per ton of emissions reduced at the next most stringent level of control when comparing two control options. Detailed control cost calculations are provided in Appendix D. 5.1.1.5 Step 5 – Select BACT BACT is identified as the option with the highest control effectiveness from Step 3 that is not eliminated in Step 4 based on consideration of cost, economic, energy or environmental impacts. Once the control technology, process or work practice is selected, a BACT emission limit is established, if appropriate, considering what is achievable over the range of operating conditions anticipated. 5.1.2 Information Relied Upon In general, the spectrum of BACT control options identified in Step 1 for consideration as potential control options is based on the following: • RACT/BACT/LAER Clearinghouse (RBLC) database located on EPA's Technology Transfer Network in the EPA electronic bulletin board system, as well as other agency on-line BACT listings. Tables summarizing the results of the RBLC database searches performed for this application are provided in Appendix D; • An assessment of recently issued BACT determinations and permits for similar sources; • EPA Air Pollution Control Technology Fact Sheets and other EPA guidance and technical reports were relied upon as a reference for the likely achievable range of control for control equipment and/or for guidance regarding the BACT process; NOI Application Ramboll 20 of 52 • Vendor data; and • Professional engineering judgement and experience. 5.2 Summary of Selected BACT Table 2 summarizes the selected BACT for the Site’s proposed new emission units. Table 2. Summary of Selected BACT for the Site Source Type Pollutant Selected BACT Fluidized Bed Dryers PM10, PM2.5 Baghouse Opacity 10% opacity limit NOX Good Design/Combustion Practices, Low NOX Burners VOC Good Combustion Practices CO Good Combustion Practices SO2 Good Combustion Practices, Propane Fuel Propane Boiler PM10, PM2.5 Good Combustion Practices, Propane Fuel Opacity 10% opacity limit NOX Good Design/Combustion Practices, Ultra-Low NOX Burners (i.e., 13 ppm) VOC Good Combustion Practices CO Good Combustion Practices SO2 Good Combustion Practices, Propane Fuel Stationary Non-Emergency Engines PM10, PM2.5 Tier 4-Certified Engine Opacity Tier 4-Certified Engine NOX Tier 4-Certified Engine VOC Tier 4-Certified Engine CO Tier 4-Certified Engine SO2 Ultra-Low Sulfur Diesel (15 ppm sulfur maximum) Stationary Emergency Engines PM10, PM2.5 Tier 4-Certified Engine Opacity Tier 4-Certified Engine NOX Tier 4-Certified Engine VOC Tier 4-Certified Engine CO Tier 4-Certified Engine SO2 Ultra-Low Sulfur Diesel Baghouse-Controlled Material Handling and Processing Equipment PM10, PM2.5 Baghouse Opacity 7% opacity limit Enclosed Material Handling and Processing Equipment PM10, PM2.5 Enclosure Opacity 20% opacity limit Fugitive Dust Sources PM10, PM2.5 Meet Requirements of Fugitive Dust Control Plan Opacity Meet Requirements of Fugitive Dust Control Plan 5.3 BACT Analysis for Fluidized Bed Dryers The processing facility will include two (2) small product dryers. Each dryer will have a fluidized bed design and Peak is proposing to use propane as the fuel for the dryer burner. The burners will have a maximum heat input capacity of 4.4 MMBTU/hr and 2.0 MMBtu/hr, respectively. The dryers will be sources of criteria pollutant emissions resulting from propane combustion by the burners as well as PM10 and PM2.5 emissions from product handling. Peak proposes to install a baghouse for each dryer for control of PM10 and PM2.5 emissions. NOI Application Ramboll 21 of 52 5.3.1 PM10 and PM2.5 BACT Analysis for Fluidized Bed Dryers 5.3.1.1 Step 1 – Identify Available Control Technologies Potentially available PM control technologies include: • Cyclone; • Baghouse; • Mechanically-Aided Wet Scrubber; • Venturi Wet Scrubber; • Electrostatic Precipitator (ESP); and • Good Combustion Practices and Use of a Clean Fuel. Cyclone Cyclones are frequently used for product recovery or emissions control of dry dusts and powders, and as primary collectors on high dust loading operations. Entrained PM is removed in a cyclone through centrifugal and inertial forces. Thus, particulate-laden gas is forced to change direction and fall out of the gas stream where it accumulates and slides down the cyclone walls into a receiving vessel. The control efficiency range for conventional single cyclones is estimated to be between 30 to 90% for PM10 and between 0 to 40% for PM2.5.71 Baghouse A fabric filtration device (baghouse) consists of a number of filtering elements (bags) along with a bag cleaning system contained in a main shell structure incorporating dust hoppers. Baghouses use fabric bags as filters to collect PM. The particulate-laden gas enters a fabric filter compartment and passes through a layer of PM and filter bags. The collected PM forms a cake on the bag, which enhances the bag’s filtering efficiency. However, excessive caking will increase the pressure drop across the fabric filter and reduce its efficiency. A phenomenon known as “blinding” occurs when cake builds up to the point that air can no longer pass through the baghouse during normal operation or the baghouse becomes clogged with wet and/or resinous compounds. The PM removal efficiency of baghouses is dependent upon a variety of particle and operational characteristics. Particle characteristics that affect the collection efficiency include particle size distribution, particle cohesion characteristics, and particle electrical resistivity. Operational parameters that affect baghouse collection efficiency include air-to-cloth ratio, operating pressure loss, cleaning sequence, interval between cleanings, cleaning method, and cleaning intensity. In addition, the particle collection efficiency and size distribution can be affected by certain fabric properties (e.g., structure of fabric, fiber composition, and bag properties). Typical baghouse control efficiencies range between 99 and 99.9% for PM10 and PM2.5.72 Mechanically-Aided Wet Scrubber A mechanically-aided scrubber is used primarily to control PM emissions. The scrubber relies almost exclusively on inertial interception for PM collection. Higher control efficiencies are achieved through commensurate high energy consumption. Control efficiencies range from 80 to 99% for PM10 and PM2.5, depending upon the application.73 71 U.S. EPA, Air Pollution Control Technology Fact Sheet, Cyclones, EPA-452/F-03-005. https://www3.epa.gov/ttn/catc/dir1/fcyclon.pdf 72 U.S. EPA, Air Pollution Control Technology Fact Sheet, Fabric Filter – Pulse-Jet Cleaned Type (also referred to as Baghouses), EPA-452/F-03-025. https://www3.epa.gov/ttn/catc/dir1/ff-pulse.pdf 73 U.S. EPA, Air Pollution Control Technology Fact Sheet, Mechanically-Aided Scrubber, EPA-452/F-03-013. https://www3.epa.gov/ttn/catc/dir1/fmechcal.pdf NOI Application Ramboll 22 of 52 Venturi Wet Scrubber A venturi wet scrubber is used to control emissions of PM and high solubility gases through inertial and diffusional interception. Increasing the control efficiency of the scrubber requires increasing the pressure drop which, in turn, increases the energy consumption. PM10 and PM2.5 control efficiencies range 70 to 99%, depending upon the application.74 Electrostatic Precipitator ESPs remove particles from a gas stream through the use of electrical forces. Discharge electrodes apply a negative charge to particles passing through a strong electrical field. These charged particles then migrate to a collecting electrode having an opposite, or positive, charge. Collected particles are removed from the collecting electrodes by periodic mechanical rapping. Typical PM control efficiencies range between 99 and 99.9%.75 An ESP can be either dry or wet. While both types of ESPs operate similarly and share many of the same physical characteristics, dry ESPs are commonly used to capture coarser, filterable particulates, whereas wet ESPs are typically used to remove condensable and liquid droplets from saturated air streams. Good Combustion Practices and Use of a Clean Fuel Good combustion practices and the use of clean fuels with negligible ash contents and very low sulfur contents, such as natural gas, propane, and/or diesel/No. 2 fuel oil, minimizes the formation of PM10 and PM2.5 emissions from the combustion process. Equipment shall operate and be maintained in accordance with the manufacturer’s specification, which technical staff shall be trained on. 5.3.1.2 Step 2 – Eliminate Technically Infeasible Options All of the PM10 and PM2.5 control devices identified in Step 1 are considered technically feasible for the dryers. 5.3.1.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of PM10 and PM2.5 emissions: 1. Baghouse/ESP: 99-99.9% control efficiency 2. Mechanically-Aided and Venturi Wet Scrubber: 70-99% control efficiency 3. Cyclone: 30-90% control efficiency for PM10; 0-40% control efficiency for PM2.5 4. Good Combustion Practices and Use of a Clean Fuel: base case 5.3.1.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs Peak has determined that use of a baghouse for each dryer is BACT for PM10 and PM2.5. The baghouse represents the top-ranked control technology from Step 3. Although an ESP system was also a top-ranked control technology, it is not anticipated that an ESP would provide a higher control efficiency for PM10 and PM2.5 than a baghouse, and an ESP would be significantly more expensive to install and operate. The remaining control technologies were not further evaluated in this step since they would provide lower control efficiencies than the selected BACT (baghouse). 74 U.S. EPA, Air Pollution Control Technology Fact Sheet, Venturi Scrubber, EPA-452/F-03-017. https://www3.epa.gov/ttn/catc/dir1/fventuri.pdf 75 U.S. EPA, Air Pollution Control Technology Fact Sheet, Dry Electrostatic Precipitator (ESP) – Wire-Plate Type, EPA-452/F-03-028. https://www3.epa.gov/ttn/catc/dir1/fdespwpl.pdf NOI Application Ramboll 23 of 52 5.3.1.5 Step 5 – Select BACT Peak has selected baghouse control as BACT for PM10 and PM2.5 emissions from the fluidized bed dryers, as baghouses offer the highest level of PM control and are widely accepted as BACT for similar source types. Peak proposes an emission limit of 0.010 gr/dscf for PM10 and PM2.5 (filterable + condensable) and 10% for opacity, consistent with the BACT emission limits for similar dryer source types in the RBLC. 5.3.2 NOX BACT Analysis for Fluidized Bed Dryers 5.3.2.1 Step 1 – Identify Available Control Technologies Potentially available NOX control technologies include: • Selective Catalytic Reduction (SCR); • Selective Non-Catalytic Reduction (SNCR); and • Low-NOX Burners/Good Burner Design and Combustion Practices. Selective Catalytic Reduction SCRs use a reducing agent, such as ammonia or urea, to chemically reduce the NOX emissions in the exhaust stream into nitrogen (N2) gas and water vapor (H2O) on the surface of a catalyst. The NOX reduction reaction is only effective at high temperatures. The temperature range for standard base metal catalyst is between 400 -800°F. As such, SCRs are a common technology for controlling NOX emissions from combustion sources, such as boilers, process heaters, turbines, and engines. SCRs are capable of NOX reduction efficiencies in the range of 70 to 90%.76 The SCR process requires the installation of reagent storage facilities, a system capable of metering and diluting the stock reagent into the appropriate solution, and an atomization/injection system at the appropriate locations in the combustion unit. Selective Non-Catalytic Reduction The SNCR system also injects a reducing agent (ammonia or urea) into the exhaust stream to chemically reduce the NOX emissions. However, unlike SCRs, the SNCR does not involve a catalyst to aid in the chemical reaction. As a result, SNCRs are less expensive to install but also achieve a lower NOX control efficiency than an SCR. Typical SNCR control efficiencies range between 30 to 50% for NOX.77 Low-NOx Burners/Good Burner Design and Combustion Practices NOX emissions from combustion can be effectively reduced via good burner design without the need for add-on controls. Low NOX burners are a commonly used control technique which reduce NOX emissions by accomplishing combustion in stages, reducing NOX emissions 40 to 85% relative to uncontrolled emission levels.78 Equipment shall operate and be maintained in accordance with the manufacturer’s specification, which technical staff shall be trained on. 5.3.2.2 Step 2 – Eliminate Technically Infeasible Options Peak has conservatively considered all control technologies identified in Step 1 to be technically feasible for the product dryers for the purposes of this BACT evaluation. However, it should be noted that a review of EPA’s RBLC database and other control technology resources for similar furnaces, dryers, and burners shows that neither SCR nor SNCR has 76 U.S. EPA, Air Pollution Control Technology Fact Sheet, Selective Catalytic Reduction (SCR), EPA-452/F-03-032. https://www3.epa.gov/ttn/catc/dir1/fscr.pdf 77 U.S. EPA, Air Pollution Control Technology Fact Sheet, Selective Non-Catalytic Reduction (SNCR), EPA-452/F-03- 031. https://www3.epa.gov/ttn/catc/dir1/fsncr.pdf 78 U.S. EPA, AP-42, Section 1.4, Natural Gas Combustion (July 1998). https://www3.epa.gov/ttnchie1/ap42/ch01/final/c01s04.pdf NOI Application Ramboll 24 of 52 been implemented as an add-on NOX control measure in other operations similar to the product dryers to be used by Peak. 5.3.2.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of NOX emissions: 1. SCR: 70-90% control efficiency 2. SNCR: 30-50% control efficiency 3. Good Burner Design and Combustion Practices: base case 5.3.2.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs Peak has evaluated the impacts of the remaining control technologies in the following sections. Selective Catalytic Reduction The exhaust stream from the product dryers will have a high concentration of PM10 and PM2.5 resulting from the dusty stone material being dried. As such, because of the particulate- laden stream, installation of a baghouse would be required upstream of an SCR to prevent catalyst plugging or poisoning. However, even with the installation of a baghouse, the remaining PM in the exhaust stream would still have a high potential to plug or poison the catalyst of an SCR, minimizing the SCR’s control effectiveness. Further, SCRs are only effective at controlling NOX emissions in high temperature exhaust gases, with the highest NOX control efficiencies occurring in gases with temperatures in the range of 700 to 750°F.79 Baghouses, however, are only capable of handling low temperature exhaust streams due to the fabric material in the control device. Even fabric filter material designed for higher temperatures are only capable of routinely accommodating up to 500°F.80 Although it may be technically feasible to operate a baghouse and SCR in series for the dryer exhaust stream, this would require increasing the temperature of the exhaust stream following the baghouse to the minimum optimal temperatures for an SCR by combusting propane which would result in additional combustion emissions. Doing so would also result in significant operational expenses. As such, given that the potential NOX emissions from the two fluid bed dryers are 3.6 tpy, the annualized capital and operational costs of an SCR would be significant in comparison to the small amount of pollutant that would be removed. An SCR would also pose adverse environmental impacts due to ammonia slip or urea release. Ammonia slip occurs from unreacted ammonia leaving the SCR with the exhaust gases resulting from incomplete reaction of the NOX and reducing reagent. Ammonia slip increases as the SCR catalyst activity decreases, which would be expected to occur in this application due to the particulate-laden exhaust stream. Peak has determined that the use of an SCR is not BACT for NOX controls based on the environmental, energy, and economic analyses. Selective Non-Catalytic Reduction Since a catalyst is not present in the control system, SNCRs are only effective for very high temperature exhaust streams. A minimum temperature of 1,600°F is needed for the NOX 79 U.S. EPA, Air Pollution Control Cost Manual (7th ed.), Section 4 – NOX Controls, Chapter 2 – Selective Catalytic Reduction, Section 2.2.2 – SCR Performance Parameters (May 2016). 80 U.S. EPA, Air Pollution Control Technology Fact Sheet, Fabric Filter – Pulse-Jet Cleaned Type (also referred to as Baghouses), EPA-452/F-03-025. https://www3.epa.gov/ttn/catc/dir1/ff-pulse.pdf NOI Application Ramboll 25 of 52 reduction reaction to occur in the absence of a catalyst.81 As such, operation of an SNCR in series with a baghouse would incur significant operating costs related to heating and cooling the exhaust stream in comparison to the small quantity of NOX that would be removed. Doing so would require combustion of propane which would result in additional combustion emissions. Further, like an SCR, an SNCR system would also pose adverse environmental impacts from ammonia slip resulting from incomplete reactions between the NOX and reducing agent. Peak has determined that the use of an SNCR is not BACT for NOX controls based on the environmental, energy, and economic analyses. Low-NOX Burner/Good Burner Design and Combustion Practices Since good burner design and combustion practices is not an add-on control technique, no adverse environmental, energy, or economic impacts are associated with this option. Good burner design includes low NOX burners and proper operation of the burners to reduce NOX formation. As such, Peak has determined that good burner design and combustion practices in conjunction with low-NOX burners is BACT for NOX controls for the product dryers. Equipment shall operate and be maintained in accordance with the manufacturer’s specification, which technical staff shall be trained on. 5.3.2.5 Step 5 – Select BACT Peak has selected good design (low NOX burners) and combustion practices as BACT for NOX emissions from the fluidized bed dryers. BACT is proposed as the use of low NOX burners in conjunction with the exclusive use of propane as fuel. Peak suppliers have confirmed low NOX burners (25 ppm NOX) are feasible for this equipment. Given the size of the dryers, the nominal NOX emissions calculated using AP-42, and previous approval of a concentration limit of 25 ppm as BACT for the two 8 MMBtu/hr fluidized bed dryers under the previous AO (DAQE-AN144290005-19), Peak is proposing the same limit as BACT for these proposed dryers. 5.3.3 VOC BACT Analysis for Fluidized Bed Dryers 5.3.3.1 Step 1 – Identify Available Control Technologies Potentially available VOC control technologies include: • Regenerative Thermal Oxidizer (RTO); • Regenerative Catalytic Oxidizer (RCO); • Catalytic Oxidation; • Wet Scrubber - Packed-Bed/Packed-Tower; • Bio-oxidation/Bio-filtration; and • Good Combustion Practices. Regenerative Thermal Oxidizer Thermal oxidation reduces VOC emissions by oxidizing VOC to carbon dioxide (CO2) gas and H2O at a high temperature with a residency time between one-half second and one second. RTOs are typically designed with a thermal recovery efficiency of 95%. RTOs are commonly used to control VOC emissions in high-volume low concentration gas streams, because the high thermal recovery efficiency for the control system (typically ranging from 95-99%) results in significant savings in fuel costs over other VOC control options while still achieving equal VOC emissions control efficiencies. A conventional thermal oxidizer (TO) does not have 81 U.S. EPA, Air Pollution Control Technology Fact Sheet, Selective Non-Catalytic Reduction (SNCR), EPA-452/F-03- 031. https://www3.epa.gov/ttn/catc/dir1/fsncr.pdf NOI Application Ramboll 26 of 52 heat recovery capability; therefore, the fuel costs are extremely high and are not suitable for high volume flow applications. An RTO uses high-density media such as a ceramic-packed bed still hot from a previous cycle to preheat an incoming VOC-laden waste gas stream. The preheated, partially oxidized gases then enter a combustion chamber where they are heated by auxiliary fuel combustion to a final oxidation temperature typically 1,400 to 1,500°F and maintained at this temperature to achieve maximum VOC destruction. The purified, hot gases exit this chamber and are directed to one or more different ceramic-packed beds cooled by an earlier cycle. Heat from the purified gases is absorbed by these beds before the gases are exhausted to the atmosphere. The reheated packed-bed then begins a new cycle by heating a new incoming waste gas stream. PM control must be placed upstream of thermal oxidation controls to remove unwanted PM that can cause plugging of heat exchange media or result in unsafe operations, such as fires, and significant operational and maintenance related difficulties. Typical VOC control efficiencies range from 95 to 99%.82 Regenerative Catalytic Oxidizer Similar to an RTO, an RCO oxidizes VOC to CO2 and H2O. However, an RCO uses catalyst to lower the activation energy required for the oxidation so that the oxidation can be accomplished at a lower temperature than an RTO. As a result, the overall auxiliary fuel is lower than that for an RTO. RCO technology is widely used in the reduction of VOC emissions. An RCO operates in the same fashion as an RTO, but it requires only moderate reheating to the operating range of the catalyst, approximately 450°F. As in the case of thermal oxidation units, PM control must be placed upstream of an RCO. Even with highly efficient PM control, there is the risk of catalyst blinding/poisoning and catalyst life guarantees are relatively short. The VOC destruction efficiency for an RCO typically ranges from 90 to 99%.83 Catalytic Oxidation A catalytic oxidizer uses a metal-enriched catalyst to oxidize VOC to CO2 and H2O at high temperatures. The VOC destruction efficiency is dependent upon factors such as VOC composition and concentration, operating temperature, oxygen concentration, catalyst characteristics, and space velocity. Under optimum operating conditions, catalytic oxidation can generally achieve approximately 95% VOC destruction efficiency.84 Wet Scrubber With packed-bed/packed-tower wet scrubbers (scrubbers), pollutants are removed by inertial or diffusional impaction, reaction with a sorbent or reagent slurry, or absorption into a liquid solvent. Wet scrubbers are widely used for controlling gaseous streams containing high VOC concentrations, especially for water-soluble compounds. Removal efficiencies for gas absorbers vary for each pollutant-solvent system and with the type of absorber used. Most absorbers can achieve removal efficiencies in excess of 90%, and packed-tower absorbers may achieve efficiencies as great as 99% for some pollutant-solvent systems.85 82 U.S. EPA, Air Pollution Control Technology Fact Sheet, Regenerative Incinerator, EPA-452/F-03-021. https://www3.epa.gov/ttn/catc/dir1/fregen.pdf 83 Ibid. 84 U.S. EPA, Air Pollution Control Technology Fact Sheet, Catalytic Incinerator, EPA-452/F-03-018. https://www3.epa.gov/ttn/catc/dir1/fcataly.pdf 85 U.S. EPA, Air Pollution Control Technology Fact Sheet, Packed-Bed/Packed-Tower Wet Scrubber, EPA-452/F-03- 015. https://www3.epa.gov/ttn/catc/dir1/fpack.pdf NOI Application Ramboll 27 of 52 Bio-oxidation/Bio-filtration Bio-oxidation/bio-filtration offers a cost-effective alternative to traditional thermal and catalytic oxidation systems in limited situations. In limited applications this air pollution control technology can provide a reduction in VOC emissions of 60 to 99.9%.86 Specifically, VOCs are oxidized using living micro-organisms on a media bed (sometimes referred to as a “bioreactor”). A fan is typically used to collect or draw contaminated air from a building or process. If the air is not properly conditioned (heat, humidity, solids), then pre -treatment is a necessary step to obtain optimum gas stream conditions before introducing it into the bioreactor. As the emissions flow through the bed media, the pollutants are absorbed by moisture on the bed media and come into contact with the microbes. Depending on the volume of air required to be treated, the footprint of a bio-oxidation/bio- filtration system can be excessive and take up significant acreage. The microbes consume and metabolize the excess organic pollutants, converting them into CO2 and H2O, much like a traditional thermal and catalytic oxidation process. “Mesophilic” microbes are typically used in these systems. Mesophilic microbes can survive and metabolize VOC materials at conditions up to 110 to 120°F. Good Combustion Practices VOC formation during combustion is minimized by ensuring that the temperature, oxygen availability, and residence time are adequate for complete combustion. 5.3.3.2 Step 2 – Eliminate Technically Infeasible Options The wet scrubber system is eliminated as technically infeasible, as it is only effective for high concentration VOC exhaust streams. The low concentration of VOC in the dryers’ exhaust streams will be well below the acceptable range for a VOC condensation control technology to be effective. It should also be noted that use of a scrubber would generate additional environmental impacts and would require on-site or off-site treatment of the scrubber blowdown water to remove/treat the soluble VOC components removed from the exhaust stream. Because of the expected low control efficiency and additional environmental impacts, wet scrubbers are not considered technically feasible. Bio-oxidation/bio-filtration is effective in low temperature ranges; however, at higher temperatures, cell components can begin to decompose and proteins within the enzymes can become denatured and ineffective. The temperature of the exhaust steams from the product dryers is expected to range from 170 to 260°F, which exceeds the typical operating temperatures of a bio-oxidation/bio-filtration system. Furthermore, the expected footprint of a unit sized to handle the volume of gas needed for treatment would be extensive and impractical. Additionally, a review of EPA’s RBLC database and other control technology resources for similar furnaces, dryers, and burners shows that the use of this technology has not been demonstrated in practice for stone and nonmetallic mineral dryers. Due to the temperature limitations of this control technology, significant land requirements, and the undemonstrated nature of this technology for similar source types, bio-oxidation/bio- filtration has been eliminated from further consideration in this BACT analysis. All of the remaining VOC control devices identified in Step 1 are considered technically feasible for the dryers. 86 U.S. EPA, Using Bioreactors to Control Air Pollution, EPA-456/R-03-003. https://www3.epa.gov/ttncatc1/dir1/fbiorect.pdf NOI Application Ramboll 28 of 52 5.3.3.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of VOC emissions: 1. RTO/RCO: 90-99% control efficiency 2. Catalytic Oxidization: 95% control efficiency 3. Good Combustion Practices: base case 5.3.3.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The Site’s product dryers will have very low levels of VOC emissions, with uncontrolled potential VOC emissions of only 0.30 tpy from both dryers. An annualized control cost as low as $3,000 would exceed typical BACT cost effectiveness thresholds. Using the low ends of the ranges for annualized costs for RTOs, RCOs, and oxidation catalysts from EPA’s Air Pollution Control Technology Fact Sheets, the annualized cost of an add-on VOC control device would be at least $115,000 per dryer.87 As such, the costs associated with installing and operating the device far exceeds the emissions control benefits. Further, the use of add - on controls would result in adverse environmental impacts related to additional combustion emissions and an increase in greenhouse gas emissions from the oxidation of hydrocarbons in the exhaust stream to CO2. For these reasons, the use of add-on controls is not selected as BACT. Since good combustion practices is not an add-on control technique, no adverse environmental, energy, or economic impacts are associated with this option. As such, Peak has determined that good combustion practices are BACT for the product dryers. Table 3. Summary of Potential VOC Control Technology Costs for Fluidized Bed Dryers Control Technology Low-end Annualized Cost ($) RTO/RCO/Catalytic Oxidation ≥ $115,000 Good Combustion Practices No additional costs 5.3.3.5 Step 5 – Select BACT Peak has selected good combustion practices as BACT for VOC emissions from the fluidized bed dryers. BACT is proposed as the exclusive use of propane as fuel. 5.3.4 CO BACT Analysis for Fluidized Bed Dryers 5.3.4.1 Step 1 – Identify Available Control Technologies Potentially available CO control technologies include: • RTO/RCO; • Catalytic Oxidation; and • Good Combustion Practices. 87 Using the EPA’s Air Pollution Control Technology Fact Sheets for Regenerative Incinerators and Catalytic Incinerators, the lower end of the annualized cost range is $8/scfm for both RTOs and oxidation catalysts and $11/scfm for RCOs, not adjusted for inflation. The drying and sizing fluid bed dryer will have an exhaust flow rate of approximately 14,400scfm, and the glazing fluid bed dryer will have an exhaust flow rate of approximately 16,600 scfm. NOI Application Ramboll 29 of 52 Regenerative and Catalytic Oxidation RTO, RCO, and catalytic oxidation were previously described in detail in Section 5.3.3.1 of this report. Similar to the process for controlling VOCs, the use of these systems also provides control for CO emissions by oxidizing the CO to CO2. Under optimum operating conditions, an RTO or RCO system can achieve a CO destruction efficiency of approximately 98%.88,89 Good Combustion Practices CO formation during combustion is minimized by ensuring that the temperature, oxygen availability, and residence time are adequate for complete combustion. 5.3.4.2 Step 2 – Eliminate Technically Infeasible Options All of the CO control devices identified in Step 1 are considered technically feasible for the dryers. 5.3.4.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of CO emissions: 1. RTO/RCO/Catalytic Oxidation: Approximately 98% control efficiency 2. Good Combustion Practices: base case 5.3.4.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The Site’s product dryers will have very low levels of CO emissions, with uncontrolled potential CO emissions of only 2.1 tpy from both dryers. An annualized control cost as low as $20,000 would exceed typical BACT cost effectiveness thresholds. As previously discussed, using the low ends of the ranges for annualized costs for RTOs, RCOs, and oxidation catalysts from EPA’s Air Pollution Control Technology Fact Sheets, the annualized cost of an add-on CO control device would be at least $115,000 per dryer.90 As such, the costs associated with installing and operating the device far exceeds the emissions control benefits. Further, the use of add-on controls would result in adverse environmental impacts related to additional combustion emissions and an increase in greenhouse gas emissions from the oxidation of hydrocarbons in the exhaust stream to CO2. For these reasons, the use of add-on controls is not selected as BACT. Since good combustion practices is not an add-on control technique, no adverse environmental, energy, or economic impacts are associated with this option. Considering this, as well as the already low potential CO emissions from the dryers, Peak has determined that good combustion practices are BACT for the product dryers. 88 U.S. EPA, Air Pollution Control Technology Fact Sheet, Regenerative Incinerator, EPA-452/F-03-021. https://www3.epa.gov/ttn/catc/dir1/fregen.pdf 89 Manufacturers of Emission Controls Association, Emission Control Technology for Stationary Internal Combustion Engines, Status Report (July 1997). 90 Using the EPA’s Air Pollution Control Technology Fact Sheets for Regenerative Incinerators and Catalytic Incinerators, the lower end of the annualized cost range is $8/scfm for both RTOs and oxidation catalysts and $11/scfm for RCOs, not adjusted for inflation. The drying and sizing fluid bed dryer will have an exhaust flow rate of approximately 14,400 scfm, and the glazing fluid bed dryer will have an exhaust flow rate of approximately 16,600 scfm. NOI Application Ramboll 30 of 52 Table 4. Summary of Potential CO Control Technology Costs for Fluidized Bed Dryers Control Technology Low-end Annualized Cost ($) RTO/RCO/Catalytic Oxidation ≥ $115,000 Good Combustion Practices No additional costs 5.3.4.5 Step 5 – Select BACT Peak has selected good combustion practices as BACT for CO emissions from the fluidized bed dryers. BACT is proposed as the exclusive use of propane as fuel. 5.3.5 SO2 BACT Analysis for Fluidized Bed Dryers 5.3.5.1 Step 1 – Identify Available Control Technologies Potentially available SO2 control technologies include: • Scrubber; and • Use of a Low Sulfur Content Fuel. Scrubber A scrubber operates by injecting a solid reagent, such as a calcium or sodium-based alkaline, into the flue gas. The SO2 is then absorbed, neutralized, and/or oxidized by the alkaline agent into neutral salt. Scrubbers are capable of SO2 reduction efficiencies in the range of 50 to 98%.91 Use of a Low Sulfur Content Fuel SO2 emissions result from the oxidation of sulfur in the fuel during the combustion process. Fuel-based SO2 emissions are almost entirely dependent on the sulfur content of the fuel. As such, use of a fuel with a low sulfur content, such as natural gas, propane, and/or diesel/No. 2 fuel oil, inherently minimizes the quantity of SO2 emitted from the combustion process. 5.3.5.2 Step 2 – Eliminate Technically Infeasible Options All of the SO2 control devices identified in Step 1 are considered technically feasible for the dryers. 5.3.5.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of SO2 emissions: 1. Scrubber: 50-98% control efficiency 2. Use of a Low Sulfur Content Fuel: base case 5.3.5.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The Site’s product dryers will have very low levels of SO2 emissions, with uncontrolled potential SO2 emissions of only 0.015 tpy from both dryers. An annualized control cost as low as $150 would exceed typical BACT cost effectiveness thresholds. The annualized operating costs alone for a scrubber would exceed this figure. As such, the costs associated with installing and operating the device far exceeds the emissions control benefits. Further, 91 U.S. EPA, Air Pollution Control Technology Fact Sheet, Flue Gas Desulfurization (FGD) – Wet, Spray Dry, and Dry Scrubbers, EPA-452/F-03-034. https://www3.epa.gov/ttn/catc/dir1/ffdg.pdf NOI Application Ramboll 31 of 52 the use of a scrubber would also have associated energy impacts related to system pumps and environmental impacts associated with wastewater treatment and disposal. For these reasons, the use of a scrubber is not selected as BACT. Since the use of a low sulfur content fuel is not an add-on control technique, no adverse environmental, energy, or economic impacts are associated with this option. Considering this, as well as the already low potential SO2 emissions from the dryers, Peak has determined that the exclusive use of propane, which is an inherently low sulfur content fuel, is BACT for the dryers. 5.3.5.5 Step 5 – Select BACT Peak has selected the use of a low sulfur content fuel as BACT for SO2 emissions from the fluidized bed dryers. BACT is proposed as the exclusive use of propane as fuel. 5.4 BACT Analysis for Propane Boiler The processing facility will include one (1) propane steam boiler for the processing of MgCl2 and bischofite. The boiler will have a maximum heat input capacity of 14.7 MMBTU/hr. The boiler will be a source of criteria pollutant emissions resulting from propane combustion. Emissions will be released through the boiler stack. 5.4.1 PM10 and PM2.5 BACT Analysis for Propane Boiler 5.4.1.1 Step 1 – Identify Available Control Technologies Peak identified good combustion practices and use of a clean fuel as PM10 and PM2.5 BACT for the propane boiler. Good Combustion Practices and Use of a Clean Fuel Good combustion practices and the use of clean fuels with negligible ash contents and very low sulfur contents, such as natural gas, propane, and/or diesel/No. 2 fuel oil, minimizes the formation of PM10 and PM2.5 emissions from the combustion process. Equipment shall operate and be maintained in accordance with the manufacturer’s specification, which technical staff shall be trained on. 5.4.1.2 Step 2 – Eliminate Technically Infeasible Options Good combustion practices and use of a clean fuel is technically feasible for the boiler. 5.4.1.3 Step 3 – Rank Remaining Control Technologies This section is not applicable as good combustion practices and use of a clean fuel is the only proposed BACT. 5.4.1.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs There are no reasonable controls for PM10 and PM2.5 other than good combustion practices that are achieved in practice for small boilers such as Peak’s proposed 14.7 MMBtu/hr propane boiler. 5.4.1.5 Step 5 – Select BACT Peak has selected good combustion practices and use of a clean fuel as BACT for PM10 and PM2.5 emissions from the boiler. 5.4.2 NOX BACT Analysis for Propane Boiler 5.4.2.1 Step 1 – Identify Available Control Technologies Potentially available NOX control technologies include: • Selective Catalytic Reduction (SCR); • Selective Non-Catalytic Reduction (SNCR); and NOI Application Ramboll 32 of 52 • Ultra-Low NOX Burners/Good Burner Design and Combustion Practices. Selective Catalytic Reduction SCRs use a reducing agent, such as ammonia or urea, to chemically reduce the NOX emissions in the exhaust stream into nitrogen (N2) gas and water vapor (H2O) on the surface of a catalyst. The NOX reduction reaction is only effective at high temperatures. The temperature range for standard base metal catalyst is between 400 -800°F. As such, SCRs are a common technology for controlling NOX emissions from combustion sources, such as boilers, process heaters, turbines, and engines. SCRs are capable of NOX reduction efficiencies in the range of 70 to 90%.92 The SCR process requires the installation of reagent storage facilities, a system capable of metering and diluting the stock reagent into the appropriate solution, and an atomization/injection system at the appropriate locations in the combustion unit. Selective Non-Catalytic Reduction The SNCR system also injects a reducing agent (ammonia or urea) into the exhaust stream to chemically reduce the NOX emissions. However, unlike SCRs, the SNCR does not involve a catalyst to aid in the chemical reaction. As a result, SNCRs are less expensive to install but also achieve a lower NOX control efficiency than an SCR. Typical SNCR control efficiencies range between 30 to 50% for NOX.93 Ultra-Low NOX Burner/Good Burner Design and Combustion Practices NOX emissions from combustion can be effectively reduced via good burner design without the need for add-on controls. Low NOX burners are a commonly used control technique which reduce NOX emissions by accomplishing combustion in stages, reducing NOX emissions 40% to 85% relative to uncontrolled emission levels.94 Ultra-low NOX burners reduce NOX emissions more so than standard low-NOX burners. Equipment shall operate and be maintained in accordance with the manufacturer’s specification, which technical staff shall be trained on. 5.4.2.2 Step 2 – Eliminate Technically Infeasible Options Peak has conservatively considered all control technologies identified in Step 1 to be technically feasible for the boiler for the purposes of this BACT evaluation. However, it should be noted that a review of EPA’s RBLC database and other control technology resources for similar furnaces, dryers, and burners shows that neither SCR nor SNCR has been implemented as an add-on NOX control measure in other operations similar to the small 14.7 MMBtu/hr boiler to be used by Peak. Further, Peak consulted their supplier and determined ultra-low NOX burners down to 13 ppm NOX (only) were technically feasible for the propane boiler95. 92 U.S. EPA, Air Pollution Control Technology Fact Sheet, Selective Catalytic Reduction (SCR), EPA-452/F-03-032. https://www3.epa.gov/ttn/catc/dir1/fscr.pdf 93 U.S. EPA, Air Pollution Control Technology Fact Sheet, Selective Non-Catalytic Reduction (SNCR), EPA-452/F-03- 031. https://www3.epa.gov/ttn/catc/dir1/fsncr.pdf 94 U.S. EPA, AP-42, Section 1.4, Natural Gas Combustion (July 1998). https://www3.epa.gov/ttnchie1/ap42/ch01/final/c01s04.pdf 95 In line with UDAQ BACT guidance, Peak evaluated ultra-low and low-NOX burners from 9 to 30 ppm NOX. While UAC R307-316 (NOX Emission Controls for Natural Gas-Fired Boilers Greater Than 5.0 MMBtu) specifies 9 ppm as technically feasible for Northern Wasatch Front, 13 ppm was the lowest achievable for the proposed equipment according to the manufacturer. R307-316 is not applicable in Millard County. NOI Application Ramboll 33 of 52 5.4.2.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of NOX emissions: 1. SCR: 70-90% control efficiency 2. SNCR: 30-50% control efficiency 3. Good Burner Design and Combustion Practices: base case 5.4.2.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs Peak has evaluated the impacts of the remaining control technologies in the following sections. Selective Catalytic Reduction SCRs are only effective at controlling NOX emissions in high temperature exhaust gases, with the highest NOX control efficiencies occurring in gases with temperatures in the range of 700 to 750°F.96 Although it may be technically feasible to operate an SCR in series with the boiler exhaust stream, this would require increasing the temperature of the exhaust stre am following the boiler to the minimum optimal temperatures for an SCR by combusting propane which would result in additional combustion emissions. Doing so would also result in significant operational expenses, such as fuel costs. An SCR would also pose adverse environmental impacts due to ammonia slip or urea release. Ammonia slip occurs from unreacted ammonia leaving the SCR with the exhaust gases resulting from incomplete reaction of the NOX and reducing reagent. Ammonia slip increases as the SCR catalyst activity decreases, which would be expected to occur in this application due to the particulate-laden exhaust stream. Peak has determined that the use of an SCR is not BACT for NOX controls based on the environmental, energy, and economic analyses. Selective Non-Catalytic Reduction Since a catalyst is not present in the control system, SNCRs are only effective for very high temperature exhaust streams. A minimum temperature of 1,600°F is needed for the NOX reduction reaction to occur in the absence of a catalyst.97 As such, operation of an SNCR in series with a boiler would incur significant operating costs related to heating and cooling the exhaust stream in comparison to the small quantity of NOX that would be removed. Doing so would require combustion of propane which would result in additional combustion emissions. Further, like an SCR, an SNCR system would also pose adverse environmental impacts from ammonia slip resulting from incomplete reactions between the NOX and reducing agent. Peak has determined that the use of an SNCR is not BACT for NOX controls based on the environmental, energy, and economic analyses. Ultra-Low NOX Burner/Good Burner Design and Combustion Practices Since good burner design and combustion practices is not an add-on control technique, no adverse environmental, energy, or economic impacts are associated with this option. Good burner design includes low NOX or ultra-low NOx burners and proper operation of the burners to reduce NOX formation. As such, Peak has determined that good burner design and 96 U.S. EPA, Air Pollution Control Cost Manual (7th ed.), Section 4 – NOX Controls, Chapter 2 – Selective Catalytic Reduction, Section 2.2.2 – SCR Performance Parameters (June 2019). 97 U.S. EPA, Air Pollution Control Technology Fact Sheet, Selective Non-Catalytic Reduction (SNCR), EPA-452/F-03- 031. https://www3.epa.gov/ttn/catc/dir1/fsncr.pdf NOI Application Ramboll 34 of 52 combustion practices in conjunction with ultra-low NOX burners (i.e., 13 ppm) is BACT for NOX controls for the boiler. 5.4.2.5 Step 5 – Select BACT Peak has selected good burner design (including ultra-low NOX burners) and combustion practices as BACT for NOX emissions from the boiler. As indicated above, the boiler manufacturer indicated the lowest NOX emission level the propane boiler unit can achieve is 13 ppm NOX, as 9 ppm NOX is only achievable using natural gas and not propane. Therefore, Peak proposes a 13 ppm NOX propane-fired burner as NOX BACT for the boiler. 5.4.3 VOC BACT Analysis for Propane Boiler 5.4.3.1 Step 1 – Identify Available Control Technologies Potentially available VOC control technologies include: • Regenerative Thermal Oxidizer (RTO); • Regenerative Catalytic Oxidizer (RCO); • Catalytic Oxidation; and • Good Combustion Practices. Regenerative Thermal Oxidizer Thermal oxidation reduces VOC emissions by oxidizing VOC to carbon dioxide (CO2) gas and H2O at a high temperature with a residency time between one-half second and one second. RTOs are typically designed with a thermal recovery efficiency of 95%. RTOs are commonly used to control VOC emissions in high-volume low concentration gas streams, because the high thermal recovery efficiency for the control system (typically ranging from 95-99%) results in significant savings in fuel costs over other VOC control options while still achieving equal VOC emissions control efficiencies. A conventional thermal oxidizer (TO) does not have heat recovery capability; therefore, the fuel costs are extremely high and are not suitable for high volume flow applications. An RTO uses high-density media such as a ceramic-packed bed still hot from a previous cycle to preheat an incoming VOC-laden waste gas stream. The preheated, partially oxidized gases then enter a combustion chamber where they are heated by auxiliary fuel combustion to a final oxidation temperature typically 1,400 to 1,500°F and maintained at this temperature to achieve maximum VOC destruction. The purified, hot gases exit this chamber and are directed to one or more different ceramic-packed beds cooled by an earlier cycle. Heat from the purified gases is absorbed by these beds before the gases are exhausted to the atmosphere. The reheated packed-bed then begins a new cycle by heating a new incoming waste gas stream. PM control must be placed upstream of thermal oxidation controls to remove unwanted PM that can cause plugging of heat exchange media or result in unsafe operations, such as fires, and significant operational and maintenance related difficulties. Typical VOC control efficiencies range from 95 to 99%.98 Regenerative Catalytic Oxidizer Similar to an RTO, an RCO oxidizes VOC to CO2 and H2O. However, an RCO uses catalyst to lower the activation energy required for the oxidation so that the oxidation can be accomplished at a lower temperature than an RTO. As a result, the overall auxiliary fuel is lower than that for an RTO. RCO technology is widely used in the reduction of VOC emissions. An RCO operates in the same fashion as an RTO, but it requires only moderate 98 U.S. EPA, Air Pollution Control Technology Fact Sheet, Regenerative Incinerator, EPA-452/F-03-021. https://www3.epa.gov/ttn/catc/dir1/fregen.pdf NOI Application Ramboll 35 of 52 reheating to the operating range of the catalyst, approximately 450°F. As in the case of thermal oxidation units, PM control must be placed upstream of an RCO. Even with highly efficient PM control, there is the risk of catalyst blinding/poisoning and catalyst life guarantees are relatively short. The VOC destruction efficiency for an RCO typically ranges from 90 to 99%.99 Catalytic Oxidation A catalytic oxidizer uses a metal-enriched catalyst to oxidize VOC to CO2 and H2O at high temperatures. The VOC destruction efficiency is dependent upon factors such as VOC composition and concentration, operating temperature, oxygen concentratio n, catalyst characteristics, and space velocity. Under optimum operating conditions, catalytic oxidation can generally achieve approximately 95% VOC destruction efficiency.100 Good Combustion Practices VOC formation during combustion is minimized by ensuring that the temperature, oxygen availability, and residence time are adequate for complete combustion. Equipment shall operate and be maintained in accordance with the manufacturer’s specification, which technical staff shall be trained on. 5.4.3.2 Step 2 – Eliminate Technically Infeasible Options All of the VOC control devices identified in Step 1 are considered technically feasible for the boiler. 5.4.3.3 Step 3 – Rank Remaining Control Technologies The control options were ranked in order of greatest to least control of VOC emissions: 1. RTO/RCO: 90-99% control efficiency 2. Catalytic Oxidization: 95% control efficiency 3. Good Combustion Practices: base case 5.4.3.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The Site’s boiler will have very low levels of VOC emissions, with uncontrolled potential VOC emissions of only 0.70 tpy from the boiler. An annualized control cost as low as $7,000 would exceed typical BACT cost effectiveness thresholds. Using the low ends of the ranges for annualized costs for RTOs, RCOs, and oxidation catalysts from EPA’s Air Pollution Control Technology Fact Sheets, the annualized cost of an add-on VOC control device would be at least $10,000 for the boiler.101 As such, the costs associated with installing and operating the device far exceeds the emissions control benefits. Further, the use of add -on controls would result in adverse environmental impacts related to additional combustion emissions and an increase in greenhouse gas emissions from the oxidation of hydrocarbons in the exhaust stream to CO2. For these reasons, the use of add-on controls is not selected as BACT. Since good combustion practices is not an add-on control technique, no adverse environmental, energy, or economic impacts are associated with this option. As such, Peak has determined that good combustion practices are BACT for the boiler. 99 Ibid. 100 U.S. EPA, Air Pollution Control Technology Fact Sheet, Catalytic Incinerator, EPA-452/F-03-018. https://www3.epa.gov/ttn/catc/dir1/fcataly.pdf 101 Using the EPA’s Air Pollution Control Technology Fact Sheets for Regenerative Incinerators and Catalytic Incinerators, the lower end of the annualized cost range is $8/scfm for both RTOs and oxidation catalysts and $11/scfm for RCOs, not adjusted for inflation. The boiler stack will have an exhaust flow rate of approximately 545 scfm. NOI Application Ramboll 36 of 52 Table 5. Summary of Potential VOC Control Technology Costs for Boiler Control Technology Low-end Annualized Cost ($) RTO/RCO/Catalytic Oxidation ≥ $10,000 Good Combustion Practices No additional costs 5.4.3.5 Step 5 – Select BACT Peak has selected good combustion practices as BACT for VOC emissions from the boiler. BACT is proposed as the exclusive use of propane as fuel. 5.4.4 CO BACT Analysis for Propane Boiler 5.4.4.1 Step 1 – Identify Available Control Technologies Potentially available CO control technologies include: • RCO; • Catalytic Oxidation; and • Good Combustion Practices. Regenerative and Catalytic Oxidation RCO, and catalytic oxidation were previously described in detail in Section 5.3.3.1 of this report. Similar to the process for controlling VOCs, the use of these systems also provides control for CO emissions by oxidizing the CO to CO2. Under optimum operating conditions, an RCO system can achieve a CO destruction efficiency of approximately 98%.102,103 Good Combustion Practices CO formation during combustion is minimized by ensuring that the temperature, oxygen availability, and residence time are adequate for complete combustion. 5.4.4.2 Step 2 – Eliminate Technically Infeasible Options Peak has conservatively considered all control technologies identified in Step 1 to be technically feasible for the boiler for the purposes of this BACT evaluation. However, it should be noted that a review of EPA’s RBLC database and other control technology resources for similar furnaces, dryers, and burners shows that RCO has not been implemented as an add- on CO control measure in other operations similar to the boiler to be used by Peak. 5.4.4.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of CO emissions: 1. RCO/Catalytic Oxidation: Approximately 98% control efficiency 2. Good Combustion Practices: base case 102 U.S. EPA, Air Pollution Control Technology Fact Sheet, Regenerative Incinerator, EPA-452/F-03-021. https://www3.epa.gov/ttn/catc/dir1/fregen.pdf 103 Manufacturers of Emission Controls Association, Emission Control Technology for Stationary Internal Combustion Engines, Status Report (July 1997). NOI Application Ramboll 37 of 52 5.4.4.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The Site’s boiler will have uncontrolled potential CO emissions of 4.7 tpy from the boiler, which was calculated based on emission factors for propane combustion in AP-42 Table 1.5- 1. RCO/Catalytic Oxidation The cost of using the highest ranked control technology, an RCO, would exceed the benefit of the CO reduction it would offer. In evaluating RCO costs for the boiler, the current cost of controlling CO with an RCO is estimated to be approximately $250K per ton of CO removed. As such, the use of RCO is not selected as BACT. Since good combustion practices is not an add-on control technique, no adverse environmental, energy, or economic impacts are associated with this option. Considering this, as well as the already low potential CO emissions from the boiler, Peak has determined that good combustion practices are BACT for the boiler. Table 6. Summary of Potential CO Control Technology Costs for Boiler Control Technology Average Cost Effectiveness ($/ton pollutant removed) RTO/RCO/Catalytic Oxidation ≥ $250,000 Good Combustion Practices No additional costs 5.4.4.5 Step 5 – Select BACT Peak has selected good combustion practices as BACT for CO emissions from the boiler. BACT is proposed as the exclusive use of propane as fuel. 5.4.5 SO2 BACT Analysis for Boiler 5.4.5.1 Step 1 – Identify Available Control Technologies Peak identified Use of a Low Sulfur Content Fuel as SO2 BACT for the propane boiler. Use of a Low Sulfur Content Fuel SO2 emissions result from the oxidation of sulfur in the fuel during the combustion process. Fuel-based SO2 emissions are almost entirely dependent on the sulfur content of the fuel. As such, use of a fuel with a low sulfur content, such as natural gas, propane, and/or diesel/No. 2 fuel oil, inherently minimizes the quantity of SO2 emitted from the combustion process. 5.4.5.2 Step 2 – Eliminate Technically Infeasible Options Use of a Low Sulfur Content Fuel is technically feasible for the boiler. 5.4.5.3 Step 3 – Rank Remaining Control Technologies This section is not applicable as Use of a Low Sulfur Content Fuel is the only proposed BACT. 5.4.5.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The Site’s boiler will have very low levels of SO2 emissions, with uncontrolled potential SO2 emissions of only 0.034 tpy from the boiler. There are no reasonable controls for SO2 that are achieved in practice for small boilers such as Peak’s proposed 14.7 MMBtu/hr boiler. Since the use of a low sulfur content fuel is not an add-on control technique, no adverse environmental, energy, or economic impacts are associated with this option. Considering NOI Application Ramboll 38 of 52 this, as well as the already low potential SO2 emissions from the boiler, Peak has determined that the exclusive use of propane, which is an inherently low sulfur content fuel, is BACT for the boiler. 5.4.5.5 Step 5 – Select BACT Peak has selected the use of a low sulfur content fuel as BACT for SO2 emissions from the boiler. The proposed BACT is the exclusive use of propane as fuel. 5.5 BACT Analysis for Stationary Non-Emergency Engines The Site will involve eleven (11) stationary non-emergency engines to power the Site’s pumps. The capacity of the engines will range from 20 bhp to 139 bhp. Each engine will be Tier 4 certified and will exclusively fire ultra-low sulfur diesel fuel (15 ppm maximum), in accordance with the requirements of 40 CFR 60 Subpart IIII. Operation of the eight (8) main pump generator sets will be temporary and will occur between Years 1 and 2 of the Project. Operation of the three (3) pond mobile pumps will occur for the duration of the Project, approximately thirty-five years total. 5.5.1 PM10 and PM2.5 BACT Analysis for Stationary Non-Emergency Engines 5.5.1.1 Step 1 – Identify Available Control Technologies Potentially available PM control technologies include: • Cyclone; • Baghouse/Fabric Filter; • Mechanically-Aided Wet Scrubber; • Venturi Wet Scrubber; • ESP; and • Good Combustion Practices and Use of a Clean Fuel. Each of these control options was discussed in detail in Section 5.3.1.1 of this application. 5.5.1.2 Step 2 – Eliminate Technically Infeasible Options All of the PM10 and PM2.5 control devices identified in Step 1 are considered technically feasible for the engines. 5.5.1.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of PM10 and PM2.5 emissions: 1. Baghouse/Fabric Filter/ESP: 99-99.9% control efficiency 2. Mechanically-Aided and Venturi Wet Scrubber: 70-99% control efficiency 3. Cyclone: 30-90% control efficiency for PM10; 0-40% control efficiency for PM2.5 4. Good Combustion Practices and Use of a Clean Fuel: base case 5.5.1.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The proposed PM10 and PM2.5 BACT for the non-emergency engines is the use of Tier 4- certified engines, in accordance with the requirements of 40 CFR 60 Subpart IIII. There are no adverse environmental, energy, or economic impacts associated with this option. The Tier 4 Final emission standards represent up to a 70% reduction in PM emissions over the Tier 4 Interim emission standards. Given the low level of potential PM10 and PM2.5 emissions from these engines (between 0.005 tpy and 0.02 tpy per engine, depending on engine size) and the fact that the engines will only be in operation for six years, the use of add-on controls, such as diesel particulate filters, would not be cost effective given the small quantity of emissions reductions that would be achieved during this period. NOI Application Ramboll 39 of 52 5.5.1.5 Step 5 – Select BACT Peak has selected the use of Tier 4-certified engines and the exclusive use of ultra-low sulfur diesel fuel as BACT for PM10 and PM2.5 emissions from the stationary non-emergency engines. 5.5.2 NOX BACT Analysis for Stationary Non-Emergency Engines 5.5.2.1 Step 1 – Identify Available Control Technologies Potentially available NOX control technologies include: • SCR; • SNCR; and • Good Burner Design and Combustion Practices. Each of these control options was discussed in detail in Section 5.3.2.1 of this application. 5.5.2.2 Step 2 – Eliminate Technically Infeasible Options All of the NOX control devices identified in Step 1 are considered technically feasible for the engines. 5.5.2.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of NOX emissions: 1. SCR: 70-90% control efficiency 2. SNCR: 30-50% control efficiency 3. Good Burner Design and Combustion Practices: base case 5.5.2.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The proposed NOX BACT for the non-emergency engines is the use of Tier 4-certified engines, in accordance with the requirements of 40 CFR 60 Subpart IIII. There are no adverse environmental, energy, or economic impacts associated with this option. The Tier 4 Final emission standards represent up to an 88% reduction in NOX emissions over Tier 4 Interim emission standards. Given the relatively low level of potential NOX emissions from these engines (between 0.09 tpy and 1.7 tpy per engine, depending on engine size) and the fact that the engines will only be in operation for six years, the use of add-on controls, such as SCRs, would not be cost effective given the small quantity of emissions reductions that would be achieved during this period. 5.5.2.5 Step 5 – Select BACT Peak has selected the use of Tier 4-certified engines as BACT for NOX emissions from the stationary non-emergency engines. 5.5.3 VOC BACT Analysis for Stationary Non-Emergency Engines 5.5.3.1 Step 1 – Identify Available Control Technologies Potentially available VOC control technologies include: • RTO; • RCO; • Catalytic Oxidation; • Wet Scrubber - Packed-Bed/Packed-Tower; • Bio-oxidation/Bio-filtration; and • Good Combustion Practices. Each of these control options was discussed in detail in Section 5.3.3.1 of this report. NOI Application Ramboll 40 of 52 5.5.3.2 Step 2 – Eliminate Technically Infeasible Options For reasons consistent with those presented in Section 5.3.3.2 for the dryers, neither a wet scrubber system nor bio-oxidation/bio-filtration are technically feasible control options for the engines. The low concentration of VOC in the engines’ exhaust streams would be below the acceptable range for a VOC condensation control technology (i.e., wet scrubbers) to be effective, and the exhaust temperatures will well exceed the maximum temperature for a bio-oxidation/bio-filtration system. All of the remaining VOC control devices identified in Step 1 are considered technically feasible for the engines. 5.5.3.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of VOC emissions: 1. RTO/RCO: 90-99% control efficiency 2. Catalytic Oxidation: 95% control efficiency 3. Good Combustion Practices: base case 5.5.3.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The proposed VOC BACT for the non-emergency engines is the use of Tier 4-certified engines, in accordance with the requirements of 40 CFR 60 Subpart IIII. There are no adverse environmental, energy, or economic impacts associated with this option. EPA determined when promulgating NSPS Subpart IIII that the Tier 4 emission standards for NMHC represent a sufficiently low level of emissions without the need for additional add-on controls, such as oxidation catalyst. Given the low level of potential VOC emissions from these engines (between 0.01 tpy and 0.2 tpy per engine, depending on engine size) and the fact that the engines will only be in operation for six years, the use of add -on controls would not be cost effective given the small quantity of emissions reductions that would be achieved during this period. 5.5.3.5 Step 5 – Select BACT Peak has selected the use of Tier 4-certified engines as BACT for VOC emissions from the stationary non-emergency engines. 5.5.4 CO BACT Analysis for Stationary Non-Emergency Engines 5.5.4.1 Step 1 – Identify Available Control Technologies Potentially available CO control technologies include: • RTO/RCO; • Catalytic Oxidation; and • Good Combustion Practices. Each of these control options was discussed in detail in Sections 5.3.3.1 and 5.3.4.1 of this application. 5.5.4.2 Step 2 – Eliminate Technically Infeasible Options All of the CO control devices identified in Step 1 are considered technically feasible for the engines. 5.5.4.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of CO emissions: 1. RTO/RCO/Catalytic Oxidation: < 98% control efficiency NOI Application Ramboll 41 of 52 2. Good Combustion Practices: base case 5.5.4.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The proposed CO BACT for the non-emergency engines is the use of Tier 4-certified engines, in accordance with the requirements of 40 CFR 60 Subpart IIII. EPA determined when promulgating NSPS Subpart IIII that the Tier 4 emission standards for CO represent a sufficiently low level of emissions without the need for additional add -on controls, such as oxidation catalyst. The potential CO emissions from the non-emergency engines range from 0.5 tpy for the smallest engine size to 5.0 tpy for the largest. The current cost of controlling CO emissions with an oxidation system (i.e., RTO, RCO, or oxidation catalysts) would be at least $23,615 per ton of pollutant removed, based on the engine size with the highest CO emissions. As such, the costs associated with installing and operating the device exceeds the emissions control benefits. Furthermore, the use of add-on controls would also result in adverse environmental impacts related to additional combustion emissions and an increase in greenhouse gas emissions from the oxidation of hydrocarbons in the exhaust stream to CO2. Peak has determined that the use of add-on controls is not BACT based on the economic, environmental, and energy analyses. There are no adverse environmental, energy, or economic impacts associated with the purchase and installation of a Tier 4-certified engine. As such, Peak has determined that Tier 4 certification is BACT. Table 7. Summary of Potential CO Control Technology Costs for Non-Emergency Engines Control Technology Average Cost Effectiveness ($/ton pollutant removed) RTO/RCO/Catalytic Oxidation ≥ $23,615 Tier 4 Certification No additional costs 5.5.4.5 Step 5 – Select BACT Peak has selected the use of Tier 4-certified engines as BACT for CO emissions from the stationary non-emergency engines. 5.5.5 SO2 BACT Analysis for Stationary Non-Emergency Engines 5.5.5.1 Step 1 – Identify Available Control Technologies Potentially available SO2 control technologies include: • Scrubber; and • Use of a Low Sulfur Content Fuel. These control options were discussed in detail in Section 5.3.5.1 of this application. 5.5.5.2 Step 2 – Eliminate Technically Infeasible Options All of the SO2 control devices identified in Step 1 are considered technically feasible for the engines. 5.5.5.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of SO2 emissions: 1. Scrubber: 50-98% control efficiency 2. Use of a Low Sulfur Content Fuel: base case NOI Application Ramboll 42 of 52 5.5.5.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The proposed SO2 BACT for the non-emergency engines is the exclusive use of ultra-low sulfur diesel fuel, in accordance with the requirements of 40 CFR 60 Subpart IIII. There are no adverse environmental, energy, or economic impacts associated with this option. Ultra- low sulfur diesel fuel has a maximum sulfur content of 15 ppm (0.0015%), resulting in very small potential SO2 emissions from the engines (between 0.0002 tpy and 0.005 tpy per engine, depending on engine size). Given these low emissions levels and the fact that the engines will only be in operation for six years, the use of add-on controls would not be cost effective given the small quantity of emissions reductions that would be achieved during this period. 5.5.5.5 Step 5 – Select BACT Peak has selected the exclusive use of ultra-low sulfur diesel fuel as BACT for SO2 emissions from the stationary non-emergency engines. 5.6 BACT Analysis for Stationary Emergency Engines The Site will involve three (3) stationary emergency engines. Specifically, the Site will have one (1) 100 bhp stationary emergency fire water pump engine and two (2) 1,342 bhp stationary emergency generator engines. Each engine will be exclusively fired with ultra-low sulfur diesel fuel (15 ppm maximum), in accordance with the requirements of 40 CFR 60 Subpart IIII. Additionally, Peak proposes for each of these emergency engines to be Tier 4- certified, which is more stringent than the required certification levels under NSPS Subpart IIII for emergency engines. A more detailed discussion on the required emissions certification under the NSPS is included in Section 4.3.7 of this application. 5.6.1 PM10 and PM2.5 BACT Analysis for Stationary Emergency Engines 5.6.1.1 Step 1 – Identify Available Control Technologies Potentially available PM control technologies include: • Cyclone; • Baghouse/Fabric Filter; • Mechanically-Aided Wet Scrubber; • Venturi Wet Scrubber; • ESP; and • Good Combustion Practices and Use of a Clean Fuel. Each of these control options was discussed in detail in Section 5.3.1.1 of this application. 5.6.1.2 Step 2 – Eliminate Technically Infeasible Options All of the PM10 and PM2.5 control devices identified in Step 1 are considered technically feasible for the engines. 5.6.1.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of PM10 and PM2.5 emissions: 1. Fabric Filter/ESP: 99-99.9% control efficiency 2. Mechanically-Aided and Venturi Wet Scrubber: 70-99% control efficiency 3. Cyclone: 30-90% control efficiency for PM10; 0-40% control efficiency for PM2.5 4. Good Combustion Practices and Use of a Clean Fuel: base case 5.6.1.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The proposed PM10 and PM2.5 BACT for the emergency engines is the use of Tier 4-certified engines, which is more stringent than the emission certification requirements of 40 CFR 60 NOI Application Ramboll 43 of 52 Subpart IIII. There are no adverse environmental, energy, or economic impacts associated with this option. The Tier 4 Final emission standards represent up to a 70% reduction in PM emissions over the Tier 4 Interim emission standards. Given the low level of potential PM10 and PM2.5 emissions from these engines (between 0.0002 tpy and 0.003 tpy per engine, depending on engine size), the use of add-on controls, such as diesel particulate filters, would not be cost effective given the small quantity of emissions reductions that would be achieved. This is consistent with EPA’s economic analysis during the development of the emissions standards in 40 CFR 60 Subpart IIII, in which EPA determined that add-on controls are economically infeasible for emergency CI ICE. 5.6.1.5 Step 5 – Select BACT Peak has selected the use of Tier 4-certified engines and the exclusive use of ultra-low sulfur diesel fuel as BACT for PM10 and PM2.5 emissions from the stationary emergency engines. 5.6.2 NOX BACT Analysis for Stationary Emergency Engines 5.6.2.1 Step 1 – Identify Available Control Technologies Potentially available NOX control technologies include: • SCR; • SNCR; and • Good Burner Design and Combustion Practices. Each of these control options was discussed in detail in Section 5.3.2.1 of this application. 5.6.2.2 Step 2 – Eliminate Technically Infeasible Options The use of SNCR would pose technical concerns for an emergency generator due to the nature of the varying conditions of the exhaust stream. Under these conditions, the SNCR would not be capable of achieving steady-state operation and would result in adverse environmental impacts from ammonia slip. As such, Peak has eliminated SNCRs as technically infeasible for emergency engines. All of the remaining NOX control devices identified in Step 1 are considered technically feasible for the engines. 5.6.2.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of NOX emissions: 1. SCR: 70-90% control efficiency 2. Good Burner Design and Combustion Practices: base case 5.6.2.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The proposed NOX BACT for the emergency engines is the use of Tier 4-certified engines, in accordance with the requirements of 40 CFR 60 Subpart IIII. There are no adverse environmental, energy, or economic impacts associated with this option. The Tier 4 Final emission standards represent up to an 88% reduction in NOX emissions over Tier 4 Interim emission standards. Given the low level of potential NOX emissions from these engines (between 0.003 tpy and 0.07 tpy per engine, depending on engine size), the use of add-on controls, such as SCRs, would not be cost effective given the small quantity of emissions reductions that would be achieved. This is consistent with EPA’s economic analysis during the development of the emissions standards in 40 CFR 60 Subpart IIII, in which EPA determined that add-on controls are economically infeasible for emergency CI ICE. NOI Application Ramboll 44 of 52 5.6.2.5 Step 5 – Select BACT Peak has selected the use of Tier 4-certified engines as BACT for NOX emissions from the stationary emergency engines. 5.6.3 VOC BACT Analysis for Stationary Emergency Engines 5.6.3.1 Step 1 – Identify Available Control Technologies Potentially available VOC control technologies include: • RTO; • RCO; • Catalytic Oxidation; • Wet Scrubber - Packed-Bed/Packed-Tower; • Bio-oxidation/Bio-filtration; and • Good Combustion Practices. Each of these control options was discussed in detail in Section 5.3.3.1 of this application. 5.6.3.2 Step 2 – Eliminate Technically Infeasible Options As discussed in Section 5.5.3.2 for the non-emergency engines, neither a wet scrubber system nor bio-oxidation/bio-filtration are technically feasible control options. The low concentration of VOC in the engines’ exhaust streams would be below the acceptable range for a VOC condensation control technology (i.e., wet scrubbers) to be effective, and the exhaust temperatures will exceed the maximum temperature for a bio-oxidation/bio-filtration system. Thermal or catalytic oxidation would not provide consistent VOC control efficiencies for emergency engines. These control options take time for the exhaust stream to reach required operating temperature for efficient oxidation, which would not be feasible for emergency generator operations due to the short periods of operation and frequent start- up/shutdown. As such, although the use of these control options would be technically feasible, the control efficiency would be lower than for a unit that runs normally at steady - state. Good combustion practices are considered technically feasible for the engines. 5.6.3.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of VOC emissions: 1. RTO/RCO: 90-99% control efficiency 2. Catalytic Oxidation: 95% control efficiency 3. Good Combustion Practices: base case 5.6.3.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The proposed VOC BACT for the emergency engines is the use of Tier 4-certified engines, in accordance with the requirements of 40 CFR 60 Subpart IIII. There are no adverse environmental, energy, or economic impacts associated with this option. EPA determined when promulgating NSPS Subpart IIII that the Tier 4 emission standards for NMHC represent a sufficiently low level of emissions without the need for additional add-on controls, even for non-emergency engines. Given the low level of potential VOC emissions from these emergency engines (between 0.002 tpy and 0.02 tpy per engine, depending on engine size), the use of add-on controls would not be cost effective given the small quantity of emissions reductions that would be achieved, particularly when accounting for the reduction in control efficiency that would occur from non-steady state operation of the NOI Application Ramboll 45 of 52 engines. This determination is consistent with EPA’s economic analysis during the development of the emissions standards in 40 CFR 60 Subpart IIII, in which EPA determined that add-on controls are economically infeasible for emergency CI ICE. 5.6.3.5 Step 5 – Select BACT Peak has selected the use of Tier 4-certified engines as BACT for VOC emissions from the stationary emergency engines. 5.6.4 CO BACT Analysis for Stationary Emergency Engines 5.6.4.1 Step 1 – Identify Available Control Technologies Potentially available CO control technologies include: • RTO/RCO; • Catalytic Oxidation; and • Good Combustion Practices. Each of these control options was discussed in detail in Sections 5.3.3.1 and 5.3.4.1 of this application. 5.6.4.2 Step 2 – Eliminate Technically Infeasible Options As discussed in Section 5.6.3.2, thermal or catalytic oxidation would not provide consistent CO control efficiencies for emergency engines. These control options take time for the exhaust stream to reach required operating temperature for efficient oxidation, which would not be feasible for emergency generator operations due to the short periods of operation and frequent starts/stops. As such, although the use of these control options would be technically feasible, the control efficiency would be lower than for a unit that runs normally at steady - state. Good combustion practices are considered technically feasible for the engines. 5.6.4.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of CO emissions: 1. RTO/RCO/Catalytic Oxidation: Approximately 98% control efficiency 2. Good Combustion Practices: base case 5.6.4.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The proposed CO BACT for the emergency engines is the use of Tier 4-certified engines, in accordance with the requirements of 40 CFR 60 Subpart IIII. There are no adverse environmental, energy, or economic impacts associated with this option. EPA determined when promulgating NSPS Subpart IIII that the Tier 4 emission standards for CO represent a sufficiently low level of emissions without the need for additional add -on controls, even for non-emergency engines. Given the low level of potential CO emissions from these emergency engines (between 0.04 tpy and 0.4 tpy per engine, depending on engine size), the use of add-on controls would not be cost effective given the small quantity of emissions reductions that would be achieved, particularly when accounting for the reduction in control efficiency that would occur from non-steady state operation of the engines. This determination is consistent with EPA’s economic analysis during the development of the emissions standards in 40 CFR 60 Subpart IIII, in which EPA determined that add-on controls are economically infeasible for emergency CI ICE. NOI Application Ramboll 46 of 52 5.6.4.5 Step 5 – Select BACT Peak has selected the use of Tier 4-certified engines as BACT for CO emissions from the stationary emergency engines. 5.6.5 SO2 BACT Analysis for Stationary Emergency Engines 5.6.5.1 Step 1 – Identify Available Control Technologies Potentially available SO2 control technologies include: • Scrubber; and • Use of a Low Sulfur Content Fuel. These control options were discussed in detail in Section 5.3.5.1 of this application. 5.6.5.2 Step 2 – Eliminate Technically Infeasible Options A scrubber for add-on SO2 control requires fairly constant exhaust gas temperatures and may pose technical challenges for controlling sources that operate for short periods of time with frequent startups and shutdowns. However, for the purposes of this evaluation, Peak has conservatively considered all of the SO2 control devices identified in Step 1 to be technically feasible for the engines. 5.6.5.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of SO2 emissions: 1. Scrubber: 50-98% control efficiency 2. Use of a Low Sulfur Content Fuel: base case 5.6.5.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The proposed SO2 BACT for the emergency engines is the exclusive use of ultra-low sulfur diesel fuel, in accordance with the requirements of 40 CFR 60 Subpart IIII. There are no adverse environmental, energy, or economic impacts associated with this option. Ultra-low sulfur diesel fuel has a maximum sulfur content of 15 ppm (0.0015%), resulting in very small levels of SO2 potential emissions from the engines (between 0.00004 tpy and 0.0005 tpy per engine, depending on engine size). Given these low emissions levels, the use of add-on controls would not be cost effective in comparison to the small quantity of emissions reductions that would be achieved. This is consistent with EPA’s economic analysis during the development of the emissions standards in 40 CFR 60 Subpart IIII, in which EPA determined that add-on controls are economically infeasible for emergency CI ICE. 5.6.5.5 Step 5 – Select BACT Peak has selected the exclusive use of ultra-low sulfur diesel fuel as BACT for SO2 emissions from the stationary emergency engines. 5.7 BACT Analysis for Baghouse-Controlled Material Handling and Equipment The Site’s processing facility will involve several material handling and processing sources, including conveyors and transfer equipment, storage silos and bins, product screens, and crushers. The material handling and processing equipment will be sources of PM10 and PM2.5 emissions. Peak has determined that BACT for these emissions from most of the material handling and processing equipment is collection and control by baghouses. BACT for certain material handling equipment with low levels of PM emissions is e nclosure. In addition to baghouse controls, several material handling and processing sources for the processing facility will be located indoors, which further serves to prevent the formation and release of fugitive dust emissions. NOI Application Ramboll 47 of 52 The following sections evaluate BACT for the material handling and processing equipment with emissions collected at pickup points and controlled by baghouses. BACT for enclosed, non-collected material handling and processing points at the processing facility is evaluated in Section 5.8. 5.7.1 PM10 and PM2.5 BACT Analysis for Baghouse-Controlled Material Handling and Processing Equipment 5.7.1.1 Step 1 – Identify Available Control Technologies Potentially available PM control technologies include: • Cyclone; • Baghouse; • Mechanically-Aided Wet Scrubber; • Venturi Wet Scrubber; • ESP; • Enclosures; and • Watering. Each of these control options, with the exception of enclosures and watering, was discussed in detail in Section 5.3.1.1 of this application. Enclosures Use of a full or partial enclosure surrounding material handling equipment can effectively serve to minimize the quantity of fugitive PM exiting the process. A PM control efficiency of 90% from a full/building enclosure and 70% from a partial enclosure has been used in this evaluation consistent with TCEQ guidance.104,105 Watering Application of water to a source suppresses fugitive dust and prevents the particles from becoming airborne. Per UDAQ guidance, a PM control efficiency of 70% is estimated for watering.106 5.7.1.2 Step 2 – Eliminate Technically Infeasible Options All of the PM10 and PM2.5 control devices identified in Step 1 are considered technically feasible for the collected material handling and processing equipment. However, use of water sprays is unnecessary and would result in notable increases in emissions of criteria pollutants from the dryers due to combustion of additional fuel to remove the moisture that would be added. Use of water spray at the processing facility is not a practical option given that the final product needs to be dried to specification. Therefore, use of water spray or wet suppressants is not considered further. 5.7.1.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of PM10 and PM2.5 emissions: 1. Baghouse/ESP: 99-99.9% control efficiency 2. Mechanically-Aided and Venturi Wet Scrubber: 70-99% control efficiency 3. Cyclone: 30-90% control efficiency for PM10; 0-40% control efficiency for PM2.5 4. Full/Building Enclosures: 90% control efficiency 104 https://www.tceq.texas.gov/assets/public/permitting/air/Guidance/NewSourceReview/emiss-calc-rock1.xlsx 105 https://www.tceq.texas.gov/permitting/air/guidance/newsourcereview/iron/nsr_fac_ironsteel.html 106 Olsen, R. to Permitting Branch (January 12, 2015). Emission Factors for Paved and Unpaved Roads [Guidelines]. Salt Lake City, UT: Utah Department of Environmental Quality, Division of Air Quality. NOI Application Ramboll 48 of 52 5. Partial Enclosures: 70% control efficiency 5.7.1.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs Peak has determined that use of a baghouse for each collected material han dling and processing source is BACT for PM10 and PM2.5. The baghouse represents the top-ranked control technology from Step 3. The remaining control technologies were not further evaluated in this step since they would provide lower control efficiencies th an the selected BACT (baghouse). 5.7.1.5 Step 5 – Select BACT Peak has selected baghouse control as BACT for PM10 and PM2.5 emissions from the collected material handling and processing equipment. Baghouses offer the highest level of PM control and are widely accepted as BACT for similar source types. Peak proposes an emission limit of 7% opacity for these sources. A 7% opacity limit is consistent with limits for similar operations under NSPS Subpart OOO and is as stringent as requirements for similar equipment operating in nonattainment areas. Condensable PM emissions are not expected from dry material handling operations at ambient temperatures.107 5.8 BACT Analysis for Enclosed Material Handling and Processing Equipment As previously discussed, the Site’s processing facility will involve certain material handling and processing sources with low levels of PM emissions for which BACT for PM10 and PM2.5 is an enclosure to minimize the formation and release of fugitive PM emissions. The types of enclosures proposed may include locating the conveyor inside a building, use of a covered conveyor, or other similar method to prevent fugitive emissions. The following sections evaluate BACT for these enclosed, non-collected material handling sources. 5.8.1 PM10 and PM2.5 BACT Analysis for Enclosed Material Handling and Processing Equipment 5.8.1.1 Step 1 – Identify Available Control Technologies Potentially available PM control technologies include: • Cyclone; • Baghouse; • Mechanically-Aided Wet Scrubber; • Venturi Wet Scrubber; • ESP; • Enclosures; and • Watering. Each of these control options was discussed in detail in Sections 5.3.1.1 and 5.7.1.1 of this application. 5.8.1.2 Step 2 – Eliminate Technically Infeasible Options All of the PM10 and PM2.5 control devices identified in Step 1 are considered technically feasible for the non-collected material handling and processing equipment. 107 Per the EPA Method 202 Best Practices Handbook, Section 4.6 (January 2016): “At ambient sources, […] Method 202 is not needed to measure total primary PM because all PM is filterable at these temperatures.” https://www3.epa.gov/ttnemc01/methods/m202-best-practices-handbook.pdf NOI Application Ramboll 49 of 52 5.8.1.3 Step 3 – Rank Remaining Control Technologies The remaining control options were ranked in order of greatest to least control of PM10 and PM2.5 emissions: 1. Baghouse/ESP: 99-99.9% control efficiency 2. Mechanically-Aided and Venturi Wet Scrubber: 70-99% control efficiency 3. Cyclone: 30-90% control efficiency for PM10; 0-40% control efficiency for PM2.5 4. Full/Building Enclosures: 90% control efficiency 5. Partial Enclosures/Watering: 70% control efficiency 5.8.1.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The following sections evaluate the energy, environmental, and economic impacts from the control options in Step 3. Fabric Filter The costs of using the highest ranked control technology, a baghouse, would exceed the benefit of the PM10 and PM2.5 reduction it would offer. In evaluating fabric filter costs for the two highest PM10-emitting enclosed material handling sources at the processing facility, the current cost of controlling PM10 with a fabric filter is estimated to be approximately $1.8M per ton of pollutant removed. As such, the use of baghouses is not selected as BACT. Wet Scrubber Similarly, the costs of using the next highest ranked control technology, a scrubber, is estimated to be approximately $2.7M per ton of PM10 removed per source, based on the two highest-emitting enclosed sources at the processing facility. Therefore, the cost of a scrubber exceeds the benefit of the PM10 and PM2.5 reduction it would offer. The use of a scrubber would also have associated energy impacts related to system pumps and environmental impacts associated with wastewater treatment and disposal. For these reasons, the use of a scrubber is not selected as BACT. Cyclone The next ranked control technology is a cyclone. Peak estimated the average cost effectiveness of a cyclone, calculated as the total annualized costs of control divided by the total annual reduction from uncontrolled emissions, using a very conservative PM10 control efficiency of 90%.108 The control efficiency would likely be much lower given the low concentration of PM10 in the inlet stream. Using this conservative control efficiency, the average cost effectiveness for a cyclone was estimated to range from approximately $7,054 per ton of PM10 removed per source, based on the two highest-emitting enclosed sources at the processing facility. Based on these average cost effectiveness values alone, the costs of a cyclone would exceed the benefits of emissions reductions for the enclosed material handling sources with lower levels of PM10 emissions but could potentially be cost effective for the higher PM10-emitting enclosed material handling sources. Peak also analyzed the incremental cost effectiveness from the next lowest ranked control technology, use of an enclosure, to a cyclone. The incremental cost effectiveness is calculated as the difference between the annualized cost for a cyclone to an enclosure divided by the difference in the annual emissions from an enclosure to a cyclone.109 An enclosure, such as use of a covered conveyor, is very inexpensive to install and operate 108 https://www.tceq.texas.gov/permitting/air/guidance/newsourcereview/iron/nsr_fac_ironsteel.html. See Section IV.D.2.b. of EPA’s New Source Review Workshop Manual: Prevention of Significant Deterioration and Nonattainment Area Permitting (draft, October 1990). 109 Ibid. NOI Application Ramboll 50 of 52 while still achieving at least 70% control efficiency for PM10. Peak estimated an incremental PM10 cost effectiveness from an enclosure to a cyclone be approximately $30,352 for the two enclosed material handling sources evaluated. As such, the use of a cyclone is not selected as BACT, as it represents a significant increase in annual costs over the use of an enclosure without a commensurate benefit in PM10 and PM2.5 emissions reductions. Enclosure Since designing the conveyors with an enclosure is not an add-on control technique, no adverse environmental, energy, or economic impacts are associated with this option. Table 8. Summary of Potential PM10 and PM2.5 Control Technology Costs for Enclosed Material Handling and Processing Sources Control Technology Average Cost Effectiveness ($/ton pollutant removed) Baghouse $1.8M Wet Scrubber $2.7M Cyclone $7,197 Table 9. Summary of Cyclone Incremental Cost Effectiveness Values for Enclosed Material Handling and Processing Sources Control Technology Incremental Cost Effectiveness ($/ton pollutant removed) Cyclone $30,352 5.8.1.5 Step 5 – Select BACT Collecting and directing emissions from the enclosed material handling sources at the processing facility to a control device would result in an average cost-effectiveness of between $7,054 per ton of PM10 removed and $2.7M per ton of PM10 removed. The incremental PM10 cost effectiveness from an enclosure to a cyclone could be greater than $30,352. As such, the cyclone is not selected as BACT, as it represents a significant increase in annual costs over the use of an enclosure without a commensurate benefit in PM10 and PM2.5 emissions reductions. Peak has selected the use of enclosures as BACT for PM10 and PM2.5 emissions from the non- collected material handling and processing equipment. Peak proposes an opacity limit of 20% for these sources, which is consistent with proposed BACT emission limits in the serious nonattainment SIP and visible emissions requirements for nonattainment areas. 5.9 BACT Analysis for Fugitive Dust Sources Fugitive dust sources at the Site will include unpaved roads; use of off-road equipment for loading, grading, excavating, and digging; and windblown dust from disturbed operational areas. The fugitive dust sources will result in emissions of PM10 and PM2.5. Peak has submitted a Fugitive Dust Control Plan for the Site to UDAQ and the BLM under separate cover. The following sections assess BACT for these fugitive dust sources. NOI Application Ramboll 51 of 52 5.9.1 PM10 and PM2.5 BACT Analysis for Fugitive Dust Sources 5.9.1.1 Step 1 – Identify Available Control Technologies UDAQ’s Guidelines on Emission Factors for Paved and Unpaved Haul Roads110 identify the following PM reduction and control options for fugitive sources: • Watering; • Application of a Chemical Suppressant; • Sweeping/Vacuum Sweeping; and • Paving Roads. 5.9.1.2 Step 2 – Eliminate Technically Infeasible Options As UDAQ notes in the proposed BACT for haul roads in the State Implementation Plan (SIP) for PM2.5 serious nonattainment areas, “specific scenarios can affect the feasibility of a control option based on the conditions on site.”111 Peak will be constructing unpaved haul roads on the Playa pursuant to requirements established by BLM. Specifically, BLM requires any permanent structures be removed at the completion of the project schedule for the Site. As such, Peak does not believe paving the haul roads would be a technically feasible control option. However, for the purposes of the NOI application, Peak has conservatively further evaluated paving within this BACT assessment as though it were technically feasible. The remaining PM10 and PM2.5 control technologies identified in Step 1 are considered technically feasible for fugitive dust emissions from on-site haul roads. Watering and chemical suppressant application are technically feasible control options for the remaining fugitive dust sources, such as berms, piles, and disturbed land. 5.9.1.3 Step 3 – Rank Remaining Control Technologies The control options were ranked in order of greatest to least control of PM10 and PM2.5 emissions based on the control efficiencies from UDAQ’s Guidelines on Emission Factors for Paved and Unpaved Haul Roads:112 1. Paved Roads with Vacuum Sweeping and Watering: 95% control efficiency 2. Paved Roads with Sweeping and Watering: 90% control efficiency 3. Chemical Suppressant and Watering: 85% control efficiency 4. Basic Watering: 70% control efficiency 5.9.1.4 Step 4 – Evaluate Energy, Environmental, and Economic Impacts and Other Costs The Site will involve approximately 21 miles of unpaved haul roads. The cost of paving these roads would exceed the benefits in PM10 and PM2.5 reductions. The average cost effectiveness from the capital costs of paving alone is estimated at approximately $3,700 per ton of pollutant removed, and the incremental cost effectiveness for paving over the next highest ranked control strategy, chemical suppressant and watering, is estimated at approximately $35,360 per ton of pollutant removed. Note that these provided costs are for paving alone and do not consider the annual costs associated with maintaining the pavement or with sweeping the roads. These costs also conservatively do not include the costs associated with removing the haul roads at the end of the Site’s operational life. Pursuant to requirements 110 Olsen, R. to Permitting Branch (January 12, 2015). Emission Factors for Paved and Unpaved Roads [Guidelines]. Salt Lake City, UT: Utah Department of Environmental Quality, Division of Air Quality. 111 Appendix A – BACT for Various Emission Units at Stationary Sources, Chapter 12G – Haul Roads, Section 12G.4 – Technological Feasibility (DAQ-2018-007161). https://documents.deq.utah.gov/air-quality/pm25-serious- sip/DAQ-2018-007161.pdf 112 Olsen, R. to Permitting Branch (January 12, 2015). Emission Factors for Paved and Unpaved Roads [Guidelines]. Salt Lake City, UT: Utah Department of Environmental Quality, Division of Air Quality. NOI Application Ramboll 52 of 52 established by BLM, Peak would be required to remove any roads or permanent structures at the completion of operations at the Site. In addition to economic considerations, paving would also present adverse environmental impacts. Impervious surfaces, including paved roads, rely on storm drains to carry runoff to waterways. The storm water runoff may carry pollutants such as oil and dirt from the roads, which can harm water quality.113 Paving would also result in additional fuel consumption due to the additional vehicles needed to transport the asphalt materials to the site during construction and to demolish and remove the asphalt at the end of the project life. As such, due to the economic and environmental impacts, paving of the on-site haul roads is not selected as BACT. Peak’s Fugitive Dust Control Plan for the Sevier Playa Potash project, submitted to UDAQ and BLM, outlines specific control measures for fugitive dust sources, including application of chemical suppressant and watering for the unpaved roads and disturbed land areas, restricting haul truck traffic to specified areas, limiting the allowable speed for trucks on the haul roads, and implementing special control measures during high-wind events. Table 10. Summary of Potential PM10 and PM2.5 Control Technology Costs for Fugitive Dust Sources Control Technology Average Cost Effectiveness ($/ton pollutant removed) Incremental Cost Effectiveness ($/ton pollutant removed) Paving $3,700 $35,260 5.9.1.5 Step 5 – Select BACT Paving roads is not technically feasible due to site-specific constraints. Moreover, the environmental and economic impacts are very high due to the location and nature of the Site. Peak has therefore selected compliance with its Fugitive Dust Control Plan, including water and use of chemical suppressants, as BACT for PM10 and PM2.5 emissions from the fugitive dust sources. Peak also is required to comply with opacity limits as set forth in R307- 205. 113 EPA, “Protecting Water Quality from Urban Runoff” (EPA 841-F-03-003). https://www3.epa.gov/npdes/pubs/nps_urban-facts_final.pdf APPENDIX A FACILITY MAPS AND DIAGRAMS SEVIER MILLARD SALT LAKE WAYNE JUAB UTAH EMERY TOOELE MORGAN SUMMIT WASATCH CARBON DAVIS BEAVER SANPETE PIUTEService Layer Credits: Newspaper: Esri, HERE, Garmin, FAO, NOAA, USGS, Bureau of Land Management, EPA, NPS Newspaper: Esri, HERE, Garmin, FAO, NOAA, USGS, EPA 0 5025Kilometers RAMBOLL US CONSULTING, INC. A RAMBOLL COMPANY FIGURE A1 State Boundaries County Boundaries Major Roads Ambient Air Boundary AMBIENT AIR BOUNDARY AND SURROUNDING AREAS PEAK MINERALS SEVIER PLAYA POTASH PROJECT !á(N Utah Wyoming Nevada Colorado Idaho Arizona Millard County, Utah Feasibility Study for the Sevier Playa Potash Project, Millard County, Utah Prepared for Peak Minerals Inc. September 23, 2022 Page 6 Novopro Projects Inc. Figure 1-2: Project Features Map Source: Novopro APPENDIX B UDAQ AIR PERMIT APPLICATION FORMS Table of Contents Form 1 Notice of Intent (NOI) Application Checklist Form 2 Company Information/Notice of Intent (NOI) Form 3 Process Information Form 10 Fabric Filters (Baghouses) Form 11 Internal Combustion Engines Form 15 Aggregate Processing Operations Form 17 Diesel Powered Standby Generator Form 19 Natural Gas Boilers and Liquid Heaters Form 1 Date: Notice of Intent (NOI) Application Checklist Company: Utah Division of Air Quality New Source Review Section Source Identification Information [R307‐401‐5] 1 2 3 4 5 6 7 8 9 NOI Application Information [R307‐401] 1 2 3 4 N/A 5 6 A 7 A B C 8 A 9 A N/A B N/A 10 A N/A B N/A Signature on Application Detailed description of the project and source process. 7/31/2023 Peak Minerals Inc. Company name, mailing address, physical address, and telephone number. Company contact (name, mailing address, telephone number). Name and contact of person submitting NOI application (if different than 2). Source Universal Transverse Mercator (UTM) coordinates. Source Standard Industrial Classification (SIC) Code. Area designation (attainment, maintenance, or nonattainment). Federal/State requirement applicability (NAAQS, NSPS, MACT, SIP, etc.) Source size determination (Major, Minor, PSD). Current Approval Order(s) and/or Title V Permit Numbers. Composition and physical characteristics of effluent (Emission rates, temperature, volume, pollutant types, and concentration). Discussion of fuels, raw materials, and products consumed/produced. Description of equipment used in the process and operating schedule. Description of changes in the process, production rates, etc. Site plan of source with building dimensions, stack parameters, etc. Best Available Control Technology (BACT) Analysis [R307‐401‐8] BACT analysis for all new and modified equipment. Emissions Related Information [R307‐401‐2(b)] Emission calculations for each new/modified units and site‐wide (Include PM10, PM2.5, NOX, SO2, CO, VOCs, HAPs, and GHG). References/assumptions, SDS, for each calculation and pollutant. All speciated HAP emissions (list in lbs/hr). Emissions Impact Analysis ‐ Approved Modeling Protocol [R307‐410] Note: The Division for Air Quality will not accept documents containing confidential information or data. Documents containing confidential information will be returned to the Source submitting the application. Nonattainment/Maintenance Areas ‐ Major NSR/Minor (Offsetting Only) [R307‐403] NAAQS Demonstration, Lowest Achievable Emission Rate, Offset Requirements. Alternate site analysis, Major source ownership compliance certification. Major Sources in Attainment or Unclassified Area (PSD) [R307‐405, R307‐406] Air quality analysis (air model, met data, background data, source impact analysis). Visibility impact analysis, Class I area impact. Page 1 of 1 Form 3 Company____________________ Process Information Site________________________ Utah Division of Air Quality New Source Review Section Process Information - For New Permit ONLY 1.Name of process:2.End product of this process: 3.Process Description*: Operating Data 4.Maximum operating schedule: __________ hrs/day __________days/week __________weeks/year 5.Percent annual production by quarter: Winter ________ Spring _______ Summer ________ Fall _______ 6.Maximum Hourly production (indicate units.): _____________ 7.Maximum annual production (indicate units): ________________ 8.Type of operation: Continuous Batch Intermittent 9.If batch, indicate minutes per cycle ________ Minutes between cycles ________ 10. Materials and quantities used in process.* Material Maximum Annual Quantity (indicate units) 11.Process-Emitting Units with pollution control equipment* Emitting Unit(s) Capacity(s) Manufacture Date(s) *If additional space is required, please create a spreadsheet or Word processing document and attach to form. (tpy) 7880 hours/year (tons) Peak Minerals Inc. Sevier Playa Potas Project Sevier Playa Potash Project SOP (Sulfate of Potash) & Magnesium Chloride The Project would be designed for approximately 215,000 tpy average annual production of Sulfate of Potash (SOP) and 300,000 tpy of Magnesium Chloride from salts present in the brines of the Sevier Playa. Brines extracted from Sevier Playa sediments would be concentrated by solar evaporation. The potassium-rich potash salts precipitated in the production ponds would be harvested and processed in a modern crystallization plant to produce a saleable SOP product, as well as other associated minerals. The Project would feature recharge and extraction canals at the surface of the mineral extraction area as a method of recovery of the potassium-rich salts. Evaporation ponds would be used for recovery of the crude salts. The salts would be harvested using mobile equipment and hauled to the Processing Facility where muriate of potash would be added for beneficiation, producing SOP 24 7 25% 25% 25% 25% 515,000 4 Potassium-bearing materials 2,000,000.00 See Table B-1 below Docuitiunl Dale;: 02/28,;2018 DAQ 2018 II 002273 Type Equipment Capacity Units Manufacture Date Generator Set 1 53 hp 2023 (est.) Generator Set 2 53 hp 2023 (est.) Generator Set 3 53 hp 2023 (est.) Generator Set 4 139 hp 2023 (est.) Generator Set 5 59 hp 2023 (est.) Generator Set 6 59 hp 2023 (est.) Generator Set 7 111 hp 2023 (est.) Generator Set 8 78 hp 2023 (est.) Pond Mobile Pumps (3) 20 hp 2023 (est.) Mixed Salts Screen 307 tons/hr 2023 (est.) Product Screen 107 tons/hr 2023 (est.) Compaction Screen 118 tons/hr 2023 (est.) Granular Product Glazing Screen 39 tons/hr 2023 (est.) Dryer Oversize Roll Crusher 20.4 tons/hr 2023 (est.) Compaction Flake Breaker 95 tons/hr 2023 (est.) Compaction Double Roll Crusher 25 tons/hr 2023 (est.) Compaction Baghouse 35,000 acfm 2023 (est.) Main Dryer Baghouse 14,125 acfm 2023 (est.) Glazing Dryer/Cooler Baghouse 6,769 acfm 2023 (est.) Loadout Silo Bin Vent 1,500 acfm 2023 (est.) MOP Silo Bin Vent 1,900 acfm 2023 (est.) Bagging Plant Buffer Silo Bin Vent 1,500 acfm 2023 (est.) Quick Lime Silo Bin Vent 1,900 acfm 2023 (est.) 50 Lb Bischofite Silo Bin Vent 1,900 acfm 2023 (est.) 1 Ton Bischofite Silo Vent 1,900 acfm 2023 (est.) Fire Pump 100 hp 2023 (est.) Emergency Generators 1,342 hp 2023 (est.) Drying and sizing fluid bed dryer 4.4 MMBtu/hr 2023 (est.) Glazing fluid bed dryer 2 MMBtu/hr 2023 (est.) Boilers MgCl2 Steam Boiler 15 MMBtu/hr 2023 (est.) Screens Crushers Baghouse Emergency Generators Dryers Delta, Utah Peak Minerals Inc. Process-Emitting Units Table B-1 Internal Combustion Engine Compaction Baghouse Belt Conveyor 0.72 tons/hr 2023 (est.) Main Dryer Baghouse Screw Conveyor 3.60 tons/hr 2023 (est.) Dry Product Drag Conveyor 107 tons/hr 2023 (est.) Screen Feed Bucket Elevator 107 tons/hr 2023 (est.) SOP Centrifuge Screw Conveyor 33 tons/hr 2023 (est.) Off-Spec Conveyor 33 tons/hr 2023 (est.) Soluble/Granular Product Diverter 51 tons/hr 2023 (est.) Soluble/Granular Product Diverter 32 tons/hr 2023 (est.) Oversize Product Magnetic Chute 20 tons/hr 2023 (est.) Undersize Belt Conveyor 95 tons/hr 2023 (est.) Belt Conveyor Bucket Elevator Feed 98 tons/hr 2023 (est.) Compaction Feed Bucket Elevator 98 tons/hr 2023 (est.) Compaction Feed Drag Conveyor 98 tons/hr 2023 (est.) Compactor 95 tons/hr 2023 (est.) Curing Drag Conveyor 95 tons/hr 2023 (est.) Curing Drag Conveyor 95 tons/hr 2023 (est.) Bucket Elevator Feed Belt Conveyor 118 tons/hr 2023 (est.) Screen Feed Bucket Elevator 118 tons/hr 2023 (est.) Granular Product Belt Conveyor 34 tons/hr 2023 (est.) Compactor Magnet 93 tons/hr 2023 (est.) Roll Crusher Belt Conveyor 118 tons/hr 2023 (est.) Compaction Surge Bin 180 tons/hr 2023 (est.) Glazing Drum 34 tons/hr 2023 (est.) Glazing Feed Belt Conveyor 38 tons/hr 2023 (est.) Glazing Baghouse Screw Conveyor 3.60 tons/hr 2023 (est.) Glazing Fluid Bed Dryer/Cooler 38 tons/hr 2023 (est.) Glazed Product Drag Conveyor 39 tons/hr 2023 (est.) Glazed Product Bucket Elevator 39 tons/hr 2023 (est.) Glazed Screen Oversize Belt Conveyor 1.40 tons/hr 2023 (est.) Loadout Feed Belt Conveyor 31 tons/hr 2023 (est.) Loadout Silo 519 tons/hr 2023 (est.) Loadout Silo Dust Filter Cyclone 31 tons/hr 2023 (est.) Loadout Silo Dust Filter Cyclone 31 tons/hr 2023 (est.) Tailings Belt Conveyor 11 tons/hr 2023 (est.) Crushing Feed Hopper 45 tons/hr 2023 (est.) Hammer Mill Chute 155 tons/hr 2023 (est.) Crushing Conveyor 155 tons/hr 2023 (est.) Crushing Magnet 155 tons/hr 2023 (est.) MOP Feed Hopper 165 tons/hr 2023 (est.) MOP Feed Conveyor 165 tons/hr 2023 (est.) MOP Silo Belt Conveyor 13 tons/hr 2023 (est.) MOP Bucket Elevator 165 tons/hr 2023 (est.) MOP Drag Conveyor 13 tons/hr 2023 (est.) MOP Silo 165 tons/hr 2023 (est.) MOP Addition Baghouse Screw Conveyor 1.00 tons/hr 2023 (est.) Off Spec Product Drag Conveyor 5.80 tons/hr 2023 (est.) Off Spec Product Hopper 5.30 tons/hr 2023 (est.) Water Soluble SOP Belt Conveyor 32 tons/hr 2023 (est.) Water Soluble SOP Bucket Elevator 32 tons/hr 2023 (est.) Bagging Silo Feed Conveyor 32 tons/hr 2023 (est.) Bagging Plant Transfer Conveyor 33 tons/hr 2023 (est.) Bagging Plant Buffer Silo 120 tons/hr 2023 (est.) Bagging Plant Accumulating Conveyor 33 tons/hr 2023 (est.) Compaction Baghouse Screw Conveyor 0.72 tons/hr 2023 (est.) Schoenite Cake Screw Conveyor 102 tons/hr 2023 (est.) Schoenite Cake Screw Conveyor 102 tons/hr 2023 (est.) Lime Loading Screw Mass Flow Conveyor 1.04 tons/hr 2023 (est.) Bischofite Belt Conveyor 14 tons/hr 2023 (est.) Silo Feed Screw Conveyor 14 tons/hr 2023 (est.) Quick Lime Silo 72 tons/hr 2023 (est.) 50 Lb Bischofite Silo 6.00 tons/hr 2023 (est.) 1 Ton Bischofite Silo 6.00 tons/hr 2023 (est.) Bischofite Flaker 6.92 tons/hr 2023 (est.) Bischofite Flaker 6.92 tons/hr 2023 (est.) Material Handling Form 5 Company: Emissions Information Source: Criteria / GHGs Utah Division of Air Quality New Source Review Section CO2eCO2eCO2e ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ ‐‐ ‐‐10,689 *Potential to Emit to include pollution control equipment as defined by R307‐401‐2. Form 5 Company: Emissions Information Source: HAP's Utah Division of Air Quality New Source Review Section **Defined in Section 112(b) of the Clean Air Act. ***Use additional sheets for pollutants if needed. PM10 (Total)‐‐ ‐‐112 PM10 (Fugitive)‐‐ ‐‐95 Peak Minerals Inc. Facility‐Wide Potential to Emit* ‐ Criteria Pollutants & GHGs Criteria Pollutants Permitted Emissions (tons / year) Emissions Increases (tons/year) Proposed Emissions (tons/year) SO2 ‐‐ ‐‐ ‐‐ CO ‐‐ ‐‐15 PM2.5 (Total)‐‐ ‐‐33 NOX ‐‐ ‐‐12 NH3 ‐‐ ‐‐ ‐‐ VOC ‐‐ ‐‐1.15 VOC (Fugitive)‐‐ ‐‐ ‐‐ CH4 ‐‐ ‐‐ ‐‐ N2O ‐‐ ‐‐ ‐‐ Greenhouse Gases Mass Basis Mass Basis Mass Basis CO2 ‐‐ ‐‐ ‐‐ SF6 ‐‐ ‐‐ ‐‐ Total CO 2 e ‐‐ ‐‐10,689 HFCs ‐‐ ‐‐ ‐‐ PFCs ‐‐ ‐‐ ‐‐ Peak Minerals Inc. Facility‐Wide Hazardous Air Pollutants** Hazardous Air Pollutants*** Permitted Emissions (tons/year) Emissions Increases (tons/year) Proposed Emissions (tons/year) Emissions Increase (pounds/hour) Benzene ‐‐ ‐‐0.012 ‐‐ Toluene ‐‐ ‐‐5.34E‐03 ‐‐ Xylenes ‐‐ ‐‐3.72E‐03 ‐‐ 1,3‐Butadiene ‐‐ ‐‐5.11E‐04 ‐‐ Formaldehyde ‐‐ ‐‐1.54E‐02 ‐‐ Acetaldehyde ‐‐ ‐‐1.00E‐02 ‐‐ Acrolein ‐‐ ‐‐1.21E‐03 ‐‐ Total HAP ‐‐ ‐‐0.052 ‐‐ Utah Division of Air Quality New Source Review Section Company _______________________ Site/Source _____________________ Form 10 Date __________________________ Fabric Filters (Baghouses) Baghouse Description 1. Briefly describe the process controlled by this baghouse: Gas Stream Characteristics 2. Flow Rate (acfm):4. Particulate Loading (grain/scf) Design Max Average Expected 3. Water Vapor Content of Effluent Stream (lb. water/lb. dry air) Inlet Outlet 5. Pressure Drop (inches H2O) High __________ Low _________ 6. Gas Stream Temperature (°F):7. Fan Requirements (hp) (ft 3/min) Equipment Information and Filter Characteristics 8. Manufacturer and Model Number: 10. Bag Diameter (in.) 11. Bag Length (ft.)12. Number of Bags:13. Stack Height ___________ feet Stack Inside Diameter ___________ inches 9. Bag Material: □Nomex nylon □Polyester □Acrylics □Fiber glass □Cotton □Teflon □ ___________ 14. Filtering Efficiency Rating: _________% 15. Air to Cloth Ratio: ______: 1 16. Hours of Operation: Max Per day ________ Max Per year _______ 17. Cleaning Mechanism: □Reverse Air □ Shaker □Pulse Jet □ Other: ______________________ Emissions Calculations (PTE) 18. Calculated emissions for this device PM10 ___________Lbs/hr___________ Tons/yr PM2.5 ___________Lbs/hr___________ Tons/yr NOx ____________Lbs/hr___________ Tons/yr SOx ____________Lbs/hr___________ Tons/yr CO ____________Lbs/hr___________ Tons/yr VOC ___________Lbs/hr___________ Tons/yr HAPs___________Lbs/hr (speciate)____________Tons/yr (speciate) Submit calculations as an appendix. Page 1 of 2 1$ 1 Ton Bischofite Silo Vent (Bischofite Facility) - Controls PM emissions related to the 1 Ton Bischofite Silo at the Bischofite Facility. 9HQWVLQGRRUV N/$ Peak Minerals Inc. Sevier Playa Potash Project July 2023 1,900 1,900 TBD 0.005 TBD TBD Equal to ambient temperature TBD TBDx TBD TBD TBD TBD 24 7880 TBD 0.357 0.3571.95 1.95 Page 2 of 2 Instructions - Form 10 Fabric Filters (Baghouses) NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Describe the process equipment that the filter controls, what product is being controlled, particle size data (if available), i.e., cement silo, grain silo, nuisance dust in work place, process control with high dust potential, etc. 2. The maximum and design exhaust gas flow rates through the filter control device in actual cubic feet per minute (ACFM). Check literature or call the sales agent. 3. The water/moisture content of the gas stream going through the filter. 4. The amount of particulate in the gas stream going into the filter and the amount coming out if available. Outlet default value = 0.016 grains PM10/dscf. 5. The pressure drop range across the system. Usually given in the literature in inches of water. 6. The temperature of the gas stream entering the filter system in degrees Fahrenheit. 7. The horse power of the fan used to move the gas stream and/or the flow rate of the fan in ft3/min. 8. Name of the manufacturer of the filter equipment and the model number if available. 9. Check the type of filter bag material or fill in the blank. Check literature or call the sales agent. 10. The diameter of the bags in the system. Check literature or call the sales agent. 11. The length of the bags in the system. Check literature or call the sales agent. 12. The number of bags. Check literature or call the sales agent. 13. The height to the top of the stack from ground level and the stack inside diameter. 14. The filtering efficiency rating that the manufacturer quotes. Check literature or call the sales agent. 15. The ratio of the flow rate of air to the cloth area (A/C). 16. The number of hours that the process equipment is in operation, maximum per day and per year. 17. The way in which the filters bags are cleaned. Check the appropriate box. 18. Supply calculations for all criteria pollutants and HAPs. Use AP42 or Manufacturers data to complete your calculations. U:\aq\ENGINEER\GENERIC\Forms 2010\Form10 Baghouses.doc Revised 12/20/10 Utah Division of Air Quality New Source Review Section Company _______________________ Site/Source _____________________ Form 10 Date __________________________ Fabric Filters (Baghouses) Baghouse Description 1. Briefly describe the process controlled by this baghouse: Gas Stream Characteristics 2. Flow Rate (acfm):4. Particulate Loading (grain/scf) Design Max Average Expected 3. Water Vapor Content of Effluent Stream (lb. water/lb. dry air) Inlet Outlet 5. Pressure Drop (inches H2O) High __________ Low _________ 6. Gas Stream Temperature (°F):7. Fan Requirements (hp) (ft 3/min) Equipment Information and Filter Characteristics 8. Manufacturer and Model Number: 10. Bag Diameter (in.) 11. Bag Length (ft.)12. Number of Bags:13.Stack Height ___________ feet Stack Inside Diameter ___________ inches 9. Bag Material: □Nomex nylon □Polyester □Acrylics □Fiber glass □Cotton □Teflon □ ___________ 14. Filtering Efficiency Rating: _________% 15. Air to Cloth Ratio: ______: 1 16. Hours of Operation: Max Per day ________ Max Per year _______ 17. Cleaning Mechanism: □Reverse Air □ Shaker □Pulse Jet □ Other: ______________________ Emissions Calculations (PTE) 18. Calculated emissions for this device PM10 ___________Lbs/hr___________ Tons/yr PM2.5 ___________Lbs/hr___________ Tons/yr NOx ____________Lbs/hr___________ Tons/yr SOx ____________Lbs/hr___________ Tons/yr CO ____________Lbs/hr___________ Tons/yr VOC ___________Lbs/hr___________ Tons/yr HAPs___________Lbs/hr (speciate)____________Tons/yr (speciate) Submit calculations as an appendix. Page 1 of 2 1$ 1$ 50 Lb Bischofite Silo Bin Vent (Bischofite Facility) - Controls PM emissions related to the 50 Lb Bischofite Silo at the Bischofite Facility.9HQWV,QGRRUV Peak Minerals Inc. Sevier Playa Potash Project July 2023 1,900 1,900 TBD 0.005 TBD TBD TBD TBD TBD TBD TBDx TBD 24 7880 TBD Equal to ambient temperature 0.357 0.3571.95 1.95 Page 2 of 2 Instructions - Form 10 Fabric Filters (Baghouses) NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Describe the process equipment that the filter controls, what product is being controlled, particle size data (if available), i.e., cement silo, grain silo, nuisance dust in work place, process control with high dust potential, etc. 2. The maximum and design exhaust gas flow rates through the filter control device in actual cubic feet per minute (ACFM). Check literature or call the sales agent. 3. The water/moisture content of the gas stream going through the filter. 4. The amount of particulate in the gas stream going into the filter and the amount coming out if available. Outlet default value = 0.016 grains PM10/dscf. 5. The pressure drop range across the system. Usually given in the literature in inches of water. 6. The temperature of the gas stream entering the filter system in degrees Fahrenheit. 7. The horse power of the fan used to move the gas stream and/or the flow rate of the fan in ft3/min. 8. Name of the manufacturer of the filter equipment and the model number if available. 9. Check the type of filter bag material or fill in the blank. Check literature or call the sales agent. 10. The diameter of the bags in the system. Check literature or call the sales agent. 11. The length of the bags in the system. Check literature or call the sales agent. 12. The number of bags. Check literature or call the sales agent. 13. The height to the top of the stack from ground level and the stack inside diameter. 14. The filtering efficiency rating that the manufacturer quotes. Check literature or call the sales agent. 15. The ratio of the flow rate of air to the cloth area (A/C). 16. The number of hours that the process equipment is in operation, maximum per day and per year. 17. The way in which the filters bags are cleaned. Check the appropriate box. 18. Supply calculations for all criteria pollutants and HAPs. Use AP42 or Manufacturers data to complete your calculations. U:\aq\ENGINEER\GENERIC\Forms 2010\Form10 Baghouses.doc Revised 12/20/10 Utah Division of Air Quality New Source Review Section Company _______________________ Site/Source _____________________ Form 10 Date __________________________ Fabric Filters (Baghouses) Baghouse Description 1. Briefly describe the process controlled by this baghouse: Gas Stream Characteristics 2. Flow Rate (acfm):4. Particulate Loading (grain/scf) Design Max Average Expected 3. Water Vapor Content of Effluent Stream (lb. water/lb. dry air) Inlet Outlet 5. Pressure Drop (inches H2O) High __________ Low _________ 6. Gas Stream Temperature (°F):7.Fan Requirements (hp) (ft3/min) Equipment Information and Filter Characteristics 8. Manufacturer and Model Number: 10. Bag Diameter (in.) 11. Bag Length (ft.)12.Number of Bags:13. Stack Height ___________ feet Stack Inside Diameter ___________ inches 9. Bag Material: □Nomex nylon □Polyester □Acrylics □Fiber glass □Cotton □Teflon □ ___________ 14. Filtering Efficiency Rating: _________% 15. Air to Cloth Ratio: ______: 1 16. Hours of Operation: Max Per day ________ Max Per year _______ 17. Cleaning Mechanism: □Reverse Air □ Shaker □Pulse Jet □ Other: ______________________ Emissions Calculations (PTE) 18. Calculated emissions for this device PM10 ___________Lbs/hr___________ Tons/yr PM2.5 ___________Lbs/hr___________ Tons/yr NOx ____________Lbs/hr___________ Tons/yr SOx ____________Lbs/hr___________ Tons/yr CO ____________Lbs/hr___________ Tons/yr VOC ___________Lbs/hr___________ Tons/yr HAPs___________Lbs/hr (speciate)____________Tons/yr (speciate) Submit calculations as an appendix. Page 1 of 2 Peak Minerals Inc. Sevier Playa Potash Project July 2023 1,500 1,500 TBD TBD TBD 0.005 TBDEqual to ambient temperature TBDx TBD TBD TBD 53 TBD 24 7880 TBD 0.280.28 Bagging Plant Buffer Silo Bin Vent (Processing Facility) - Controls PM emissions related to bagging operations at the Processing Facility. 1.51.5 Page 2 of 2 Instructions - Form 10 Fabric Filters (Baghouses) NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Describe the process equipment that the filter controls, what product is being controlled, particle size data (if available), i.e., cement silo, grain silo, nuisance dust in work place, process control with high dust potential, etc. 2. The maximum and design exhaust gas flow rates through the filter control device in actual cubic feet per minute (ACFM). Check literature or call the sales agent. 3. The water/moisture content of the gas stream going through the filter. 4. The amount of particulate in the gas stream going into the filter and the amount coming out if available. Outlet default value = 0.016 grains PM10/dscf. 5. The pressure drop range across the system. Usually given in the literature in inches of water. 6. The temperature of the gas stream entering the filter system in degrees Fahrenheit. 7. The horse power of the fan used to move the gas stream and/or the flow rate of the fan in ft3/min. 8. Name of the manufacturer of the filter equipment and the model number if available. 9. Check the type of filter bag material or fill in the blank. Check literature or call the sales agent. 10. The diameter of the bags in the system. Check literature or call the sales agent. 11. The length of the bags in the system. Check literature or call the sales agent. 12. The number of bags. Check literature or call the sales agent. 13. The height to the top of the stack from ground level and the stack inside diameter. 14. The filtering efficiency rating that the manufacturer quotes. Check literature or call the sales agent. 15. The ratio of the flow rate of air to the cloth area (A/C). 16. The number of hours that the process equipment is in operation, maximum per day and per year. 17. The way in which the filters bags are cleaned. Check the appropriate box. 18. Supply calculations for all criteria pollutants and HAPs. Use AP42 or Manufacturers data to complete your calculations. U:\aq\ENGINEER\GENERIC\Forms 2010\Form10 Baghouses.doc Revised 12/20/10 Utah Division of Air Quality New Source Review Section Form 10 Company ______________________ Site/Source _____________________ Date __________________________ Fabric Filters (Baghouses) Baghouse Description 1. Briefly describe the process controlled by this baghouse: Gas Stream Characteristics 2. Flow Rate (acfm):4. Particulate Loading (grain/scf) Design Max Average Expected 3. Water Vapor Content of Effluent Stream (lb. water/lb. dry air) Inlet Outlet 5. Pressure Drop (inches H2O) High __________ Low _________ 6. Gas Stream Temperature (°F):7. Fan Requirements (hp) (ft 3/min) Equipment Information and Filter Characteristics 8. Manufacturer and Model Number: 10. Bag Diameter (in.) 11. Bag Length (ft.)12. Number of Bags:13. Stack Height _________ feet Stack Inside Diameter ___________ inches 9. Bag Material: □Nomex nylon □Polyester □Acrylics □Fiber glass □Cotton □Teflon □___________ 14. Filtering Efficiency Rating: _________% 15. Air to Cloth Ratio: ______: 1 16. Hours of Operation: Max Per day ________ Max Per year _______ 17. Cleaning Mechanism: □Reverse Air □ Shaker □Pulse Jet □ Other: ______________________ Emissions Calculations (PTE) 18. Calculated emissions for this device PM10 ___________Lbs/hr___________ Tons/yr PM2.5 ___________Lbs/hr___________ Tons/yr NOx ____________Lbs/hr___________ Tons/yr SOx ____________Lbs/hr___________ Tons/yr CO ____________Lbs/hr___________ Tons/yr VOC ___________Lbs/hr___________ Tons/yr HAPs___________Lbs/hr (speciate)____________Tons/yr (speciate) Submit calculations as an appendix. Page 1 of 2 July 2023 Peak Minerals Inc. Sevier Playa Potash Project Compaction Baghouse (Processing Facility) - Controls PM emissions from all compaction operations at theProcessing Facility including crushers, screens, and material handling 35,000 Unknown 0.005 TBD TBD Equal to ambient temperature TBD 35,000 TBDx TBD TBDTBD 24 TBD 6.6 6.6 TBD 83 24 3636 Page 2 of 2 Instructions - Form 10 Fabric Filters (Baghouses) NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Describe the process equipment that the filter controls, what product is being controlled, particle size data (if available), i.e., cement silo, grain silo, nuisance dust in work place, process control with high dust potential, etc. 2. The maximum and design exhaust gas flow rates through the filter control device in actual cubic feet per minute (ACFM). Check literature or call the sales agent. 3. The water/moisture content of the gas stream going through the filter. 4. The amount of particulate in the gas stream going into the filter and the amount coming out if available. Outlet default value = 0.016 grains PM10/dscf. 5. The pressure drop range across the system. Usually given in the literature in inches of water. 6. The temperature of the gas stream entering the filter system in degrees Fahrenheit. 7. The horse power of the fan used to move the gas stream and/or the flow rate of the fan in ft3/min. 8. Name of the manufacturer of the filter equipment and the model number if available. 9. Check the type of filter bag material or fill in the blank. Check literature or call the sales agent. 10. The diameter of the bags in the system. Check literature or call the sales agent. 11. The length of the bags in the system. Check literature or call the sales agent. 12. The number of bags. Check literature or call the sales agent. 13. The height to the top of the stack from ground level and the stack inside diameter. 14. The filtering efficiency rating that the manufacturer quotes. Check literature or call the sales agent. 15. The ratio of the flow rate of air to the cloth area (A/C). 16. The number of hours that the process equipment is in operation, maximum per day and per year. 17. The way in which the filters bags are cleaned. Check the appropriate box. 18. Supply calculations for all criteria pollutants and HAPs. Use AP42 or Manufacturers data to complete your calculations. U:\aq\ENGINEER\GENERIC\Forms 2010\Form10 Baghouses.doc Revised 12/20/10 Utah Division of Air Quality New Source Review Section Company _______________________ Site/Source _____________________ Form 10 Date __________________________ Fabric Filters (Baghouses) Baghouse Description 1. Briefly describe the process controlled by this baghouse: Gas Stream Characteristics 2. Flow Rate (acfm): 4. Particulate Loading (grain/scf) Design Max Average Expected 3. Water Vapor Content of Effluent Stream (lb. water/lb. dry air) Inlet Outlet 5. Pressure Drop (inches H2O) High __________ Low _________ 6. Gas Stream Temperature (°F): 7. Fan Requirements (hp) (ft3/min) Equipment Information and Filter Characteristics 8. Manufacturer and Model Number: 10. Bag Diameter (in.) 11. Bag Length (ft.) 12. Number of Bags: 13. Stack Height ___________ feet Stack Inside Diameter ___________ inches 9. Bag Material: □ Nomex nylon □ Polyester □ Acrylics □ Fiber glass □ Cotton □ Teflon □ ___________ 14. Filtering Efficiency Rating: _________% 15. Air to Cloth Ratio: ______: 1 16. Hours of Operation: Max Per day ________ Max Per year _______ 17. Cleaning Mechanism: □ Reverse Air □ Shaker □ Pulse Jet □ Other: ______________________ Emissions Calculations (PTE) 18. Calculated emissions for this device PM10 ___________Lbs/hr___________ Tons/yr PM2.5 ___________Lbs/hr___________ Tons/yr NOx ____________Lbs/hr___________ Tons/yr SOx ____________Lbs/hr___________ Tons/yr CO ____________Lbs/hr___________ Tons/yr VOC ___________Lbs/hr___________ Tons/yr HAPs___________Lbs/hr (speciate)____________Tons/yr (speciate) Submit calculations as an appendix. Page 1 of 2 6,769 6,769 TBD 0.010 TBD TBD 170 TBD TBDx TBD TBD TBD 83 24 TBD 24 7880 TBD 2.5 2.5 Glazing Dryer Baghouse (Processing Facility) - Controls PM emissions related to drop points and other materialhandling processing in the glazing operation at the Processing Facility. Peak Minerals Inc. Sevier Playa Potash Project July 2023 14 14 Page 2 of 2 Instructions - Form 10 Fabric Filters (Baghouses) NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Describe the process equipment that the filter controls, what product is being controlled, particle size data (if available), i.e., cement silo, grain silo, nuisance dust in work place, process control with high dust potential, etc. 2. The maximum and design exhaust gas flow rates through the filter control device in actual cubic feet per minute (ACFM). Check literature or call the sales agent. 3. The water/moisture content of the gas stream going through the filter. 4. The amount of particulate in the gas stream going into the filter and the amount coming out if available. Outlet default value = 0.016 grains PM10/dscf. 5. The pressure drop range across the system. Usually given in the literature in inches of water. 6. The temperature of the gas stream entering the filter system in degrees Fahrenheit. 7. The horse power of the fan used to move the gas stream and/or the flow rate of the fan in ft3/min. 8. Name of the manufacturer of the filter equipment and the model number if available. 9. Check the type of filter bag material or fill in the blank. Check literature or call the sales agent. 10. The diameter of the bags in the system. Check literature or call the sales agent. 11. The length of the bags in the system. Check literature or call the sales agent. 12. The number of bags. Check literature or call the sales agent. 13. The height to the top of the stack from ground level and the stack inside diameter. 14. The filtering efficiency rating that the manufacturer quotes. Check literature or call the sales agent. 15. The ratio of the flow rate of air to the cloth area (A/C). 16. The number of hours that the process equipment is in operation, maximum per day and per year. 17. The way in which the filters bags are cleaned. Check the appropriate box. 18. Supply calculations for all criteria pollutants and HAPs. Use AP42 or Manufacturers data to complete your calculations. U:\aq\ENGINEER\GENERIC\Forms 2010\Form10 Baghouses.doc Revised 12/20/10 Utah Division of Air Quality New Source Review Section Company _______________________ Site/Source _____________________ Form 10 Date __________________________ Fabric Filters (Baghouses) Baghouse Description 1. Briefly describe the process controlled by this baghouse: Gas Stream Characteristics 2. Flow Rate (acfm): 4. Particulate Loading (grain/scf) Design Max Average Expected 3. Water Vapor Content of Effluent Stream (lb. water/lb. dry air) Inlet Outlet 5. Pressure Drop (inches H2O) High __________ Low _________ 6. Gas Stream Temperature (°F): 7. Fan Requirements (hp) (ft3/min) Equipment Information and Filter Characteristics 8. Manufacturer and Model Number: 10. Bag Diameter (in.) 11. Bag Length (ft.) 12. Number of Bags: 13. Stack Height ___________ feet Stack Inside Diameter ___________ inches 9. Bag Material: □ Nomex nylon □ Polyester □ Acrylics □ Fiber glass □ Cotton □ Teflon □ ___________ 14. Filtering Efficiency Rating: _________% 15. Air to Cloth Ratio: ______: 1 16. Hours of Operation: Max Per day ________ Max Per year _______ 17. Cleaning Mechanism: □ Reverse Air □ Shaker □ Pulse Jet □ Other: ______________________ Emissions Calculations (PTE) 18. Calculated emissions for this device PM10 ___________Lbs/hr___________ Tons/yr PM2.5 ___________Lbs/hr___________ Tons/yr NOx ____________Lbs/hr___________ Tons/yr SOx ____________Lbs/hr___________ Tons/yr CO ____________Lbs/hr___________ Tons/yr VOC ___________Lbs/hr___________ Tons/yr HAPs___________Lbs/hr (speciate)____________Tons/yr (speciate) Submit calculations as an appendix. Page 1 of 2 Peak Minerals Inc. Sevier Playa Potash Project July 2023 1,500 1,500 TBD 0.005 TBD TBD Equal to ambient temperature TBD TBDx TBD TBD TBD TBD 24 7880 TBD 78 12 0.28 0.28 Loadout Silo Bin Vent (Processing Facility) - Controls PM emissions related to the Loadout Silo at the Processing Facility. 1.51.5 Page 2 of 2 Instructions - Form 10 Fabric Filters (Baghouses) NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Describe the process equipment that the filter controls, what product is being controlled, particle size data (if available), i.e., cement silo, grain silo, nuisance dust in work place, process control with high dust potential, etc. 2. The maximum and design exhaust gas flow rates through the filter control device in actual cubic feet per minute (ACFM). Check literature or call the sales agent. 3. The water/moisture content of the gas stream going through the filter. 4. The amount of particulate in the gas stream going into the filter and the amount coming out if available. Outlet default value = 0.016 grains PM10/dscf. 5. The pressure drop range across the system. Usually given in the literature in inches of water. 6. The temperature of the gas stream entering the filter system in degrees Fahrenheit. 7. The horse power of the fan used to move the gas stream and/or the flow rate of the fan in ft3/min. 8. Name of the manufacturer of the filter equipment and the model number if available. 9. Check the type of filter bag material or fill in the blank. Check literature or call the sales agent. 10. The diameter of the bags in the system. Check literature or call the sales agent. 11. The length of the bags in the system. Check literature or call the sales agent. 12. The number of bags. Check literature or call the sales agent. 13. The height to the top of the stack from ground level and the stack inside diameter. 14. The filtering efficiency rating that the manufacturer quotes. Check literature or call the sales agent. 15. The ratio of the flow rate of air to the cloth area (A/C). 16. The number of hours that the process equipment is in operation, maximum per day and per year. 17. The way in which the filters bags are cleaned. Check the appropriate box. 18. Supply calculations for all criteria pollutants and HAPs. Use AP42 or Manufacturers data to complete your calculations. U:\aq\ENGINEER\GENERIC\Forms 2010\Form10 Baghouses.doc Revised 12/20/10 Utah Division of Air Quality New Source Review Section Company _______________________ Site/Source _____________________ Form 10 Date __________________________ Fabric Filters (Baghouses) Baghouse Description 1. Briefly describe the process controlled by this baghouse: Gas Stream Characteristics 2. Flow Rate (acfm): 4. Particulate Loading (grain/scf) Design Max Average Expected 3. Water Vapor Content of Effluent Stream (lb. water/lb. dry air) Inlet Outlet 5. Pressure Drop (inches H2O) High __________ Low _________ 6. Gas Stream Temperature (°F): 7. Fan Requirements (hp) (ft3/min) Equipment Information and Filter Characteristics 8. Manufacturer and Model Number: 10. Bag Diameter (in.) 11. Bag Length (ft.) 12. Number of Bags: 13. Stack Height ___________ feet Stack Inside Diameter ___________ inches 9. Bag Material: □ Nomex nylon □ Polyester □ Acrylics □ Fiber glass □ Cotton □ Teflon □ ___________ 14. Filtering Efficiency Rating: _________% 15. Air to Cloth Ratio: ______: 1 16. Hours of Operation: Max Per day ________ Max Per year _______ 17. Cleaning Mechanism: □ Reverse Air □ Shaker □ Pulse Jet □ Other: ______________________ Emissions Calculations (PTE) 18. Calculated emissions for this device PM10 ___________Lbs/hr___________ Tons/yr PM2.5 ___________Lbs/hr___________ Tons/yr NOx ____________Lbs/hr___________ Tons/yr SOx ____________Lbs/hr___________ Tons/yr CO ____________Lbs/hr___________ Tons/yr VOC ___________Lbs/hr___________ Tons/yr HAPs___________Lbs/hr (speciate)____________Tons/yr (speciate) Submit calculations as an appendix. Page 1 of 2 Peak Minerals Inc. Sevier Playa Potash Project July 2023 Main Dryer Baghouse (Processing Facility) - Controls particulate matter from the drying and sizing fluid bed dryer at theProcessing Facility. 14,125 14,125 Unknown 0.010 260 TBD TBD x TBD TBD TBD TBD TBD TBD 24 7880 TBD 24 83 5.35.329 29 Page 2 of 2 Instructions - Form 10 Fabric Filters (Baghouses) NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Describe the process equipment that the filter controls, what product is being controlled, particle size data (if available), i.e., cement silo, grain silo, nuisance dust in work place, process control with high dust potential, etc. 2. The maximum and design exhaust gas flow rates through the filter control device in actual cubic feet per minute (ACFM). Check literature or call the sales agent. 3. The water/moisture content of the gas stream going through the filter. 4. The amount of particulate in the gas stream going into the filter and the amount coming out if available. Outlet default value = 0.016 grains PM10/dscf. 5. The pressure drop range across the system. Usually given in the literature in inches of water. 6. The temperature of the gas stream entering the filter system in degrees Fahrenheit. 7. The horse power of the fan used to move the gas stream and/or the flow rate of the fan in ft3/min. 8. Name of the manufacturer of the filter equipment and the model number if available. 9. Check the type of filter bag material or fill in the blank. Check literature or call the sales agent. 10. The diameter of the bags in the system. Check literature or call the sales agent. 11. The length of the bags in the system. Check literature or call the sales agent. 12. The number of bags. Check literature or call the sales agent. 13. The height to the top of the stack from ground level and the stack inside diameter. 14. The filtering efficiency rating that the manufacturer quotes. Check literature or call the sales agent. 15. The ratio of the flow rate of air to the cloth area (A/C). 16. The number of hours that the process equipment is in operation, maximum per day and per year. 17. The way in which the filters bags are cleaned. Check the appropriate box. 18. Supply calculations for all criteria pollutants and HAPs. Use AP42 or Manufacturers data to complete your calculations. U:\aq\ENGINEER\GENERIC\Forms 2010\Form10 Baghouses.doc Revised 12/20/10 Utah Division of Air Quality New Source Review Section Company _______________________ Site/Source _____________________ Form 10 Date __________________________ Fabric Filters (Baghouses) Baghouse Description 1. Briefly describe the process controlled by this baghouse: Gas Stream Characteristics 2. Flow Rate (acfm): 4. Particulate Loading (grain/scf) Design Max Average Expected 3. Water Vapor Content of Effluent Stream (lb. water/lb. dry air) Inlet Outlet 5. Pressure Drop (inches H2O) High __________ Low _________ 6. Gas Stream Temperature (°F): 7. Fan Requirements (hp) (ft3/min) Equipment Information and Filter Characteristics 8. Manufacturer and Model Number: 10. Bag Diameter (in.) 11. Bag Length (ft.) 12. Number of Bags: 13. Stack Height ___________ feet Stack Inside Diameter ___________ inches 9. Bag Material: □ Nomex nylon □ Polyester □ Acrylics □ Fiber glass □ Cotton □ Teflon □ ___________ 14. Filtering Efficiency Rating: _________% 15. Air to Cloth Ratio: ______: 1 16. Hours of Operation: Max Per day ________ Max Per year _______ 17. Cleaning Mechanism: □ Reverse Air □ Shaker □ Pulse Jet □ Other: ______________________ Emissions Calculations (PTE) 18. Calculated emissions for this device PM10 ___________Lbs/hr___________ Tons/yr PM2.5 ___________Lbs/hr___________ Tons/yr NOx ____________Lbs/hr___________ Tons/yr SOx ____________Lbs/hr___________ Tons/yr CO ____________Lbs/hr___________ Tons/yr VOC ___________Lbs/hr___________ Tons/yr HAPs___________Lbs/hr (speciate)____________Tons/yr (speciate) Submit calculations as an appendix. Page 1 of 2 Peak Minerals Inc. Sevier Playa Potash Project July 2023 1,9001,900 TBD 0.005 TBD TBD Equal to ambient temperature TBD TBDx TBD TBD TBD TBD 53 12 24 7880 TBD 0.36 0.36 MOP Silo Bin Vent (Processing Facility) - Controls PM emissions related to the MOP Silo at the Processing Facility. 1.95 1.95 Page 2 of 2 Instructions - Form 10 Fabric Filters (Baghouses) NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Describe the process equipment that the filter controls, what product is being controlled, particle size data (if available), i.e., cement silo, grain silo, nuisance dust in work place, process control with high dust potential, etc. 2. The maximum and design exhaust gas flow rates through the filter control device in actual cubic feet per minute (ACFM). Check literature or call the sales agent. 3. The water/moisture content of the gas stream going through the filter. 4. The amount of particulate in the gas stream going into the filter and the amount coming out if available. Outlet default value = 0.016 grains PM10/dscf. 5. The pressure drop range across the system. Usually given in the literature in inches of water. 6. The temperature of the gas stream entering the filter system in degrees Fahrenheit. 7. The horse power of the fan used to move the gas stream and/or the flow rate of the fan in ft3/min. 8. Name of the manufacturer of the filter equipment and the model number if available. 9. Check the type of filter bag material or fill in the blank. Check literature or call the sales agent. 10. The diameter of the bags in the system. Check literature or call the sales agent. 11. The length of the bags in the system. Check literature or call the sales agent. 12. The number of bags. Check literature or call the sales agent. 13. The height to the top of the stack from ground level and the stack inside diameter. 14. The filtering efficiency rating that the manufacturer quotes. Check literature or call the sales agent. 15. The ratio of the flow rate of air to the cloth area (A/C). 16. The number of hours that the process equipment is in operation, maximum per day and per year. 17. The way in which the filters bags are cleaned. Check the appropriate box. 18. Supply calculations for all criteria pollutants and HAPs. Use AP42 or Manufacturers data to complete your calculations. U:\aq\ENGINEER\GENERIC\Forms 2010\Form10 Baghouses.doc Revised 12/20/10 Utah Division of Air Quality New Source Review Section Company _______________________ Site/Source _____________________ Form 10 Date __________________________ Fabric Filters (Baghouses) Baghouse Description 1. Briefly describe the process controlled by this baghouse: Gas Stream Characteristics 2. Flow Rate (acfm): 4. Particulate Loading (grain/scf) Design Max Average Expected 3. Water Vapor Content of Effluent Stream (lb. water/lb. dry air) Inlet Outlet 5. Pressure Drop (inches H2O) High __________ Low _________ 6. Gas Stream Temperature (°F): 7. Fan Requirements (hp) (ft3/min) Equipment Information and Filter Characteristics 8. Manufacturer and Model Number: 10. Bag Diameter (in.) 11. Bag Length (ft.) 12. Number of Bags: 13. Stack Height ___________ feet Stack Inside Diameter ___________ inches 9. Bag Material: □ Nomex nylon □ Polyester □ Acrylics □ Fiber glass □ Cotton □ Teflon □ ___________ 14. Filtering Efficiency Rating: _________% 15. Air to Cloth Ratio: ______: 1 16. Hours of Operation: Max Per day ________ Max Per year _______ 17. Cleaning Mechanism: □ Reverse Air □ Shaker □ Pulse Jet □ Other: ______________________ Emissions Calculations (PTE) 18. Calculated emissions for this device PM10 ___________Lbs/hr___________ Tons/yr PM2.5 ___________Lbs/hr___________ Tons/yr NOx ____________Lbs/hr___________ Tons/yr SOx ____________Lbs/hr___________ Tons/yr CO ____________Lbs/hr___________ Tons/yr VOC ___________Lbs/hr___________ Tons/yr HAPs___________Lbs/hr (speciate)____________Tons/yr (speciate) Submit calculations as an appendix. Page 1 of 2 Peak Minerals Inc. Sevier Playa Potash Project July 2023 Quick Lime Silo Bin Vent (Bischofite Facility) - Controls PM emissions related to the Quick Lime Silo at the Bischofite Facility. 1,900 TBD 0.005 TBD TBD Equal to ambient temperature TBD TBDx TBD TBD TBD TBD 24 7880 TBD 51 8 0.357 0.357 1,900 1.95 1.95 Page 2 of 2 Instructions - Form 10 Fabric Filters (Baghouses) NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Describe the process equipment that the filter controls, what product is being controlled, particle size data (if available), i.e., cement silo, grain silo, nuisance dust in work place, process control with high dust potential, etc. 2. The maximum and design exhaust gas flow rates through the filter control device in actual cubic feet per minute (ACFM). Check literature or call the sales agent. 3. The water/moisture content of the gas stream going through the filter. 4. The amount of particulate in the gas stream going into the filter and the amount coming out if available. Outlet default value = 0.016 grains PM10/dscf. 5. The pressure drop range across the system. Usually given in the literature in inches of water. 6. The temperature of the gas stream entering the filter system in degrees Fahrenheit. 7. The horse power of the fan used to move the gas stream and/or the flow rate of the fan in ft3/min. 8. Name of the manufacturer of the filter equipment and the model number if available. 9. Check the type of filter bag material or fill in the blank. Check literature or call the sales agent. 10. The diameter of the bags in the system. Check literature or call the sales agent. 11. The length of the bags in the system. Check literature or call the sales agent. 12. The number of bags. Check literature or call the sales agent. 13. The height to the top of the stack from ground level and the stack inside diameter. 14. The filtering efficiency rating that the manufacturer quotes. Check literature or call the sales agent. 15. The ratio of the flow rate of air to the cloth area (A/C). 16. The number of hours that the process equipment is in operation, maximum per day and per year. 17. The way in which the filters bags are cleaned. Check the appropriate box. 18. Supply calculations for all criteria pollutants and HAPs. Use AP42 or Manufacturers data to complete your calculations. U:\aq\ENGINEER\GENERIC\Forms 2010\Form10 Baghouses.doc Revised 12/20/10 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 Peak Minerals Inc. Sevier Playa Potash Project July 2023 TBD TBD TBD x TBD 19,300 <0.0015 N/A TBD TBD Emergency Generator #1 1 24 100 Hours/year 100 Hours/year 1,342 1,342 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. x x TBD TBD TBD TBD x Tier 4 certification Page 3 of 4 INSTRUCTIONS – Form 11 Internal Combustion Engine NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed. 2. Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per week, and weeks per year. 3. Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site operating range is in megawatts or horsepower. 4. Indicate the origin of the gas used in the engine. 5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens. 6. Specify what the annual consumption of fuel is in million standard cubic feet (MMscf). 7. Supply the maximum firing rate in BTU/hr. 8. Supply the average firing rate in BTU/hr. 9. Indicate the grade of oil being used. 10. Supply the annual consumption calculated in gallons of oil. 11. Indicate the heat content of the oil in BTU/lb or BTU/gal. 12. Indicate the sulfur content of the oil in percent by weight. 13. Indicate the ash content of the oil. 14. Supply the average firing rate of oil. 15. Supply the maximum firing rate of oil. 16. Indicate what the firing direction is. 17. Indicate what the engine will be used for. 18. Indicate what type of cycle the engine will have. 19. Indicate the manufacturer’s emissions rate in grams/hp-hr 20. Provide manufacturer's emission information for the engine. Also indicate what method of emission control to be used. 21. Provide details of the operation of emission controls and exhaust parameter information. f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc Revised 12/20/10 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. NOx SOx CO VOC PM10 PM25 4,526 9.8 824EG12980.6612308,784 4,288,2310.074 5.2E-04 0.39 0.022 0.0033 0.0032 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 Peak Minerals Inc. Sevier Playa Potash Project July 2023 TBD TBD TBD x TBD 19,300 <0.0015 N/A TBD TBD Emergency Generator #2 1 24 100 Hours/year 100 Hours/year 1,342 1,342 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. x x TBD TBD TBD TBD x Tier 4 certification Page 3 of 4 INSTRUCTIONS – Form 11 Internal Combustion Engine NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed. 2. Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per week, and weeks per year. 3. Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site operating range is in megawatts or horsepower. 4. Indicate the origin of the gas used in the engine. 5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens. 6. Specify what the annual consumption of fuel is in million standard cubic feet (MMscf). 7. Supply the maximum firing rate in BTU/hr. 8. Supply the average firing rate in BTU/hr. 9. Indicate the grade of oil being used. 10. Supply the annual consumption calculated in gallons of oil. 11. Indicate the heat content of the oil in BTU/lb or BTU/gal. 12. Indicate the sulfur content of the oil in percent by weight. 13. Indicate the ash content of the oil. 14. Supply the average firing rate of oil. 15. Supply the maximum firing rate of oil. 16. Indicate what the firing direction is. 17. Indicate what the engine will be used for. 18. Indicate what type of cycle the engine will have. 19. Indicate the manufacturer’s emissions rate in grams/hp-hr 20. Provide manufacturer's emission information for the engine. Also indicate what method of emission control to be used. 21. Provide details of the operation of emission controls and exhaust parameter information. f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc Revised 12/20/10 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. NOx SOx CO VOC PM10 PM25 4,526 9.8 824EG22980.6612308,790 4,288,2310.074 5.2E-04 0.39 0.022 0.0033 0.0032 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 Peak Minerals Inc. Sevier Playa Potash Project July 2023 TBD TBD TBD 24 7 52 24 7 52 53 53 x <0.0015 N/A 19,300TBD Generator Set 1 TBD TBD 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. TBD TBD TBD TBD x x x Tier 4 certification Page 3 of 4 INSTRUCTIONS – Form 11 Internal Combustion Engine NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed. 2. Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per week, and weeks per year. 3. Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site operating range is in megawatts or horsepower. 4. Indicate the origin of the gas used in the engine. 5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens. 6. Specify what the annual consumption of fuel is in million standard cubic feet (MMscf). 7. Supply the maximum firing rate in BTU/hr. 8. Supply the average firing rate in BTU/hr. 9. Indicate the grade of oil being used. 10. Supply the annual consumption calculated in gallons of oil. 11. Indicate the heat content of the oil in BTU/lb or BTU/gal. 12. Indicate the sulfur content of the oil in percent by weight. 13. Indicate the ash content of the oil. 14. Supply the average firing rate of oil. 15. Supply the maximum firing rate of oil. 16. Indicate what the firing direction is. 17. Indicate what the engine will be used for. 18. Indicate what type of cycle the engine will have. 19. Indicate the manufacturer’s emissions rate in grams/hp-hr 20. Provide manufacturer's emission information for the engine. Also indicate what method of emission control to be used. 21. Provide details of the operation of emission controls and exhaust parameter information. f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc Revised 12/20/10 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. Genset1 CO SOx VOC PM10 NOx PM2.5 0.003 1.9 0.10 0.011 0.011 1.7 9.8 0.33 279 824 4,526 0.4 0.0006 0.4 0.022 0.0026 0.0025 12 313,567 4,302,944 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 TBD TBD TBD 24 7 52 24 7 52 53 53 x TBD 19,300 <0.0015 N/A Generator Set 2 Peak Minerals Inc. July 2023 Sevier Playa Potash Project TBD TBD 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. x x TBD TBD TBD x Tier 4 certification Page 3 of 4 INSTRUCTIONS – Form 11 Internal Combustion Engine NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed. 2. Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per week, and weeks per year. 3. Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site operating range is in megawatts or horsepower. 4. Indicate the origin of the gas used in the engine. 5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens. 6. Specify what the annual consumption of fuel is in million standard cubic feet (MMscf). 7. Supply the maximum firing rate in BTU/hr. 8. Supply the average firing rate in BTU/hr. 9. Indicate the grade of oil being used. 10. Supply the annual consumption calculated in gallons of oil. 11. Indicate the heat content of the oil in BTU/lb or BTU/gal. 12. Indicate the sulfur content of the oil in percent by weight. 13. Indicate the ash content of the oil. 14. Supply the average firing rate of oil. 15. Supply the maximum firing rate of oil. 16. Indicate what the firing direction is. 17. Indicate what the engine will be used for. 18. Indicate what type of cycle the engine will have. 19. Indicate the manufacturer’s emissions rate in grams/hp-hr 20. Provide manufacturer's emission information for the engine. Also indicate what method of emission control to be used. 21. Provide details of the operation of emission controls and exhaust parameter information. f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc Revised 12/20/10 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. Genset2 NOx SOx CO VOC PM10 PM2.5 1.7 0.003 1.9 0.10 0.011 0.011 9.8 0.33 279 824 4,526 0.4 0.0006 0.4 0.022 0.0026 0.0025 12 313,878 4,296,370 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 Peak Minerals Inc. Sevier Playa Potash Project July 2023 Generator Set 3 TBD TBD TBD 24 7 52 7 52 24 53 53 x TBD 19,300 <0.0015 N/A TBD TBD 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. x x TBD TBDTBD TBD x Tier 4 certification Page 3 of 4 INSTRUCTIONS – Form 11 Internal Combustion Engine NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed. 2. Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per week, and weeks per year. 3. Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site operating range is in megawatts or horsepower. 4. Indicate the origin of the gas used in the engine. 5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens. 6. Specify what the annual consumption of fuel is in million standard cubic feet (MMscf). 7. Supply the maximum firing rate in BTU/hr. 8. Supply the average firing rate in BTU/hr. 9. Indicate the grade of oil being used. 10. Supply the annual consumption calculated in gallons of oil. 11. Indicate the heat content of the oil in BTU/lb or BTU/gal. 12. Indicate the sulfur content of the oil in percent by weight. 13. Indicate the ash content of the oil. 14. Supply the average firing rate of oil. 15. Supply the maximum firing rate of oil. 16. Indicate what the firing direction is. 17. Indicate what the engine will be used for. 18. Indicate what type of cycle the engine will have. 19. Indicate the manufacturer’s emissions rate in grams/hp-hr 20. Provide manufacturer's emission information for the engine. Also indicate what method of emission control to be used. 21. Provide details of the operation of emission controls and exhaust parameter information. f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc Revised 12/20/10 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. Genset3 NOx SOx CO VOC PM10 PM25 1.7 0.003 1.9 0.10 0.011 0.011 9.8 0.33 279 824 4,526 0.4 0.0006 0.4 0.022 0.0026 0.0025 12 313,851 4,291,844 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 Peak Minerals Inc. Sevier Playa Potash Project July 2023 Generator Set 4 TBD TBD TBD 24 7 52 24 7 52 139 139 x TBD 19,300 <0.0015 N/A TBD TBD 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. x x TBD TBD TBD TBD x Tier 4 certification Page 3 of 4 INSTRUCTIONS – Form 11 Internal Combustion Engine NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed. 2. Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per week, and weeks per year. 3. Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site operating range is in megawatts or horsepower. 4. Indicate the origin of the gas used in the engine. 5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens. 6. Specify what the annual consumption of fuel is in million standard cubic feet (MMscf). 7. Supply the maximum firing rate in BTU/hr. 8. Supply the average firing rate in BTU/hr. 9. Indicate the grade of oil being used. 10. Supply the annual consumption calculated in gallons of oil. 11. Indicate the heat content of the oil in BTU/lb or BTU/gal. 12. Indicate the sulfur content of the oil in percent by weight. 13. Indicate the ash content of the oil. 14. Supply the average firing rate of oil. 15. Supply the maximum firing rate of oil. 16. Indicate what the firing direction is. 17. Indicate what the engine will be used for. 18. Indicate what type of cycle the engine will have. 19. Indicate the manufacturer’s emissions rate in grams/hp-hr 20. Provide manufacturer's emission information for the engine. Also indicate what method of emission control to be used. 21. Provide details of the operation of emission controls and exhaust parameter information. f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc Revised 12/20/10 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. Genset4 NOx SOx CO VOC PM10 PM25 0.40 0.0047 5.0 0.20 0.020 0.019 9.8 0.33 279 824 4,526 0.09 0.0011 1.1 0.046 0.004 0.0046 12 317,398 4,311,511 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 Peak Minerals Inc. Sevier Playa Potash Project July 2023 TBD TBD TBD Generator Set 5 24 24 59 59 x TBD 19,300 <0.0015 N/A TBD TBD 152 Days/year 152 Days/year 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. x x TBD TBD TBD TBD x Tier 4 certification Page 3 of 4 INSTRUCTIONS – Form 11 Internal Combustion Engine NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed. 2. Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per week, and weeks per year. 3. Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site operating range is in megawatts or horsepower. 4. Indicate the origin of the gas used in the engine. 5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens. 6. Specify what the annual consumption of fuel is in million standard cubic feet (MMscf). 7. Supply the maximum firing rate in BTU/hr. 8. Supply the average firing rate in BTU/hr. 9. Indicate the grade of oil being used. 10. Supply the annual consumption calculated in gallons of oil. 11. Indicate the heat content of the oil in BTU/lb or BTU/gal. 12. Indicate the sulfur content of the oil in percent by weight. 13. Indicate the ash content of the oil. 14. Supply the average firing rate of oil. 15. Supply the maximum firing rate of oil. 16. Indicate what the firing direction is. 17. Indicate what the engine will be used for. 18. Indicate what type of cycle the engine will have. 19. Indicate the manufacturer’s emissions rate in grams/hp-hr 20. Provide manufacturer's emission information for the engine. Also indicate what method of emission control to be used. 21. Provide details of the operation of emission controls and exhaust parameter information. f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc Revised 12/20/10 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. Genset5 CO VOC PM10 PM25 0.8 SOx NOx 0.0013 0.9 0.044 0.005 0.005 9.8 0.33 279 824 4,526 0.43 0.0007 0.5 0.02 0.003 0.003 12 318,594 4,315,345 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 Peak Minerals Inc. Sevier Playa Potash Project July 2023 TBD TBD TBD 24 24 152 Days/year152 Days/year 59 59 x TBD 19,300 <0.0015 N/A TBD TBD Generator Set 6 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. x x TBD TBD TBD TBD x Tier 4 certification Page 3 of 4 INSTRUCTIONS – Form 11 Internal Combustion Engine NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed. 2. Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per week, and weeks per year. 3. Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site operating range is in megawatts or horsepower. 4. Indicate the origin of the gas used in the engine. 5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens. 6. Specify what the annual consumption of fuel is in million standard cubic feet (MMscf). 7. Supply the maximum firing rate in BTU/hr. 8. Supply the average firing rate in BTU/hr. 9. Indicate the grade of oil being used. 10. Supply the annual consumption calculated in gallons of oil. 11. Indicate the heat content of the oil in BTU/lb or BTU/gal. 12. Indicate the sulfur content of the oil in percent by weight. 13. Indicate the ash content of the oil. 14. Supply the average firing rate of oil. 15. Supply the maximum firing rate of oil. 16. Indicate what the firing direction is. 17. Indicate what the engine will be used for. 18. Indicate what type of cycle the engine will have. 19. Indicate the manufacturer’s emissions rate in grams/hp-hr 20. Provide manufacturer's emission information for the engine. Also indicate what method of emission control to be used. 21. Provide details of the operation of emission controls and exhaust parameter information. f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc Revised 12/20/10 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. Genset6 NOx SOx CO VOC PM10 PM25 0.9 0.0013 0.8 0.044 0.005 0.005 9.8 0.33 279 824 4,526 0.43 0.0007 0.5 0.02 0.003 0.003 12 319,151 4,317,462 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 Peak Minerals Inc. Sevier Playa Potash Project July 2023 Generator Set 7 TBD TBD TBD 24 152 Days/year 152 Days/year 111 111 x TBD 19,300 <0.0015 N/A TBD TBD 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. x x TBD TBD TBD TBD x Tier 4 certification Page 3 of 4 INSTRUCTIONS – Form 11 Internal Combustion Engine NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed. 2. Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per week, and weeks per year. 3. Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site operating range is in megawatts or horsepower. 4. Indicate the origin of the gas used in the engine. 5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens. 6. Specify what the annual consumption of fuel is in million standard cubic feet (MMscf). 7. Supply the maximum firing rate in BTU/hr. 8. Supply the average firing rate in BTU/hr. 9. Indicate the grade of oil being used. 10. Supply the annual consumption calculated in gallons of oil. 11. Indicate the heat content of the oil in BTU/lb or BTU/gal. 12. Indicate the sulfur content of the oil in percent by weight. 13. Indicate the ash content of the oil. 14. Supply the average firing rate of oil. 15. Supply the maximum firing rate of oil. 16. Indicate what the firing direction is. 17. Indicate what the engine will be used for. 18. Indicate what type of cycle the engine will have. 19. Indicate the manufacturer’s emissions rate in grams/hp-hr 20. Provide manufacturer's emission information for the engine. Also indicate what method of emission control to be used. 21. Provide details of the operation of emission controls and exhaust parameter information. f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc Revised 12/20/10 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. Genset7 NOx SOx CO VOC PM10 PM25 0.07 0.001 0.9 0.04 0.004 0.004 0.13 0.0016 1.7 0.07 0.007 0.006 4,526 9.8 0.33 279 82412311,914 4,290,010 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 Peak Minerals Inc. Sevier Playa Potash Project July 2023 TBD TBD TBD 24 152 Days/year 152 Days/year x TBD 19,300 <0.0015 N/A TBD TBD Generator Set 8 78 78 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. x x TBD TBD TBD TBD x Tier 4 certification Page 3 of 4 INSTRUCTIONS – Form 11 Internal Combustion Engine NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed. 2. Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per week, and weeks per year. 3. Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site operating range is in megawatts or horsepower. 4. Indicate the origin of the gas used in the engine. 5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens. 6. Specify what the annual consumption of fuel is in million standard cubic feet (MMscf). 7. Supply the maximum firing rate in BTU/hr. 8. Supply the average firing rate in BTU/hr. 9. Indicate the grade of oil being used. 10. Supply the annual consumption calculated in gallons of oil. 11. Indicate the heat content of the oil in BTU/lb or BTU/gal. 12. Indicate the sulfur content of the oil in percent by weight. 13. Indicate the ash content of the oil. 14. Supply the average firing rate of oil. 15. Supply the maximum firing rate of oil. 16. Indicate what the firing direction is. 17. Indicate what the engine will be used for. 18. Indicate what type of cycle the engine will have. 19. Indicate the manufacturer’s emissions rate in grams/hp-hr 20. Provide manufacturer's emission information for the engine. Also indicate what method of emission control to be used. 21. Provide details of the operation of emission controls and exhaust parameter information. f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc Revised 12/20/10 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. NOx SOx CO VOC PM10 PM25 4,526 9.8 0.33 279 824Genset80.05 0.00067 0.64 0.026 0.0026 0.0025 0.09 0.0012 1.2 0.05 0.0047 0.0045 12 306,488 4,289,349 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 Peak Minerals Inc. Sevier Playa Potash Project July 2023 TBD TBD TBD 24 x TBD 19,300 <0.0015 N/A TBD TBD Pond Mobile Pump #1 20 20 1,488 Hours/year 1,488 Hoursyear 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. x x TBD TBD TBD TBD x Tier 4 certification Page 3 of 4 INSTRUCTIONS – Form 11 Internal Combustion Engine NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed. 2. Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per week, and weeks per year. 3. Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site operating range is in megawatts or horsepower. 4. Indicate the origin of the gas used in the engine. 5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens. 6. Specify what the annual consumption of fuel is in million standard cubic feet (MMscf). 7. Supply the maximum firing rate in BTU/hr. 8. Supply the average firing rate in BTU/hr. 9. Indicate the grade of oil being used. 10. Supply the annual consumption calculated in gallons of oil. 11. Indicate the heat content of the oil in BTU/lb or BTU/gal. 12. Indicate the sulfur content of the oil in percent by weight. 13. Indicate the ash content of the oil. 14. Supply the average firing rate of oil. 15. Supply the maximum firing rate of oil. 16. Indicate what the firing direction is. 17. Indicate what the engine will be used for. 18. Indicate what type of cycle the engine will have. 19. Indicate the manufacturer’s emissions rate in grams/hp-hr 20. Provide manufacturer's emission information for the engine. Also indicate what method of emission control to be used. 21. Provide details of the operation of emission controls and exhaust parameter information. f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc Revised 12/20/10 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. NOx SOx CO VOC PM10 PM25 4,526 9.8 0.33 279 824PMP10.52 5.3E-04 0.48 0.029 0.029 0.028 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 Peak Minerals Inc. Sevier Playa Potash Project July 2023 TBD TBD TBD 24 x TBD 19,300 <0.0015 N/A TBD TBD Pond Mobile Pump #1 20 20 1,488 Hours/year 1,488 Hoursyear 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. x x TBD TBD TBD TBD x Tier 4 certification Page 3 of 4 INSTRUCTIONS – Form 11 Internal Combustion Engine NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed. 2. Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per week, and weeks per year. 3. Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site operating range is in megawatts or horsepower. 4. Indicate the origin of the gas used in the engine. 5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens. 6. Specify what the annual consumption of fuel is in million standard cubic feet (MMscf). 7. Supply the maximum firing rate in BTU/hr. 8. Supply the average firing rate in BTU/hr. 9. Indicate the grade of oil being used. 10. Supply the annual consumption calculated in gallons of oil. 11. Indicate the heat content of the oil in BTU/lb or BTU/gal. 12. Indicate the sulfur content of the oil in percent by weight. 13. Indicate the ash content of the oil. 14. Supply the average firing rate of oil. 15. Supply the maximum firing rate of oil. 16. Indicate what the firing direction is. 17. Indicate what the engine will be used for. 18. Indicate what type of cycle the engine will have. 19. Indicate the manufacturer’s emissions rate in grams/hp-hr 20. Provide manufacturer's emission information for the engine. Also indicate what method of emission control to be used. 21. Provide details of the operation of emission controls and exhaust parameter information. f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc Revised 12/20/10 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. NOx SOx CO VOC PM10 PM25 4,526 9.8 0.33 279 824PMP10.17 1.8E-04 0.16 0.010 0.010 0.0095 12 308,813 4,289,835 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 Peak Minerals Inc. Sevier Playa Potash Project July 2023 TBD TBD TBD 24 x TBD 19,300 <0.0015 N/A TBD TBD 20 20 1,488 Hours/year 1,488 Hoursyear Pond Mobile Pump #2 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. x x TBD TBD TBD TBD x Tier 4 certification Page 3 of 4 INSTRUCTIONS – Form 11 Internal Combustion Engine NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed. 2. Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per week, and weeks per year. 3. Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site operating range is in megawatts or horsepower. 4. Indicate the origin of the gas used in the engine. 5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens. 6. Specify what the annual consumption of fuel is in million standard cubic feet (MMscf). 7. Supply the maximum firing rate in BTU/hr. 8. Supply the average firing rate in BTU/hr. 9. Indicate the grade of oil being used. 10. Supply the annual consumption calculated in gallons of oil. 11. Indicate the heat content of the oil in BTU/lb or BTU/gal. 12. Indicate the sulfur content of the oil in percent by weight. 13. Indicate the ash content of the oil. 14. Supply the average firing rate of oil. 15. Supply the maximum firing rate of oil. 16. Indicate what the firing direction is. 17. Indicate what the engine will be used for. 18. Indicate what type of cycle the engine will have. 19. Indicate the manufacturer’s emissions rate in grams/hp-hr 20. Provide manufacturer's emission information for the engine. Also indicate what method of emission control to be used. 21. Provide details of the operation of emission controls and exhaust parameter information. f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc Revised 12/20/10 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. NOx SOx CO VOC PM10 PM25 4,526 0.33 279 824PMP20.17 1.8E-04 0.16 0.010 0.010 0.0095 12 308,814 4,289,505 9.8 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 Peak Minerals Inc. Sevier Playa Potash Project July 2023 TBD TBD TBD 24 x TBD 19,300 <0.0015 N/A TBD TBD 20 20 1,488 Hours/year 1,488 Hoursyear Pond Mobile Pump #3 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. x x TBD TBD TBD TBD x Tier 4 certification Page 3 of 4 INSTRUCTIONS – Form 11 Internal Combustion Engine NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 1. Indicate the manufacturer, the model number and the date the engine was constructed or reconstructed. 2. Complete the fuel burning equipment's average and maximum operating schedule in hours per day, days per week, and weeks per year. 3. Specify the manufacturer's rated output and heat rate at baseload corresponding to International Standard Organization (ISO) conditions in megawatts (MW) or horsepower (hp). Also indicated what the proposed site operating range is in megawatts or horsepower. 4. Indicate the origin of the gas used in the engine. 5. Indicate if the gas supply can be interrupted and what the backup fuel is in case this happens. 6. Specify what the annual consumption of fuel is in million standard cubic feet (MMscf). 7. Supply the maximum firing rate in BTU/hr. 8. Supply the average firing rate in BTU/hr. 9. Indicate the grade of oil being used. 10. Supply the annual consumption calculated in gallons of oil. 11. Indicate the heat content of the oil in BTU/lb or BTU/gal. 12. Indicate the sulfur content of the oil in percent by weight. 13. Indicate the ash content of the oil. 14. Supply the average firing rate of oil. 15. Supply the maximum firing rate of oil. 16. Indicate what the firing direction is. 17. Indicate what the engine will be used for. 18. Indicate what type of cycle the engine will have. 19. Indicate the manufacturer’s emissions rate in grams/hp-hr 20. Provide manufacturer's emission information for the engine. Also indicate what method of emission control to be used. 21. Provide details of the operation of emission controls and exhaust parameter information. f:\aq\ENGINEER\GENERIC\Forms 2010\Form11 Internal Combustion Engines.doc Revised 12/20/10 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. NOx SOx CO VOC PM10 PM25 4,526 0.33 279 824PMP30.17 1.8E-04 0.16 0.010 0.010 0.0095 12 306,685 4,289,479 9.8 Utah Division of Air Quality Date _______________________________________ New Source Review Section Company_____________________________ Site ___ Form 15 Aggregate Processing Operations Equipment Information 1. Check the appropriate crushing operations used in your process: Type of Unit ___________________________ Manufacturer/Model________________________ Design Capacity______________________tons/hr Date Manufactured ________________________ _ Primary Crushing type _ Cone _ Jaw _ Ball _ Secondary Crushing type _ Cone _ Jaw _ Ball _ Tertiary Crushing type _ Cone _ Jaw _ Ball Screen Manufacturer __________________________ Model and Date Manufactured __________________ Screen type and size (triple, double, or single deck) _________________________________ 2. Dust sources will be controlled as follows: No Pre Water Bag Other Control Soaked Spray house (explain) _ Feed hopper _ _ _ _ _ _ All belt transfer points _ _ _ _ _ _ Inlet to all crushers _ _ _ _ _ _ Exit of all crushers _ _ _ _ _ _ All shaker screens _ _ _ _ _ 3. Water Sprays Total Water Rate to nozzles (gal/min): __________ Nozzle pressure (psi): _____________ Quantity of nozzles at each spray bar location: ______________ 4. Maximum Plant Production Rate and Operating Hours: _______ tons/yr ________ tons/hr _______ hrs/yr ________ hrs/day 5. Water sprays used on storage piles? _ Yes _ No Storage pile size:____________________ 6a. Number of conveyor belt transfer and drop points: 6b. List manufactured dates for all conveyor belts NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. To relocate an Aggregate Plant submit Form 15b. 3. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 4. Equipment listed on this form may be subject to New Source Performance Standards. If so, additional information may be requested for the engineering review. Instructions 1. Indicate the type, manufacturer/model, design capacity and manufactured date of the equipment. Mark the appropriate box for the kind of crushing at the facility and indicate the type (cone, ball, jaw) of crushing being done. 2. Mark the appropriate box for the control device for the emission points. 3. List the specifications of the water sprays. Check vendor literature or call sales agent. 4 Indicate the maximum amount of product that will be processed by the facility in tons per hour, the number of hours the facility will be run per day and number of days/year. 5. Are water sprinklers used on storage piles? Indicate the size of the storage piles. 6. Provide the number of belt drop points and list manufactured dates for all your conveyor belts. N:\engineers\ehe\word\form\Form 15 Aggregate Processing Operations Revised 12/20/2010 July 2023 Peak Minerals Inc. Sevier Playa Potash Project Processing Facility TBD 2023 TBD TBD, 2023 TBD N/A 2023 Most of the material transfer points at the Processing Facility will be controlled by baghouses. Any material handling equipment not controlled by a baghouse will be enclosed (either inside a building or via a conveyor enclosure) to minimize fugitive dust formation. The production rates and operating hours listed are based on the highest values for any emission unit at the Processing Facility 519 7880 24 4089720 519 N/A TBD Utah Division of Air Quality New Source Review Section Company: ___________________ Site/Source: _________________ Form 17 Date: _______________________ Diesel Powered Standby Generator Company Information 1. Company Name and Address: ____________________________________________ ____________________________________________ ____________________________________________ ____________________________________________ Phone Number: _______________________________ Fax Number: _______________________________ 2. Company Contact: ____________________________________________ ____________________________________________ ____________________________________________ ____________________________________________ Phone Number: _______________________________ Fax Number: _______________________________ 3. Installation Address: ____________________________________________ County where facility is located: __________________ ____________________________________________ ____________________________________________ Latitude, Longitude and UTM Coordinates of Facility ____________________________________________ __________________________________________ Phone Number: _______________________________ __________________________________________ Fax Number: _______________________________ Standby Generator Information 4. Engines: Maximum Maximum Emission Rate Date the engine Manufacturer Model Rated Hours of Rate of NOx was constructed Horsepower or Kilowatts Operation grams/BHP-HR or reconstructed _______________________________________________________________________________________________ _______________________________________________________________________________________________ _______________________________________________________________________________________________ _______________________________________________________________________________________________ _______________________________________________________________________________________________ _______________________________________________________________________________________________ _______________________________________________________________________________________________ _______________________________________________________________________________________________ Attach Manufacturer-supplied information 5. Calculated emissions for this equipment: PM10____________ Lbs/hr _____________Tons/yr PM2.5____________ Lbs/hr _____________Tons/yr NOx_____________Lbs/hr______________Tons/yr SOx ____________ Lbs/hr______________Tons/yr CO _____________Lbs/hr______________Tons/yr VOC ____________Lbs/hr______________Tons/yr CO2 ____________Tons/yr CH4 ____________ Tons/yr N2O ____________Tons/yr HAPs___________ Lbs/hr (speciate)__________Tons/yr (speciate) Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix. 2023TBD (Fire Pump Engine)100 hp 100 0.3 0.0033 0.41 4.3E-05 0.0017 1.6E-04 1.6E-04 Peak Minerals Inc. 10808 South River Front Parkway, Suite 343 South Jordan, UT 84095 801-984-3350 Michael LeBaron 801-920-4421 Peak Minerals Inc. Sevier Playa Lakeview Yard 32600 West Crystal Peak Spur Road Delta, UT 84624 Peak Minerals Inc. Sevier Playa Potash Project July 2023 Lat: 38.721 Long: -113.199 UTM Zone: 12 X: 308828 Y: 4288134 Instructions Form 17 - Diesel Powered Standby Generator Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! Lines 1 Fill in the name, address, phone number, and fax number of the business applying for the and 2: permit exemption. Line 3 Fill in the address where the equipment will be located. Directions to business if needed for remote locations, i.e., five miles south of Deseret on highway 101, turn left at farmhouse, go 1.5 miles. Identify the county the equipment will be located. Also enter the latitude, longitude and UTM coordinates of the facility. Line 4 Fill in the manufacturer, model, maximum rated horsepower or kilowatts, maximum hours of operation, emission rate for NOx in grams/BHP-hr, and the date the engine was constructed or reconstructed. Attach manufacturer emission information. Note: Maximum rated horsepower not to exceed 1000hp or 750 kilowatts. Also maximum hours not to exceed 300 hours. Line 5 Supply calculations for all criteria pollutants, greenhouse gases and hazardous air pollutants. Use EPA AP-42 or manufacturers’ data to complete your calculations. Fill in the name, address, phone number, and fax number of the business applying for the U:\aq\ENGINEER\GENERIC\Forms 2010\Form17 Diesel-fired Standby Generators.doc Revised 12/20/10 Utah Division of Air Quality New Source Review Section Company _______________________ Site/Source _____________________ Form 19 Date ___________________________ Natural Gas Boilers and Liquid Heaters Boiler Information 1. Boiler Manufacturer: ___________________________________________________________________________ 2. Model Number: ______________________________3. Serial Number: _______________________________ 4. Boiler Rating: _________________(10 6 Btu per Hour) 5.Operating Schedule: __________ hours per day __________ days per week ___________ days per year 6. Use: □ steam: psig □hot water □other hot liquid: ________________________________ □Natural Gas □ LPG □ Butane □ Methanol □Process Gas - H2S content in process gas __________ grain/100cu.ft. 7. Fuels: □Fuel Oil - specify grade:□Other, specify: ______________________________________ Sulfur content % by weight Days per year during which unit is oil fired: ________________ Backup Fuel □Diesel □ Natural Gas □ LPG □ Butane □ Methanol □ Other _________________ 8. Is unit used to incinerate waste gas liquid stream? □ yes □ no (Submit drawing of method of waste stream introduction to burners) Gas Burner Information 9. Gas Burner Manufacturer: _____________________________________________________________________ 10. No. of Burners: ______________________________11. Minimum rating per burner: _____________ cu. ft/hr 12. Average Load: _______%13. Maximum rating per burner: ____________ cu. ft/hr 14. Performance Guarantee (ppm dry corrected to 3% Oxygen): NOx: ______________ CO: ______________ Hydrocarbons: ______________ □Manual □Automatic on-off15. Gas burner mode of control: □Automatic hi-low □Automatic full modulation Oil Burner Information 16. Oil burner manufacturer: 17. Model: _______________ number of burners: _________________ Size number: _______________ 18. Minimum rating per burner: _____________ gal/hr 19. Maximum rating per burner: ___________ gal/hr Page 1 of 3 Peak Minerals Inc. Sevier Playa Potash Project July 2023 TBD TBD TBD 15 24 328 x x x x TBD TBD 100 TBD TBD TBD TBD TBD MgCl2 Steam Boiler Page 2 of 3 Form 11 - Natural Gas Boiler and Liquid Heater (Continued) Modifications for Emissions Reduction 20. Type of modification: □ Low NOX Burner □ Flue Gas Recirculation (FGR) □ Oxygen Trim □ Other (specify) ______________________________________ For Low-NOX Burners 21. Burner Type: □ Staged air □ Staged fuel □ Internal flue gas recirculation □ Ceramic □ Other (specify): ___________________________________________________ 22. Manufacturer and Model Number: _______________________________________________________________ 23. Rating: ______________________ 106 BTU/HR 24. Combustion air blower horsepower: ____________ For Flue Gas Recirculation (FGR) 25. Type: □ Induced □ Forced Recirculation fan horsepower: ______________________________________ 26. FGR capacity at full load: scfm %FGR 27. FGR gas temperature or load at which FGR commences: OF % load 28. Where is recirculation flue gas reintroduced? _______________________________________________________ For Oxygen Trim Systems 29. Manufacturer and Model Number: ________________________________________________________________ 30. Recorder: □ yes □ no Describe: ____________________________________________________________ Stack or Vent Data 31. Inside stack diameter or dimensions ____________ Stack height above the ground ________________ Stack height above the building ________________ 32. Gas exit temperature: ___________ OF 33. Stack serves: □ this equipment only, □ other equipment (submit type and rating of all other equipment exhausted through this stack or vent) 34. Stack flow rate: _________________ acfm Vertically restricted? □ Yes □ No Emissions Calculations (PTE) 35. Calculated emissions for this device PM10 ___________Lbs/hr___________ Tons/yr PM2.5 ___________Lbs/hr___________ Tons/yr NOx ___________Lbs/hr ___________Tons/yr SOx ____________Lbs/hr___________ Tons/yr CO ____________Lbs/hr ___________Tons/yr VOC ___________Lbs/hr ___________Tons/yr CO2 ___________ Tons/yr CH4 ___________Tons/yr N2O ___________Tons/yr HAPs_________ Lbs/hr (speciate)__________Tons/yr (speciate) Submit calculations as an appendix. If other pollutants are emitted, include the emissions in the appendix. x x TBD TBD 15 TBD 18 in 50 ft 224 x TBD 8.2 0.034 4.7 0.70 0.44 0.44 Page 3 of 3 Instructions Form 19 – Natural Gas Boiler and Liquid Heater This application form is applicable to natural gas-fired boilers and liquid heaters. Boiler(s) rated for a total of less than five million Btu per hr and fueled by natural gas and one million Btu per hour and fired by fuel oil numbers 1-6 are exempt from filing a Notice of Intent to construct. See Source Category Exemptions R307-401-10 (1) and (2). NOTE: 1. Submit this form in conjunction with Form 1 and Form 2. 2. Call the Division of Air Quality (DAQ) at (801) 536-4000 if you have problems or questions in filling out this form. Ask to speak with a New Source Review engineer. We will be glad to help! 3. Attach specification sheets for all burners, equipment and modifications to boiler. 1. Company name of manufacturer of boiler (specifically the pressure vessel or shell). 2. Manufacturer's model number. 3. Specific identification, serial, number of the boiler. 4. The maximum heat input for which the boiler is rated. Give the value in million British thermal units per hour. 5. The operating schedule for which you want to be permitted. The air quality impact will be evaluated according to this schedule. Note: The approval order will limit operating hours to what you request. 6. Mark the box indicating the purpose of the boiler. 7. Mark all fuels that you wish to be approved to use, also list the backup fuel to be used if any. 8. If a waste stream is burned, answer yes and submit drawings, etc. to characterize the method. 9. Company name of manufacturer of gas burners. If the boiler is a packaged boiler, list the manufacturer of the boiler. 10. How many gas burners will be installed in the boiler? 11. Minimum gas flow rate at which each burner can operate (in cubic feet per hour) 12. The average load at which you plan to operate each burner, compared to the maximum burner rating. 13. Maximum gas flow rate at which each burner can operate (in cubic feet per hour) 14. List the maximum concentration which the manufacturer guarantees the burners will produce in parts per million of Nitrogen Oxides (NOX), Carbon Monoxide (CO), and Total Hydrocarbons. If the percentage of Non-methane hydrocarbons is known, please provide that information. 15. Indicate the method used to control the flame for the burners. 16. Company name of manufacturer of oil burners. If the boiler is a packaged boiler, and has duel fuel capability, list the manufacturer of the boiler. 17. Manufacturer's model, number (quantity), and size of oil burners to be installed in the boiler. 18. Minimum oil flow rate at which each burner can operate (in gallons per hour). 19. Maximum oil flow rate at which each burner can operate (in gallons per hour). 20. Indicate the type of emissions reduction strategy(ies) used in the proposed boiler. 21. Indicate the low-NOX strategy used in the burner design. 22. Company name of manufacturer of the burners. Manufacturer's model number for the burners. 23. The heat input rating of each burner in million British thermal units per hour. 24. In a forced draft design, the horsepower of the fan motor used. 25. Method for delivering the flue gas to the combustion zone. Forced draft indicates the presence of a fan. Give the fan horsepower if so equipped. 26. The amount of flue gas which can be recirculated, in standard cubic feet per minute. And the percentage of the flue gas that can be recirculated at full load. 27. Generally, flue gas recirculation systems start up at a given load or temperature. Give that specification. 28. Where in relation to the burner/combustion zone is the flue gas reintroduced to the boiler? 29. Name of the manufacturer and the model number of the oxygen trim system. 30. Is there a data recorder? If so, describe it: What is recorded? How is it read? 31. Give the inside diameter or the dimensions of the stack. List the stack height above the ground and above the building in which it is located, describe if the gas flow is vertically restricted. This information will be used in modeling the impact of emissions on the ambient air. 32. Give the expected gas exit temperature at the end of the stack. Also to be used in modeling. 33. Indicate if other equipment is also vented to this stack. If other equipment is served by the stack, provide the flow rates, operating parameters, fuel and combustion information that can be used to characterize the total emissions from the stack. 34. Give the gas flow rate out of the stack in actual cubic feet per minute (acfm). 35. Supply calculations for all criteria pollutants, greenhouse gases and HAPs. Use AP42 or Manufacturers’ data to complete your calculations. U:\aq\ENGINEER\GENERIC\Forms 2010\Form19 Natural gas-Fired Boilers and Liquid Heaters.doc Revised 12/20/10 APPENDIX C POTENTIAL EMISSIONS CALCULATIONS PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 Preconcentration Ponds/Trenches/Canals Loader 1 328 10 3,280 10 0.80 0.41 0.12 4.1 1.2 0.66 0.20 Preconcentration Ponds/Trenches/Canals Track dozer 1 328 24 7,872 24 0.80 0.41 0.12 10 3.0 1.6 0.49 Preconcentration Ponds/Trenches/Canals Backhoe 2 200 12 4,800 24 0.80 0.41 0.12 10 3.0 1.0 0.30 Waste Product Storage Loader 1 328 10 3,280 10 0.80 0.41 0.12 4.1 1.2 0.66 0.20 Waste Product Storage Track dozer 1 328 24 7,872 24 0.80 0.41 0.12 10 3.0 1.6 0.49 Production Ponds Grader 1 328 10 3,280 10 0.80 0.41 0.12 4.1 1.2 0.66 0.20 Production Ponds Loader 1 328 10 3,280 10 0.80 0.41 0.12 4.1 1.2 0.66 0.20 All Areas Loader 1 328 10 3,280 10 0.80 0.41 0.12 4.1 1.2 0.66 0.20 All Areas Track dozer 1 328 8.0 2,624 8.0 0.80 0.41 0.12 3.2 1.0 0.53 0.16 All Areas Backhoe 1 328 8.0 2,624 8.0 0.80 0.41 0.12 3.2 1.0 0.53 0.16 All Areas Portable genset5 2 110 12 2,640 24 0.80 000000 All Areas Bobcat 1 200 12 2,400 12 0.80 0.41 0.12 4.9 1.5 0.49 0.149 All Areas Scissor lift5 1 60 12 720 12 0.80 000000 All Areas Portable light tower5 2 328 12 7,872 24 0.80 000000 MgCl2 / Bischofite Process Plant Backhoe 1 328 8.0 2,624 8.0 0.80 0.41 0.12 3.2 1.0 0.53 0.16 Access Road Network Backhoe 1 200 12 2,400 12 0.80 0.41 0.12 4.9 1.5 0.49 0.15 Access Road Network Track dozer 1 328 8.0 2,624 8.0 0.80 0.41 0.12 3.2 1.0 0.53 0.16 Access Road Network Rollers 1 328 12 3,936 12 0.80 0.41 0.12 4.9 1.5 0.80 0.24 Access Road Network Grader 1 328 10 3,280 8.0 0.80 0.41 0.12 3.2 1.0 0.66 0.20 Production Ponds Pumps5 2 150 24 7,200 48 0.80 000000 All Areas Forklifts 2 200 24 9,600 48 0.80 0.41 0.12 19 5.9 1.94 0.59 MgCl2 / Bischofite Process Plant Forklifts 2 200 24 9,600 48 0.80 0.41 0.12 19 5.9 1.94 0.59 Notes: 1. Equipment quantity, operating hours per day, and operating days per year provided by Peak Minerals. References: UDAQ. 2015. January 12. Emissions Factors for Paved and Unpaved Haul Roads. Table 1 Fugitive Dust - Off-road Equipment Peak Minerals Inc. Delta, Utah Area/Activity Equipment Description Equipment Quantity (excluding spares)1 Operating Days/Year1 Maximum Operating Hours/Day1 Maximum Operating Hours per Year Maximum Total Equipment Hours per Day Control Efficiency2 (%) Emission Factors3,4 (lb/hr) Max Daily Emissions (lb/day) Max Annual Emissions (tpy) Mojave Desert Air Quality Management District (MDAQMD). 1999. Emissions Inventory Guidance Mineral Handling and Processing Industries. Available online at: http://www.mdaqmd.ca.gov/home/showdocument?id=768 2. Consistent with the Peak Minerals fugitive dust control plan, brine is approved for fugitive dust control use in all off-road areas on the Playa. Therefore, all activities assume an 80% control efficiency consistent with UDAQ guidance for "chemical suppressants" (brine). 3. Moisture content assumed to be equal to the most conservative moisture content (23%) from onsite sampling conducted by Ramboll. Silt content assumed to be consistent with conservative default from Mojave Desert Air Quality Management District (MDAQMD) guidance (30%) . 4. Fugitive dust emission factors for off-road equipment calculated using MDAQMD Bulldozing, Scraping and Grading of Materials "most complex" methodology from the Emissions Inventory Guidance for Mineral Handling and Processing Industries document, Section VI.D. 5. The portable gensets, scissor lift, and portable light towers are assumed to have no fugitive emissions, as they are portable sources that would be towed when moved. Thus, emissions would be accounted for in the vehicle that transports them. The pumps are also assumed to have no fugitive emissions, as these sources are not mobile and not involved in material handling. PM10 PM2.5 (hrs/day) (days/yr)PM10 PM2.5 PM10 PM2.5 Production Pond Solids Haul Trucks 4-30 59 2.5 0.25 -- -- 328 5.0 33 10,824 165 54,120 Water Tanker Truck 4-30 19 1.5 0.15 1 -- 328 5.0 2.0 656 10 3,280 Brine Tanker Truck 4-30 19 1.5 0.15 -- -- 328 5.0 11 3,608 55 18,040 Production Pond Solids Tandem Dump Trailers (Side Dumping)10 4-30 61 2.6 0.26 5 -- -- -- -- -- -- -- MOP and Granular SOP Haul Trucks 4-30 52 2.4 0.24 -- -- 230 1.0 15 3,450 15 3,450 Water Soluble SOP Flatbed Trucks 4-30 42 2.1 0.21 -- -- 99 1.0 15 1,485 15 1,485 Bischofite (granular MgCl2) Flatbed Trucks 4-30 42 2.1 0.21 -- -- 328 1.0 7.0 2,296 7.0 2,296 Propane Delivery Trucks 4-30 20 1.5 0.15 -- -- 328 1.0 1.0 328 1.0 328 Water Tanker Truck 4-30 19 1.5 0.15 1 -- 328 1.0 2.0 656 2.0 656 MgCl2 Brine Product Truck 4-30 44 2.2 0.22 -- -- 328 1.0 15 4,920 15 4,920 Worker Commute Vehicles11 4-30 2.5 0.61 0.061 -- -- 328 1.0 131 42,968 131 42,968 Production Pond Solids Haul Trucks 4-30 59 2.5 0.25 -- -- 328 0.30 90 29,520 27 8,856 MOP and Granular SOP Haul Trucks 4-30 52 2.4 0.24 -- -- 230 0.87 15 3,450 13 3,002 Water Soluble SOP Flatbed Trucks 4-30 42 2.1 0.21 -- -- 99 1.0 15 1,485 15 1,485 Bischofite (granular MgCl2) Flatbed Trucks 4-30 42 2.1 0.21 -- -- 328 1.0 7.0 2,296 7.0 2,296 Propane Delivery Trucks 4-30 20 1.5 0.15 -- -- 328 0.75 1.0 328 0.75 246 SOP Processing Facility Type 3 Tailings Hauling12 4-30 59 2.5 0.25 -- -- 328 0.30 4.0 1,025 1.2 308 Bischofite Processing Facility Tailings Hauling12 4-30 59 2.5 0.25 -- -- 328 0.30 4.0 238 1.2 71 Water Tanker Truck 4-30 19 1.5 0.15 1 -- 328 1.2 2.0 656 2.4 787 MgCl2 Brine Product Truck 4-30 44 2.2 0.22 -- -- 328 1.2 15 4,920 18 5,904 Fuel Tanker Truck 4-30 3.5 0.70 0.070 -- -- 328 0.75 2.0 656 1.5 492 Flatbed Truck13 4-30 3.5 0.70 0.070 1 6.0 164 -- -- -- 180 29,520 Utility Pontoon 4-30 3.5 0.70 0.070 1 -- 328 40 2.0 656 80 26,240 Fuel Tanker Truck 4-30 3.5 0.70 0.070 1 -- 328 40 2.0 656 80 26,240 Water Tanker Truck 4-30 3.5 0.70 0.070 -- -- 328 40 4.0 1,312 160 52,480 Brine Tanker Truck 4-30 19 1.5 0.15 -- -- 328 40 17 5,576 680 223,040 Welding Trailer14 4-30 3.5 0.70 0.070 -- -- -- -- -- -- -- -- Maintenance Truck13 4-30 3.5 0.70 0.070 1 4.0 46 -- -- -- 120 5,520 Pickup Truck13 4-30 3.5 0.70 0.070 4 4.0 328 -- -- -- 480 157,440 30 3.0 4.0 0.40 85% 30 3.0 4.1 Number of Vehicles6 Table 2 Fugitive Dust - Equipment Travel on Unpaved Roads and Disturbed Areas Peak Minerals Inc. Delta, Utah Ponds Production Ponds Haul Road 4.8 1.377 7.7 13 Maximum Daily Emissions (lb/day) Total Annual Emissions (tpy) 0.41 Control Efficiency9 (%) Area Roadway Maximum Daily Miles Traveled8 Maximum Number of Round Trips per Day6 Operating Schedule6 Round Trip Distance7 (miles) Number of Round Trips per Year Annual Miles Traveled Project YearsEquipment/Activity Description Unpaved Surface Silt Content1 (%) Weighted Average Vehicle Weight2,3,4 (tons) Uncontrolled Emission Factor5 (lb/VMT) 85% Equipment Transport 4.8 All Areas Within Processing Facility Boundary Within Processing Facility Boundary 85% CPM Spur Road CPM Spur Road On-playa Access Road 4.8 4.8 85% 268 27 41 4.1 PM10 PM2.5 (hrs/day) (days/yr)PM10 PM2.5 PM10 PM2.5 Number of Vehicles6 Table 2 Fugitive Dust - Equipment Travel on Unpaved Roads and Disturbed Areas Peak Minerals Inc. Delta, Utah Maximum Daily Emissions (lb/day) Total Annual Emissions (tpy) Control Efficiency9 (%) Area Roadway Maximum Daily Miles Traveled8 Maximum Number of Round Trips per Day6 Operating Schedule6 Round Trip Distance7 (miles) Number of Round Trips per Year Annual Miles Traveled Project YearsEquipment/Activity Description Unpaved Surface Silt Content1 (%) Weighted Average Vehicle Weight2,3,4 (tons) Uncontrolled Emission Factor5 (lb/VMT) Water Tanker Truck 4-30 4.8 19 1.5 0.15 1 -- 328 5.0 2.0 656 10 3,280 SOP Processing Facility Type 3 Tailings Hauling12 4-30 4.8 59 2.5 0.25 -- -- 328 7.7 4.0 1,025 31 7,893 Bischofite Processing Facility Tailings Hauling12 4-30 4.8 59 2.5 0.25 -- -- 328 7.7 4.0 238 31 1,829 Back-mix Tailings Hauling12 4-30 4.8 59 2.5 0.25 -- -- 328 2.0 20 6,625 40 13,250 Brine tanker15 4-30 30 3.5 3.7 0.37 -- -- -- 3.9 1.0 -- 3.9 1,265 80% 2.8 0.28 0.46 0.046 Brine tanker15 4-30 30 3.5 3.7 0.37 -- -- -- 1.5 1.0 -- 1.5 495 80% 1.1 0.11 0.18 0.018 Flatbed Truck 4-30 4.8 3.5 0.70 0.070 -- -- 164 40 1.0 164 40 6,560 85% 4.2 0.42 0.35 0.035 Water Tanker Truck 4-30 4.8 3.5 0.70 0.070 -- -- 328 40 1.0 328 40 13,120 85% 4.2 0.42 0.69 0.069 Preconstruction Ponds/Trenches /Canals Preconstruction Ponds/Trenches/ Canals Pickup Truck 4-30 4.8 3.5 0.70 0.070 -- -- 328 40 2.0 656 80 26,240 85% 8.5 0.85 1.4 0.14 Notes: References: CalEEMod. 2022. CalEEMod User's Guide. Available online at: https://caleemod.com/user-guide. June. EPA. 2006. AP-42, Section 13.2.2, Unpaved Roads. Available online at: https://www3.epa.gov/ttnchie1/ap42/ch13/final/c13s0202.pdf. November. Novopro. 2022. Feasibility Report for the Sevier Playa Potash Project. September. UDAQ. 2015. Emissions Factors for Paved and Unpaved Haul Roads. January 12. Available online at: https://documents.deq.utah.gov/air-quality/permitting/operating-permits/DAQ-2017-006548.pdf 2. Vehicle and load weights were provided by Peak Minerals. 4. Propane delivery vehicle weight assumed to be 20 tons, consistent with CalEEMod default for haul trucks. 6. Equipment specific information provided by Peak Minerals. 5. Unpaved road fugitive dust emission factors calculated based on AP-42, Section 13.2.2 unpaved roads methodology for industrial sites (EPA 2006). Access Road Network Operational Disturbed Areas (on- playa) Operational Disturbed Area (Production Ponds) Offsite Unpaved Roads 4.1 4.7 0.47 Tailings Facility Haul Road 85% 41 Mojave Desert Air Quality Management District. 1999. Emissions Inventory Guidance Mineral Handling and Processing Industries. Available online at: http://www.mdaqmd.ca.gov/home/showdocument?id=768 10. Tandem dump trailers are assumed to be included as part of the hauling trip for those trailers so emissions are zeroed out for fugitive dust. 14. The welding trailers are assumed to have no fugitive emissions, as they are portable sources that would be towed when moved. Thus, emissions would be accounted for in the vehicle that transports them. 15. Round trip distances for brine tanker trucks operating on operational disturbed areas were estimated assuming the operational area disturbed each day is traversed by a brine tanker with a travel width of 3 meters. 7. Round trip distances were provided by Peak Minerals. 12. SOP processing facility, Bischofite processing facility, and back-mix pond tailings haul trip counts are back calculated assuming 82,000, 19,000, and 530,000 tons of tailings will be produced per year, respectively, and an assumption that the tailings haul trucks carry 80 tons. 13. On-playa Access Road flatbed trucks, maintenance vehicles, and pickup trucks were assumed to be traveling at 30 mph for all operational hours specified by Peak Minerals. 11. Worker commute vehicle daily trip rates based on Peak Minerals guidance. Access Road Network 3. Weights of vehicles used to carry loads are based on round trip averages (i.e. loaded one direction, unloaded another). MOP and Granular SOP Haul Trucks are assumed to be loaded in both directions. 8. Maximum daily miles traveled calculated based on round trip distances and maximum number of round trips per day or number of vehicles, hours per day of operation, and an assumed vehicle speed of 30 mph. 9. Unpaved road fugitive dust emissions on all unpaved roads assumed to be controlled using chemical suppressants (magnesium chloride) and watering (85% control efficiency consistent with UDAQ guidance). Consistent with the Peak Minerals fugitive dust control plan, brine is approved for fugitive dust control use in all off-road areas on the Playa. Therefore, all operational disturbed area activities assume an 80% control efficiency consistent with UDAQ guidance for "chemical suppressants" (brine). 1. Unpaved surface silt content on unpaved roads assumed to be 4.8% consistent with UDAQ's default silt content recommendation as outlined in UDAQ's 2015 Emission Factors for Paved and Unpaved Haul Roads guidance. Disturbed area silt content assumed to be 30% consistent with conservative default from MDAQMD guidance. TSP PM10 PM2.5 TSP PM10 PM2.5 Operational Disturbed Areas (on-playa)1 4.6 80% 576 288 115 14 7.1 2.9 Operational Disturbed Area (Production Ponds)1 1.8 80% 225 113 45 5.6 2.8 1.1 Notes: References: Dregger. 2005. The Wind Investigator: How to Approximate Wind Velocities at Roof Level. October. Fouad and Calvert. 2002. Wind Load Provisions in the 2001 Supports Specification. November. UDAQ. 2015. January 12. Emissions Factors for Paved and Unpaved Haul Roads. MDAQMD. 1999. Emissions Inventory Guidance Section VI.L. Wind Erosion from Unpaved Operational Areas and Roads. Available online at: http://www.mdaqmd.ca.gov/home/showdocument?id=768 4. Emissions estimated using the most complex Wind Erosion from Unpaved Operational Areas and Roads methodology in MDAQMD Emissions Inventory Guidance, Section VI.L. Threshold friction velocity selected from the MDAQMD guidance based on an area use of "disturbed desert". 1. Windblown dust from disturbed areas assumed to be a "limited" reservoir consistent with MDAQMD definitions due to the significant crusting that occurs on the playa (observed during Ramboll site visit). 2. Maximum daily disturbed areas estimated assuming a maximum disturbed area of 4.6 acres for on-playa activities and a maximum disturbed area of 1.8 acres for activities at the production ponds (per Peak Minerals guidance, provided on May 1, 2023). 5. The maximum daily windspeeds required for input into the MDAQMD equation were assumed to be the "fastest mile" windspeed from each day (consistent with AP-42 Section 13.2.5 guidance, which the MDAQMD equation is based on). The fastest mile wind speeds were calculated using hourly site-specific meteorological data from 12/1/2011 through 11/30/2012 by scaling up the maximum hourly average wind speed to a fastest mile windspeed using the equation: u+ = 1.52u/1.2 Where: u+ = fastest mile wind speed, and u = hourly mean wind speed. This empirical relationship is based on a conversion of the hourly average wind speed to a 3second gust wind speed with the coefficient 1.52 (Dregger 2005), then a conversion of the 3second gust windspeed to a fastest mile of wind with the coefficient 1/1.2 (Fouad and Calvert 2002). Any hours with missing wind speed data were conservatively assumed to have winds equivalent to the annual average hourly wind speed. 3. Consistent with the Peak Minerals fugitive dust control plan, brine is approved for fugitive dust control use in all off-road areas on the Playa. Thus, any on-Playa disturbed areas assume an 80% control efficiency consistent with UDAQ guidance for "chemical suppressants" (brine). Daily Emissions (lb/day) EPA. 2006. AP-42, Section 13.2.5, Industrial Wind Erosion. Available online at: https://www3.epa.gov/ttnchie1/ap42/ch13/final/c13s0205.pdf. November. Table 3a Fugitive Dust - Windblown Dust Peak Minerals Inc. Delta, Utah Source Name Maximum Daily Disturbed Area2 (acres) Control Efficiency3 Annual Emissions4,5 (tpy) (m/s) (mph) TSP PM10 PM2.5 1 3.6 8.1 4.6 0.24 0 00 2 3.6 8.1 4.6 0.24 0 00 3 3.6 8.1 4.6 0.24 0 00 4 3.6 8.1 4.6 0.24 0 00 5 3.6 8.1 4.6 0.24 0 00 6 3.6 8.1 4.6 0.24 0 00 7 3.6 8.1 4.6 0.24 0 00 8 2.4 5.4 3.0 0.16 0 00 9 2.2 4.9 2.8 0.15 0 00 10 1.6 3.6 2.0 0.11 0 00 11 1.4 3.1 1.8 0.094 0 00 12 1.8 4.0 2.3 0.12 0 00 13 2.5 5.6 3.2 0.17 0 00 14 3.5 7.8 4.4 0.23 0 00 15 4.2 9.4 5.3 0.28 0 00 16 4.3 10 5.4 0.29 0 00 17 2.4 5.4 3.0 0.16 0 00 18 4.5 10 5.7 0.30 0 00 19 4.4 10 5.6 0.30 0 00 20 3.0 6.7 3.8 0.20 0 00 21 5.0 11 6.3 0.34 6.4E-04 3.2E-04 1.3E-04 22 9.4 21 12 0.63 0.057 0.029 0.011 23 2.5 5.6 3.2 0.17 0 00 24 1.7 3.8 2.2 0.11 0 00 25 1.8 4.0 2.3 0.12 0 00 26 3.8 8.5 4.8 0.26 0 00 27 3.2 7.2 4.1 0.21 0 00 28 2.9 6.5 3.7 0.19 0 00 29 3.5 7.8 4.4 0.23 0 00 30 7.2 16 9.1 0.48 0.023 0.012 0.0046 31 8.6 19 11 0.58 0.043 0.022 0.0087 32 1.9 4.3 2.4 0.13 0 00 33 2.7 6.0 3.4 0.18 0 00 34 2.4 5.4 3.0 0.16 0 00 35 2.0 4.5 2.5 0.13 0 00 36 3.3 7.4 4.2 0.22 0 00 37 3.1 6.9 3.9 0.21 0 00 38 5.4 12 6.8 0.36 0.0039 0.0020 7.8E-04 39 2.1 4.7 2.7 0.14 0 00 40 2.0 4.5 2.5 0.13 0 00 41 2.8 6.3 3.5 0.19 0 00 42 4.3 10 5.4 0.29 0 00 43 3.1 6.9 3.9 0.21 0 00 44 2.9 6.5 3.7 0.19 0 00 45 2.3 5.1 2.9 0.15 0 00 46 12 26 15 0.77 0.10 0.050 0.020 47 15 34 19 1.0 0.20 0.10 0.040 48 2.8 6.3 3.5 0.19 0 00 49 7.0 16 8.9 0.47 0.021 0.010 0.0041 50 7.1 16 9.0 0.48 0.022 0.011 0.0044 51 6.4 14 8.1 0.43 0.014 0.0068 0.0027 52 18 41 23 1.2 0.31 0.16 0.063 53 4.5 10 5.7 0.30 0 00 54 10 21 12 0.64 0.059 0.029 0.012 55 6.5 15 8.2 0.44 0.015 0.0074 0.0030 56 4.4 10 5.6 0.30 0 00 57 11 24 14 0.73 0.087 0.043 0.017 58 8.0 18 10 0.54 0.034 0.017 0.0068 59 3.0 6.7 3.8 0.20 0 00 60 2.9 6.5 3.7 0.19 0 00 61 3.1 6.9 3.9 0.21 0 00 62 3.6 8.1 4.6 0.24 0 00 63 6.7 15 8.5 0.45 0.017 0.0085 0.0034 64 8.2 18 10 0.55 0.037 0.019 0.0074 65 4.4 10 5.6 0.30 0 00 66 5.4 12 6.8 0.36 0.0039 0.0020 7.8E-04 67 3.6 8.1 4.6 0.24 0 00 68 3.7 8.3 4.7 0.25 0 00 69 2.9 6.5 3.7 0.19 0 00 70 4.3 10 5.4 0.29 0 00 71 3.1 6.9 3.9 0.21 0 00 72 3.8 8.5 4.8 0.26 0 00 73 8.0 18 10 0.54 0.034 0.017 0.0068 74 5.0 11 6.3 0.34 6.4E-04 3.2E-04 1.3E-04 75 4.3 10 5.4 0.29 0 00 76 3.2 7.2 4.1 0.21 0 00 77 4.6 10 5.8 0.31 0 00 78 5.7 13 7.2 0.38 0.0066 0.0033 0.0013 79 3.8 8.5 4.8 0.26 0 00 80 3.6 8.1 4.6 0.24 0 00 81 8.1 18 10 0.54 0.036 0.018 0.0071 82 3.8 8.5 4.8 0.26 0 00 83 2.4 5.4 3.0 0.16 0 00 84 6.2 14 7.9 0.42 0.012 0.0058 0.0023 85 12 26 15 0.79 0.11 0.053 0.021 86 2.8 6.3 3.5 0.19 0 00 87 11 25 14 0.75 0.091 0.045 0.018 88 3.7 8.3 4.7 0.25 0 00 89 12 28 16 0.83 0.12 0.059 0.024 90 9.4 21 12 0.63 0.057 0.029 0.011 91 12 27 15 0.81 0.11 0.056 0.022 92 9.0 20 11 0.60 0.050 0.025 0.010 93 8.1 18 10 0.54 0.036 0.018 0.0071 94 3.6 8.1 4.6 0.24 0 00 95 4.0 8.9 5.1 0.27 0 00 96 7.4 17 9.4 0.50 0.026 0.013 0.0052 97 15 33 19 1.0 0.18 0.092 0.037 98 7.9 18 10 0.53 0.033 0.016 0.0065 99 5.1 11 6.5 0.34 0.0014 7.1E-04 2.8E-04 100 2.4 5.4 3.0 0.16 0 00 101 3.5 7.8 4.4 0.23 0 00 102 6.8 15 8.6 0.46 0.018 0.0091 0.0037 103 10 22 12 0.66 0.064 0.032 0.013 Table 3b Fugitive Dust - Windblown Dust Detailed Calculations Summary Peak Minerals Inc. Delta, Utah Maximum Daily Average Hourly Wind Speed Daily Fastest Mile Wind Speed (u+) (m/s) Maximum Daily Friction Velocity (ui) (m/s) Daily Emission Factor (tons/acre)Day (m/s) (mph) TSP PM10 PM2.5 Table 3b Fugitive Dust - Windblown Dust Detailed Calculations Summary Peak Minerals Inc. Delta, Utah Maximum Daily Average Hourly Wind Speed Daily Fastest Mile Wind Speed (u+) (m/s) Maximum Daily Friction Velocity (ui) (m/s) Daily Emission Factor (tons/acre)Day 104 11 24 14 0.73 0.084 0.042 0.017 105 8.1 18 10 0.54 0.036 0.018 0.0071 106 6.6 15 8.4 0.44 0.016 0.0080 0.0032 107 11 23 13 0.70 0.078 0.039 0.016 108 15 34 19 1.0 0.20 0.10 0.041 109 14 31 18 0.93 0.16 0.081 0.032 110 6.1 14 7.7 0.41 0.011 0.0053 0.0021 111 2.9 6.5 3.7 0.19 0 00 112 3.6 8.1 4.6 0.24 0 00 113 6.5 15 8.2 0.44 0.015 0.0074 0.0030 114 11 24 14 0.73 0.084 0.042 0.017 115 8.9 20 11 0.60 0.048 0.024 0.010 116 13 29 16 0.87 0.13 0.067 0.027 117 15 33 18 1.0 0.18 0.091 0.036 118 10 23 13 0.68 0.072 0.036 0.014 119 10 23 13 0.68 0.070 0.035 0.014 120 5.7 13 7.2 0.38 0.0066 0.0033 0.0013 121 5.4 12 6.8 0.36 0.0039 0.0020 7.8E-04 122 16 37 21 1.1 0.24 0.12 0.048 123 14 31 17 0.93 0.16 0.079 0.032 124 12 26 15 0.78 0.10 0.051 0.020 125 3.4 7.6 4.3 0.23 0 00 126 12 28 16 0.83 0.12 0.061 0.024 127 15 34 19 1.0 0.20 0.10 0.039 128 10 22 12 0.66 0.064 0.032 0.013 129 3.7 8.3 4.7 0.25 0 00 130 5.5 12 7.0 0.37 0.0048 0.0024 0.0010 131 7.8 17 10 0.52 0.031 0.016 0.0063 132 11 24 13 0.71 0.080 0.040 0.016 133 15 33 19 1.0 0.19 0.10 0.038 134 10 23 13 0.68 0.070 0.035 0.014 135 10 22 12 0.65 0.063 0.031 0.013 136 8.4 19 11 0.56 0.040 0.020 0.0081 137 5.7 13 7.2 0.38 0.0066 0.0033 0.0013 138 6.5 15 8.2 0.44 0.015 0.0074 0.0030 139 5.0 11 6.3 0.34 6.4E-04 3.2E-04 1.3E-04 140 7.9 18 10 0.53 0.033 0.016 0.0065 141 5.8 13 7.3 0.39 0.0075 0.0038 0.0015 142 4.8 11 6.1 0.32 0 00 143 4.5 10 5.7 0.30 0 00 144 5.6 13 7.1 0.38 0.0057 0.0028 0.0011 145 8.2 18 10 0.55 0.037 0.019 0.0074 146 7.9 18 10 0.53 0.033 0.016 0.0065 147 13 28 16 0.85 0.13 0.063 0.025 148 13 29 16 0.86 0.13 0.066 0.026 149 8.1 18 10 0.54 0.036 0.018 0.0071 150 7.7 17 10 0.52 0.030 0.015 0.0060 151 4.3 10 5.4 0.29 0 00 152 11 25 14 0.76 0.10 0.048 0.019 153 13 30 17 0.90 0.15 0.074 0.029 154 12 27 15 0.81 0.11 0.056 0.022 155 12 26 15 0.78 0.10 0.051 0.020 156 10 21 12 0.64 0.059 0.029 0.012 157 11 25 14 0.74 0.089 0.044 0.018 158 8.5 19 11 0.57 0.042 0.021 0.0084 159 11 24 14 0.72 0.082 0.041 0.016 160 7.1 16 9.0 0.48 0.022 0.011 0.0044 161 5.6 13 7.1 0.38 0.0057 0.0028 0.0011 162 14 32 18 1.0 0.17 0.085 0.034 163 7.4 17 9.4 0.50 0.026 0.013 0.0052 164 4.9 11 6.2 0.33 0 00 165 6.9 15 8.7 0.46 0.019 0.010 0.0039 166 5.6 13 7.1 0.38 0.0057 0.0028 0.0011 167 8.6 19 11 0.58 0.043 0.022 0.0087 168 4.6 10 5.8 0.31 0 00 169 14 31 18 0.94 0.16 0.082 0.033 170 12 28 16 0.83 0.12 0.059 0.024 171 3.9 8.7 4.9 0.26 0 00 172 4.6 10 5.8 0.31 0 00 173 9.4 21 12 0.63 0.057 0.029 0.011 174 10 23 13 0.68 0.070 0.035 0.014 175 10 23 13 0.70 0.076 0.038 0.015 176 10 23 13 0.69 0.074 0.037 0.015 177 18 39 22 1.2 0.28 0.14 0.057 178 16 35 20 1.1 0.22 0.11 0.043 179 7.1 16 9.0 0.48 0.022 0.011 0.0044 180 5.3 12 6.7 0.36 0.0031 0.0015 6.1E-04 181 6.0 13 7.6 0.40 0.0095 0.0047 0.0019 182 6.4 14 8.1 0.43 0.014 0.0068 0.0027 183 7.0 16 8.9 0.47 0.021 0.010 0.0041 184 5.4 12 6.8 0.36 0.0039 0.0020 7.8E-04 185 10 23 13 0.68 0.072 0.036 0.014 186 8.4 19 11 0.56 0.040 0.020 0.0081 187 12 26 15 0.78 0.10 0.051 0.020 188 16 35 20 1.1 0.22 0.11 0.043 189 8.3 19 11 0.56 0.039 0.019 0.0077 190 3.6 8.1 4.6 0.24 0 00 191 12 28 16 0.83 0.12 0.059 0.024 192 18 40 23 1.2 0.29 0.15 0.058 193 6.4 14 8.1 0.43 0.014 0.0068 0.0027 194 4.5 10 5.7 0.30 0 00 195 6.7 15 8.5 0.45 0.017 0.0085 0.0034 196 7.8 17 10 0.52 0.031 0.016 0.0063 197 5.0 11 6.3 0.34 6.4E-04 3.2E-04 1.3E-04 198 14 30 17 0.91 0.15 0.075 0.030 199 5.6 13 7.1 0.38 0.0057 0.0028 0.0011 200 10 22 12 0.65 0.063 0.031 0.013 201 12 26 15 0.79 0.11 0.053 0.021 202 13 29 16 0.87 0.13 0.067 0.027 203 8.8 20 11 0.59 0.047 0.023 0.0093 204 10 23 13 0.68 0.070 0.035 0.014 205 13 29 16 0.87 0.13 0.067 0.027 206 13 28 16 0.85 0.13 0.064 0.026 (m/s) (mph) TSP PM10 PM2.5 Table 3b Fugitive Dust - Windblown Dust Detailed Calculations Summary Peak Minerals Inc. Delta, Utah Maximum Daily Average Hourly Wind Speed Daily Fastest Mile Wind Speed (u+) (m/s) Maximum Daily Friction Velocity (ui) (m/s) Daily Emission Factor (tons/acre)Day 207 13 28 16 0.85 0.13 0.063 0.025 208 14 31 17 0.93 0.16 0.079 0.032 209 13 28 16 0.84 0.12 0.062 0.025 210 11 23 13 0.70 0.078 0.039 0.016 211 12 26 15 0.79 0.11 0.053 0.021 212 11 24 13 0.71 0.080 0.040 0.016 213 8.5 19 11 0.57 0.042 0.021 0.0084 214 11 25 14 0.74 0.089 0.044 0.018 215 7.5 17 10 0.50 0.027 0.014 0.0054 216 8.6 19 11 0.58 0.043 0.022 0.0087 217 8.6 19 11 0.58 0.043 0.022 0.0087 218 8.5 19 11 0.57 0.042 0.021 0.0084 219 6.0 13 7.6 0.40 0.0095 0.0047 0.0019 220 5.6 13 7.1 0.38 0.0057 0.0028 0.0011 221 6.1 14 7.7 0.41 0.011 0.0053 0.0021 222 4.6 10 5.8 0.31 0 00 223 6.4 14 8.1 0.43 0.014 0.0068 0.0027 224 11 23 13 0.70 0.078 0.039 0.016 225 12 26 15 0.78 0.10 0.051 0.020 226 14 31 18 0.93 0.16 0.081 0.032 227 8.7 19 11 0.58 0.045 0.023 0.0090 228 10 23 13 0.68 0.070 0.035 0.014 229 11 24 14 0.72 0.082 0.041 0.016 230 11 23 13 0.70 0.078 0.039 0.016 231 8.0 18 10 0.54 0.034 0.017 0.0068 232 8.1 18 10 0.54 0.036 0.018 0.0071 233 5.1 11 6.5 0.34 0.0014 7.1E-04 2.8E-04 234 10 23 13 0.68 0.072 0.036 0.014 235 11 25 14 0.76 0.10 0.048 0.019 236 8.6 19 11 0.58 0.043 0.022 0.0087 237 14 31 17 0.92 0.16 0.078 0.031 238 3.8 8.5 4.8 0.26 0 00 239 8.5 19 11 0.57 0.042 0.021 0.0084 240 10 21 12 0.64 0.059 0.029 0.012 241 9.0 20 11 0.60 0.050 0.025 0.010 242 12 27 15 0.81 0.11 0.056 0.022 243 14 32 18 1.0 0.17 0.086 0.035 244 9.4 21 12 0.63 0.057 0.029 0.011 245 7.1 16 9.0 0.48 0.022 0.011 0.0044 246 5.6 13 7.1 0.38 0.0057 0.0028 0.0011 247 5.0 11 6.3 0.34 6.4E-04 3.2E-04 1.3E-04 248 12 26 15 0.78 0.10 0.051 0.020 249 11 25 14 0.74 0.089 0.044 0.018 250 8.2 18 10 0.55 0.037 0.019 0.0074 251 8.0 18 10 0.54 0.034 0.017 0.0068 252 8.7 19 11 0.58 0.045 0.023 0.0090 253 7.6 17 10 0.51 0.029 0.014 0.0057 254 10 22 12 0.65 0.063 0.031 0.013 255 8.8 20 11 0.59 0.047 0.023 0.0093 256 6.3 14 8.0 0.42 0.013 0.0063 0.0025 257 12 27 15 0.82 0.12 0.058 0.023 258 3.9 8.7 4.9 0.26 0 00 259 7.6 17 10 0.51 0.029 0.014 0.0057 260 6.1 14 7.7 0.41 0.011 0.0053 0.0021 261 10 23 13 0.68 0.072 0.036 0.014 262 4.4 10 5.6 0.30 0 00 263 11 24 13 0.71 0.080 0.040 0.016 264 8.4 19 11 0.56 0.040 0.020 0.0081 265 12 28 16 0.83 0.12 0.061 0.024 266 8.2 18 10 0.55 0.037 0.019 0.0074 267 4.6 10 5.8 0.31 0 00 268 8.3 19 11 0.56 0.039 0.019 0.0077 269 8.5 19 11 0.57 0.042 0.021 0.0084 270 10 22 12 0.65 0.063 0.031 0.013 271 8.7 19 11 0.58 0.045 0.023 0.0090 272 8.6 19 11 0.58 0.043 0.022 0.0087 273 8.0 18 10 0.54 0.034 0.017 0.0068 274 11 24 14 0.73 0.084 0.042 0.017 275 7.7 17 10 0.52 0.030 0.015 0.0060 276 8.9 20 11 0.60 0.048 0.024 0.010 277 6.0 13 7.6 0.40 0.0095 0.0047 0.0019 278 8.1 18 10 0.54 0.036 0.018 0.0071 279 7.8 17 10 0.52 0.031 0.016 0.0063 280 7.5 17 10 0.50 0.027 0.014 0.0054 281 10 22 13 0.66 0.066 0.033 0.013 282 7.6 17 10 0.51 0.029 0.014 0.0057 283 5.3 12 6.7 0.36 0.0031 0.0015 6.1E-04 284 7.0 16 8.9 0.47 0.021 0.010 0.0041 285 8.8 20 11 0.59 0.047 0.023 0.0093 286 9.3 21 12 0.62 0.055 0.028 0.011 287 8.4 19 11 0.56 0.040 0.020 0.0081 288 4.8 11 6.1 0.32 0 00 289 4.0 8.9 5.1 0.27 0 00 290 5.4 12 6.8 0.36 0.0039 0.0020 7.8E-04 291 5.3 12 6.7 0.36 0.0031 0.0015 6.1E-04 292 6.2 14 7.9 0.42 0.012 0.0058 0.0023 293 4.1 9.2 5.2 0.28 0 00 294 3.5 7.8 4.4 0.23 0 00 295 4.0 8.9 5.1 0.27 0 00 296 4.9 11 6.2 0.33 0 00 297 5.6 13 7.1 0.38 0.0057 0.0028 0.0011 298 10 22 13 0.66 0.066 0.033 0.013 299 9.1 20 12 0.61 0.052 0.026 0.010 300 4.5 10 5.7 0.30 0 00 301 3.2 7.2 4.1 0.21 0 00 302 3.7 8.3 4.7 0.25 0 00 303 4.6 10 5.8 0.31 0 00 304 4.3 10 5.4 0.29 0 00 305 3.6 8.1 4.6 0.24 0 00 306 3.6 8.1 4.6 0.24 0 00 307 4.1 9.2 5.2 0.28 0 00 308 10 21 12 0.64 0.059 0.029 0.012 309 4.1 9.2 5.2 0.28 0 00 (m/s) (mph) TSP PM10 PM2.5 Table 3b Fugitive Dust - Windblown Dust Detailed Calculations Summary Peak Minerals Inc. Delta, Utah Maximum Daily Average Hourly Wind Speed Daily Fastest Mile Wind Speed (u+) (m/s) Maximum Daily Friction Velocity (ui) (m/s) Daily Emission Factor (tons/acre)Day 310 7.0 16 8.9 0.47 0.021 0.010 0.0041 311 6.7 15 8.5 0.45 0.017 0.0085 0.0034 312 3.3 7.4 4.2 0.22 0 00 313 6.0 13 7.6 0.40 0.0095 0.0047 0.0019 314 4.3 10 5.4 0.29 0 00 315 8.5 19 11 0.57 0.042 0.021 0.0084 316 8.3 19 11 0.56 0.039 0.019 0.0077 317 5.4 12 6.8 0.36 0.0039 0.0020 7.8E-04 318 4.6 10 5.8 0.31 0 00 319 3.4 7.6 4.3 0.23 0 00 320 3.2 7.2 4.1 0.21 0 00 321 8.3 19 11 0.56 0.039 0.019 0.0077 322 5.9 13 7.5 0.40 0.0085 0.0043 0.0017 323 3.9 8.7 4.9 0.26 0 00 324 3.6 8.1 4.6 0.24 0 00 325 9.1 20 12 0.61 0.052 0.026 0.010 326 11 24 13 0.71 0.080 0.040 0.016 327 18 39 22 1.2 0.28 0.14 0.057 328 16 37 21 1.1 0.24 0.12 0.048 329 8.6 19 11 0.58 0.043 0.022 0.0087 (m/s) (mph) TSP PM10 PM2.5 Table 3b Fugitive Dust - Windblown Dust Detailed Calculations Summary Peak Minerals Inc. Delta, Utah Maximum Daily Average Hourly Wind Speed Daily Fastest Mile Wind Speed (u+) (m/s) Maximum Daily Friction Velocity (ui) (m/s) Daily Emission Factor (tons/acre)Day 330 7.6 17 10 0.51 0.029 0.014 0.0057 331 3.2 7.2 4.1 0.21 0 00 332 2.4 5.4 3.0 0.16 0 00 333 2.7 6.0 3.4 0.18 0 00 334 4.5 10 5.7 0.30 0 00 335 3.4 7.6 4.3 0.23 0 00 336 7.5 17 10 0.50 0.027 0.014 0.0054 337 7.9 18 10 0.53 0.033 0.016 0.0065 338 3.9 8.7 4.9 0.26 0 00 339 2.9 6.5 3.7 0.19 0 00 340 3.2 7.2 4.1 0.21 0 00 341 3.6 8.1 4.6 0.24 0 00 342 2.3 5.1 2.9 0.15 0 00 343 6.5 15 8.2 0.44 0.015 0.0074 0.0030 344 16 36 21 1.1 0.24 0.12 0.047 345 17 38 22 1.1 0.26 0.13 0.053 346 4.7 11 6.0 0.32 0 00 347 5.4 12 6.8 0.36 0.0039 0.0020 7.8E-04 348 2.7 6.0 3.4 0.18 0 00 349 2.2 4.9 2.8 0.15 0 00 350 2.7 6.0 3.4 0.18 0 00 351 2.5 5.6 3.2 0.17 0 00 352 8.2 18 10 0.55 0.037 0.019 0.0074 353 10 23 13 0.70 0.076 0.038 0.015 354 8.8 20 11 0.59 0.047 0.023 0.0093 355 5.7 13 7.2 0.38 0.0066 0.0033 0.0013 356 7.2 16 9.1 0.48 0.023 0.012 0.0046 357 6.6 15 8.4 0.44 0.016 0.0080 0.0032 358 6.5 15 8.2 0.44 0.015 0.0074 0.0030 359 2.7 6.0 3.4 0.18 0 00 360 3.0 6.7 3.8 0.20 0 00 361 6.0 13 7.6 0.40 0.0095 0.0047 0.0019 362 2.9 6.5 3.7 0.19 0 00 363 2.7 6.0 3.4 0.18 0 00 364 12 26 15 0.77 0.10 0.050 0.020 365 10 23 13 0.70 0.076 0.038 0.015 366 11 25 14 0.75 0.091 0.045 0.018 Notes: References: EPA. 2006. AP-42, Section 13.2.5, Industrial Wind Erosion. Available online at: https://www3.epa.gov/ttnchie1/ap42/ch13/final/c13s0205.pdf. November. MDAQMD. 1999. Emissions Inventory Guidance Section VI.L. Wind Erosion from Unpaved Operational Areas and Roads. Available online at: http://www.mdaqmd.ca.gov/home/showdocument?id=768 1. The maximum daily windspeeds required for input into the MDAQMD equation were assumed to be the "fastest mile" windspeed from each day (consistent with AP-42 Section 13.2.5 guidance, which the MDAQMD equation is based on). The fastest mile wind speeds were calculated using hourly site-specific meteorological data from 12/1/2011 through 11/30/2012 by scaling up the maximum hourly average wind speed to a fastest mile windspeed using the equation: u+ = 1.52u/1.2 Where: u+ = fastest mile wind speed, and u = hourly mean wind speed. This empirical relationship is based on a conversion of the hourly average wind speed to a 3second gust wind speed with the coefficient 1.52 (Dregger 2005), then a conversion of the 3second gust windspeed to a fastest mile of wind with the coefficient 1/1.2 (Fouad and Calvert 2002). Any hours with missing wind speed data were conservatively assumed to have winds equivalent to the annual average maximum hourly wind speed. Dregger. 2005. The Wind Investigator: How to Approximate Wind Velocities at Roof Level. October. Fouad and Calvert. 2002. Wind Load Provisions in the 2001 Supports Specification. November. NOx SOx CO VOC PM10 PM2.5 CO2 CH4 N2ONOx SOx CO VOC PM10 PM2.5 NOx SOx CO VOC PM10 PM2.5 Generator Set 1 1 Tier 4 53 Diesel 1-2 365 24 3.3 0.0054 3.7 0.19 0.022 0.022 590 0.0028 0.027 9 0.015 10 0.5 0.06 0.06 1.7 0.003 1.9 0.10 0.011 0.011 Generator Set 2 1 Tier 4 53 Diesel 1-2 365 24 3.3 0.0054 3.7 0.19 0.022 0.022 590 0.0028 0.027 9 0.015 10 0.5 0.06 0.06 1.7 0.003 1.9 0.10 0.011 0.011 Generator Set 3 1 Tier 4 53 Diesel 1-2 365 24 3.3 0.0054 3.7 0.19 0.022 0.022 590 0.0028 0.027 9 0.015 10 0.5 0.06 0.06 1.7 0.003 1.9 0.10 0.011 0.011 Generator Set 4 1 Tier 4 139 Diesel 1-2 365 24 0.30 0.0035 3.7 0.15 0.015 0.014 531 0.0023 0.025 2.2 0.026 27 1.1 0.11 0.11 0.40 0.0047 5.0 0.20 0.020 0.019 Generator Set 5 1 Tier 4 59 Diesel 1-2 152 24 3.3 0.0054 3.7 0.19 0.022 0.022 590 0.0028 0.027 10 0.017 12 0.6 0.07 0.07 0.8 0.0013 0.9 0.044 0.005 0.005 Generator Set 6 1 Tier 4 59 Diesel 1-2 152 24 3.3 0.0054 3.7 0.19 0.022 0.022 590 0.0028 0.027 10 0.017 12 0.6 0.07 0.07 0.8 0.0013 0.9 0.044 0.005 0.005 Generator Set 7 1 Tier 4 111 Diesel 2 152 24 0.30 0.0035 3.7 0.15 0.015 0.014 531 0.0023 0.025 2 0.02 22 0.9 0.09 0.08 0.13 0.0016 1.7 0.07 0.007 0.006 Generator Set 8 1 Tier 4 78 Diesel 2 152 24 0.30 0.0039 3.7 0.15 0.015 0.014 590 0.0023 0.027 1.2 0.016 15 0.6 0.06 0.06 0.09 0.0012 1.2 0.05 0.0047 0.0045 Notes: References: EPA 2018. Diesel Fuel Standards and Rulemakings. Available online at: https://www.epa.gov/diesel-fuel-standards/diesel-fuel-standards-and-rulemakings Table 4 Exhaust - Generator Sets for Pumps Peak Minerals Inc. Delta, Utah Project Years of Operation Operating Days per Year Operating Hours per Day Equipment Description Equipment Quantity Engine Tier Level Engine (hp) Fuel Type Criteria Air Pollutants and Greenhouse Gas Emissions 4. Total GHG (CO2e) emissions calculated based on CO 2, CH4, and N2O emission factors along with global warming potentials from 40 CFR Part 98, Table A-1. 2. CO2 emission factors are based on MOVES-NONROAD methodology with default BSFC-based or operator provided fuel consumption estimates. CH 4 emission factors are based on VOC emission factors and MOVES-NONROAD hydrocarbon conversions (EPA 2010). N 2O emission factors are based on g/kg factor from the latest EPA GHG sinks inventory (EPA 2018) and default BSFC-based or operator provided fuel consumption estimates. Annual Emissions3 (tpy) 1. Criteria pollutant emission factors for off-road equipment are based on EPA tiered emission limits. Diesel fuel assumed to have 15 ppm of sulfur consistent with Ultra Low Sulfur Diesel (ULSD) EPA standards (EPA 2018). VOC emission factors were developed based on Tier 4 Non-Methane Hydrocarbon (NMHC) emission standards. If an emission standard was specified as NMHC+NOx, it was assumed 5% of NMHC+NOx emissions were NMHC. Per the EPA NONROAD model, a VOC to NMHC ratio of 1.07 was assumed. Emission Factors1,2 (g/hp-hr) Daily Emissions3 (lb/day) 3. Emissions assume a 100% load factor. Generator Set 1 Generator Set 2 Generator Set 3 Generator Set 4 Generator Set 5 Generator Set 6 Generator Set 7 Generator Set 8 11111111 53 53 53 139 59 59 111 78 Diesel Diesel Diesel Diesel Diesel Diesel Diesel Diesel 24 24 24 24 24 24 24 24 365 365 365 365 152 152 152 152 Acetaldehyde 7.7E-04 7.7E-04 7.7E-04 7.7E-04 7.7E-04 7.7E-04 7.7E-04 7.7E-04 Acrolein 9.3E-05 9.3E-05 9.3E-05 9.3E-05 9.3E-05 9.3E-05 9.3E-05 9.3E-05 Benzene 9.3E-04 9.3E-04 9.3E-04 9.3E-04 9.3E-04 9.3E-04 9.3E-04 9.3E-04 1,3-Butadiene 3.9E-05 3.9E-05 3.9E-05 3.9E-05 3.9E-05 3.9E-05 3.9E-05 3.9E-05 Formaldehyde 0.0012 0.0012 0.0012 0.0012 0.0012 0.0012 0.0012 0.0012 Naphthalene 8.5E-05 8.5E-05 8.5E-05 8.5E-05 8.5E-05 8.5E-05 8.5E-05 8.5E-05 PAHs 1.7E-04 1.7E-04 1.7E-04 1.7E-04 1.7E-04 1.7E-04 1.7E-04 1.7E-04 Toluene 4.1E-04 4.1E-04 4.1E-04 4.1E-04 4.1E-04 4.1E-04 4.1E-04 4.1E-04 Xylenes 2.9E-04 2.9E-04 2.9E-04 2.9E-04 2.9E-04 2.9E-04 2.9E-04 2.9E-04 Acetaldehyde 0.007 0.007 0.007 0.018 0.008 0.008 0.014 0.010 Acrolein 0.0008 0.0008 0.0008 0.0022 0.0009 0.0009 0.002 0.0012 Benzene 0.008 0.008 0.008 0.022 0.009 0.009 0.02 0.012 1,3-Butadiene 0.0003 0.0003 0.0003 0.0009 3.9E-04 3.9E-04 0.0007 0.0005 Formaldehyde 0.011 0.011 0.011 0.028 0.012 0.012 0.02 0.015 Naphthalene 0.0008 0.0008 0.0008 0.0020 0.0008 0.0008 0.0016 0.0011 PAHs 0.0015 0.0015 0.0015 0.0039 0.0017 0.0017 0.003 0.0022 Toluene 0.004 0.004 0.004 0.010 0.0041 0.0041 0.008 0.005 Xylenes 0.003 0.003 0.003 0.007 0.0028 0.0028 0.005 0.0037 Acetaldehyde 0.0012 0.0012 0.0012 0.0033 0.0006 0.0006 0.0011 0.0008 Acrolein 1.5E-04 1.5E-04 1.5E-04 3.9E-04 7.0E-05 7.0E-05 1.3E-04 9.2E-05 Benzene 0.0015 0.0015 0.0015 0.0040 0.0007 0.0007 0.0013 0.0009 1,3-Butadiene 6.4E-05 6.4E-05 6.4E-05 1.7E-04 2.9E-05 2.9E-05 5.5E-05 3.9E-05 Formaldehyde 0.0019 0.0019 0.0019 0.005 0.0009 0.0009 0.002 0.0012 Naphthalene 1.4E-04 1.4E-04 1.4E-04 3.6E-04 6.4E-05 6.4E-05 1.2E-04 8.4E-05 PAHs 0.0003 0.0003 0.0003 0.0007 1.3E-04 1.3E-04 0.0002 1.7E-04 Toluene 0.0007 0.0007 0.0007 0.0017 3.1E-04 3.1E-04 0.0006 4.1E-04 Xylenes 0.0005 0.0005 0.0005 0.0012 2.1E-04 2.1E-04 0.0004 2.8E-04 Notes: References: EPA. 1996b. AP-42, Section 3.4, Large Stationary Diesel and All Stationary Dual-Fuel Engines. Available online at: https://www3.epa.gov/ttnchie1/ap42/ch03/final/c03s04.pdf. October. Equipment Quantity Engine (hp) Fuel Type Operating Hours per Day Operating Days per Year Emission Factors1,2 (lb/MMBtu) Daily Emissions (lb/day) Annual Emissions (tpy) 1. Emission factors for generators less than 600 HP are based on AP-42 Section 3.3 (EPA 1996a). EPA. 1996a. AP-42, Section 3.3, Gasoline and Diesel Industrial Engines. Available online at: https://www3.epa.gov/ttnchie1/ap42/ch03/final/c03s03.pdf. October. Equipment Description Table 5 Exhaust - Generator Sets for Pumps Hazardous Air Pollutants Peak Minerals Inc. Delta, Utah PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 Compaction Baghouse Belt Conveyor 3470-CV-021 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Compaction Baghouse ---4 0.72 0.0014 2.1E-04 0 0 0 0 0 0 Main Dryer Baghouse Screw Conveyor 3410-CV-020 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Dryer Baghouse ---4 3.6 0.0070 0.0011 0 0 0 0 0 0 Dry Product Drag Conveyor 3410-CV-001 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Compaction Baghouse ---4 107 0.21 0.031 0 0 0 0 0 0 Screen Feed Bucket Elevator 3410-BE-001 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Compaction Baghouse ---4 107 0.21 0.031 0 0 0 0 0 0 SOP Centrifuge Screw Conveyor 3410-CV-503 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Wet process, Negligible 100% 33 0.064 0.010 0 0 0 0 0 0 Off-Spec Conveyor 3410-CV-504 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Mop Addition Area Baghouse ---4 33 0.064 0.010 0 0 0 0 0 0 Soluble/Granular Product Diverter 3410-DT-001 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Dryer Baghouse ---4 51 0.10 0.015 0 0 0 0 0 0 Soluble/Granular Product Diverter 3410-DT-002 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Dryer Baghouse ---4 32 0.062 0.0095 0 0 0 0 0 0 Oversize Product Magnetic Chute 3410-MG-001 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Dryer Baghouse ---4 20 0.039 0.0059 0 0 0 0 0 0 Undersize Belt Conveyor 3420-CV-301 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Compaction Baghouse ---4 95 0.19 0.028 0 0 0 0 0 0 Belt Conveyor Bucket Elevator Feed 3420-CV-401 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Compaction Baghouse ---4 98 0.19 0.029 0 0 0 0 0 0 Compaction Feed Bucket Elevator 3420-BE-101 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Compaction Baghouse ---4 98 0.19 0.029 0 0 0 0 0 0 Compaction Feed Drag Conveyor 3420-CV-101 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Compaction Baghouse ---4 98 0.19 0.029 0 0 0 0 0 0 Compactor 3420-CM-001 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Compaction Baghouse ---4 95 0.19 0.028 0 0 0 0 0 0 Curing Drag Conveyor 3420-CV-001 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Compaction Baghouse ---4 95 0.19 0.028 0 0 0 0 0 0 Curing Drag Conveyor 3420-CV-002 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Compaction Baghouse ---4 95 0.19 0.028 0 0 0 0 0 0 Bucket Elevator Feed Belt Conveyor 3420-CV-003 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Compaction Baghouse ---4 118 0.23 0.035 0 0 0 0 0 0 Screen Feed Bucket Elevator 3420-BE-201 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Compaction Baghouse ---4 118 0.23 0.035 0 0 0 0 0 0 Granular Product Belt Conveyor 3420-CV-004 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Compaction Baghouse ---4 34 0.066 0.010 0 0 0 0 0 0 Compactor Magnet 3420-MG-101 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Compaction Baghouse ---4 93 0.18 0.027 0 0 0 0 0 0 Roll Crusher Belt Conveyor 3420-CV-005 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Compaction Baghouse ---4 118 0.23 0.035 0 0 0 0 0 0 Compaction Surge Bin 3420-SI-101 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Compaction Baghouse ---4 180 0.35 0.053 0 0 0 0 0 0 Glazing Drum 3430-CD-001 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Glazing Dryer Baghouse ---4 34 0.066 0.010 0 0 0 0 0 0 Glazing Feed Belt Conveyor 3430-CV-001 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Glazing Dryer Baghouse ---4 38 0.074 0.011 0 0 0 0 0 0 Glazing Baghouse Screw Conveyor 3430-CV-020 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Glazing Dryer Baghouse ---4 3.6 0.0070 0.0011 0 0 0 0 0 0 Glazing Fluid Bed Dryer/Cooler 3430-DY-001 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Glazing Dryer Baghouse ---4 38 0.074 0.011 0 0 0 0 0 0 Glazed Product Drag Conveyor 3430-CV-002 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Glazing Dryer Baghouse ---4 39 0.076 0.012 0 0 0 0 0 0 Glazed Product Bucket Elevator 3430-BE-101 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Glazing Dryer Baghouse ---4 39 0.076 0.012 0 0 0 0 0 0 Table 6 Delta, Utah Peak Minerals Inc. Fugitive Emissions - Processing Facility Material Handling Points Source Name Aerodynamic Particle Size Multiplier (k) Material Moisture Content1 (%) Wind Speed2 (miles/hr) Annual Hours of Operation3 Control Source Control Efficiency 4 Process Rate5 (tph) Emission Factor3 (lb/ton) Uncontrolled Annual Emissions (tpy) Controlled Annual Emissions6 (tpy) Controlled Maximum Daily Emissions6 (lb/day) Controlled Daily Emissions6 (lb/day) Equipment Number Daily Hours of Operation3 PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 Table 6 Delta, Utah Peak Minerals Inc. Fugitive Emissions - Processing Facility Material Handling Points Source Name Aerodynamic Particle Size Multiplier (k) Material Moisture Content1 (%) Wind Speed2 (miles/hr) Annual Hours of Operation3 Control Source Control Efficiency 4 Process Rate5 (tph) Emission Factor3 (lb/ton) Uncontrolled Annual Emissions (tpy) Controlled Annual Emissions6 (tpy) Controlled Maximum Daily Emissions6 (lb/day) Controlled Daily Emissions6 (lb/day) Equipment Number Daily Hours of Operation3 Glazed Screen Oversize Belt Conveyor 3430-CV-003 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Glazing Dryer Baghouse ---4 1.4 0.0027 4.1E-04 0 0 0 0 0 0 Loadout Feed Belt Conveyor 3440-CV-101 0.35 0.053 0.20 8.1 7,880 24 0.053 0.0080 Loadout Silo Baghouse ---4 316.41.0000000 Loadout Silo 3440-SI-001 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Loadout Silo Baghouse ---4 519 1.0 0.15 0 0 0 0 0 0 Loadout Silo Dust Filter Cyclone 3440-CC-001 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Loadout Silo Baghouse ---4 31 0.060 0.0090 0 0 0 0 0 0 Loadout Silo Dust Filter Cyclone 3440-CC-002 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Loadout Silo Baghouse ---4 31 0.060 0.0090 0 0 0 0 0 0 Tailings Belt Conveyor 3360-CV-641 0.35 0.053 20 0.22 7,880 24 7.9E-07 1.2E-07 Wet process, Negligible 100% 11 3.5E-05 5.3E-06 0 0 0 0 0 0 Crushing Feed Hopper 3310-HP-101 0.35 0.053 15 8.1 7,880 24 1.3E-04 1.9E-05 Wet process, Negligible 100% 45 0.022 0.0034 0 0 0 0 0 0 Hammer Mill Chute 3310-CH-101 0.35 0.053 15 8.1 7,880 24 1.3E-04 1.9E-05 Wet process, Negligible 100% 155 0.077 0.012 0 0 0 0 0 0 Crushing Conveyor 3310-CV-101 0.35 0.053 15 8.1 7,880 24 1.3E-04 1.9E-05 Wet process, Negligible 100% 155 0.077 0.012 0 0 0 0 0 0 Crushing Magnet 3310-MG-101 0.35 0.053 15 8.1 7,880 24 1.3E-04 1.9E-05 Wet process, Negligible 100% 155 0.077 0.012 0 0 0 0 0 0 MOP Feed Hopper 3480-HP-801 0.35 0.053 0.20 8.1 1,338 4 0.053 0.0080 Mop Addition Area Baghouse ---4 165 5.9 0.89 0 0 0 0 0 0 MOP Feed Conveyor 3480-CV-801 0.35 0.053 0.20 8.1 1,338 4 0.053 0.0080 Mop Addition Area Baghouse ---4 165 5.9 0.89 0 0 0 0 0 0 MOP Silo Belt Conveyor 3480-CV-802 0.35 0.053 0.20 8.1 7,880 24 0.053 0.0080 Mop Addition Area Baghouse ---4 13 2.7 0.41 0 0 0 0 0 0 MOP Bucket Elevator 3480-BE-802 0.35 0.053 0.20 8.1 1,338 4 0.053 0.0080 Mop Addition Area Baghouse ---4 165 5.9 0.89 0 0 0 0 0 0 MOP Drag Conveyor 3480-CV-803 0.35 0.053 0.20 8.1 7,880 24 0.053 0.0080 Mop Addition Area Baghouse ---4 13 2.7 0.41 0 0 0 0 0 0 MOP Silo 3480-SI-804 0.35 0.053 0.20 8.1 1,338 4 0.053 0.0080 MOP Silo Vent Filter ---4 165 5.9 0.89 0 0 0 0 0 0 MOP Addition Baghouse Screw Conveyor 3480-CV-820 0.35 0.053 0.20 8.1 1,338 4 0.053 0.0080 Mop Addition Area Baghouse ---4 1.0 0.036 0.0054 0 0 0 0 0 0 Off Spec Product Drag Conveyor 3490-CV-901 0.35 0.053 0.20 8.1 1,338 4 0.053 0.0080 Mop Addition Area Baghouse ---4 5.80.210.031000000 Off Spec Product Hopper 3490-HP-901 0.35 0.053 0.20 8.1 1,338 4 0.053 0.0080 Mop Addition Area Baghouse ---4 5.30.190.029000000 Water Soluble SOP Belt Conveyor 3460-CV-601 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Uncontrolled, Enclosed/Indoors 90% 32 0.062 0.0095 0.0062 9.5E-04 0.038 0.0058 0.038 0.0058 Water Soluble SOP Bucket Elevator 3460-BE-602 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Uncontrolled, Enclosed/Indoors 90% 32 0.062 0.0095 0.0062 9.5E-04 0.038 0.0058 0.038 0.0058 Bagging Silo Feed Conveyor 3460-CV-603 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Uncontrolled, Enclosed/Indoors 90% 32 0.062 0.0095 0.0062 9.5E-04 0.038 0.0058 0.038 0.0058 Bagging Plant Transfer Conveyor 3460-CV-605 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Uncontrolled, Enclosed/Indoors 90% 33 0.064 0.010 0.0064 0.0010 0.039 0.0059 0.039 0.0059 PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 Table 6 Delta, Utah Peak Minerals Inc. Fugitive Emissions - Processing Facility Material Handling Points Source Name Aerodynamic Particle Size Multiplier (k) Material Moisture Content1 (%) Wind Speed2 (miles/hr) Annual Hours of Operation3 Control Source Control Efficiency 4 Process Rate5 (tph) Emission Factor3 (lb/ton) Uncontrolled Annual Emissions (tpy) Controlled Annual Emissions6 (tpy) Controlled Maximum Daily Emissions6 (lb/day) Controlled Daily Emissions6 (lb/day) Equipment Number Daily Hours of Operation3 Bagging Plant Buffer Silo 3460-SI-605 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Bagging Plant Buffer Silo Vent Filter ---4 120 0.23 0.035 0 0 0 0 0 0 Bagging Plant Accumulating Conveyor 3460-CV-606 0.35 0.053 0.20 0.22 7,880 24 5.0E-04 7.5E-05 Uncontrolled, indoor 90% 33 0.064 0.010 0.0064 0.0010 0.039 0.0059 0.039 0.0059 Compaction Baghouse Screw Conveyor 3470-CV-022 0.35 0.053 0.20 0.22 7,880 24 4.8E-04 7.3E-05 Compaction Baghouse ---4 0.72 0.0014 2.1E-04 0 0 0 0 0 0 Schoenite Cake Screw Conveyor 3340-CV-401 0.35 0.053 20 0.22 7,880 24 7.9E-07 1.2E-07 Wet process, Negligible 100% 102 3.2E-04 4.8E-05 0 0 0 0 0 0 Schoenite Cake Screw Conveyor 3340-CV-402 0.35 0.053 20 0.22 7,880 24 7.9E-07 1.2E-07 Wet process, Negligible 100% 102 3.2E-04 4.8E-05 0 0 0 0 0 0 Lime Loading Screw Mass Flow Conveyor 050-CV-011 0.35 0.053 0.70 8.1 7,880 24 0.0092 0.0014 Uncontrolled, Enclosed/Outdoors 70% 1.0 0.038 0.0057 0.011 0.0017 0.069 0.010 2.319 0.351 Bischofite Belt Conveyor 050-CV-071 0.35 0.053 0.70 0.22 7,880 24 8.6E-05 1.3E-05 Uncontrolled, Enclosed/Indoors 90% 14 0.0047 7.1E-04 4.7E-04 7.1E-05 0.0029 4.4E-04 0.0029 4.4E-04 Silo Feed Screw Conveyor 050-CV-072 0.35 0.053 0.70 0.22 7,880 24 8.6E-05 1.3E-05 Uncontrolled, Enclosed/Indoors 90% 14 0.0047 7.1E-04 4.7E-04 7.1E-05 0.0029 4.4E-04 0.0029 4.4E-04 Quick Lime Silo 050-SI-011 0.35 0.053 0.70 8.1 7,880 24 0.0092 0.0014 Silo Bin Vent ---4 72 2.6 0.39 0 0 0 0 0 0 50 Lb Bischofite Silo 050-SI-071 0.35 0.053 0.70 0.22 7,880 24 8.6E-05 1.3E-05 Silo Bin Vent ---4 6.0 0.0020 3.1E-04 0 0 0 0 0 0 1 Ton Bischofite Silo 050-SI-072 0.35 0.053 0.70 0.22 7,880 24 8.6E-05 1.3E-05 Silo Bin Vent ---4 6.0 0.0020 3.1E-04 0 0 0 0 0 0 Bischofite Flaker 050-XM-071 0.35 0.053 100 0.22 7,880 24 8.3E-08 1.2E-08 Uncontrolled, Enclosed/Indoors 90% 6.9 2.3E-06 3.4E-07 2.3E-07 3.4E-08 1.4E-06 2.1E-07 1.4E-06 2.1E-07 Bischofite Flaker 050-XM-072 0.35 0.053 100 0.22 7,880 24 8.3E-08 1.2E-08 Uncontrolled, Enclosed/Indoors 90% 6.9 2.3E-06 3.4E-07 2.3E-07 3.4E-08 1.4E-06 2.1E-07 1.4E-06 2.1E-07 Notes: References: 2. Emissions from all material handling sources located indoors are based on a windspeed of 0.1 m/s (0.22 mph) consistent with EPA's Risk Management Program guidance (EPA 1999). Outdoor sources use a wind speed consistent with the annual average speed from site specific meteorological data. 1. Moisture content of the process feed and tailings were provided by Peak Minerals. Moisture content for all internal Processing Facility material handling sources use the most conservative (lowest) moisture content from Peak Minerals guidance: there are four moisture content changes through the Processing Facility operation, occurring at the compactor feed (1.5%), main SOP dryer outlet (0.2%), glazing outlet (1.5%) and glazing dryer/cooler outlet (0.2%). Thus, 0.2% was used for all internal Processing Facility SOP material handling calculations, except for wet processes and MgCl2 processes which were specified by Peak Minerals. The moisture content of lime loaded into the silo is from AP-42 Table 13.2.4-1 for crushed limestone. TCEQ. 2021. TCEQ Mechanical Sources; Current Best Available Control Technology (BACT) Guidelines. January. Available online at: https://www.tceq.texas.gov/permitting/air/nav/air_bact_mechsource.html MDAQMD. 1999. Emissions Inventory Guidance. Available online at: http://www.mdaqmd.ca.gov/home/showdocument?id=768 EPA. 2006. AP-42 Section 13.2.4. Aggregated Handling and Storage Piles. Available online at: https://www3.epa.gov/ttn/chief/ap42/ch13/final/c13s0204.pdf EPA. 1999. Risk Management Program Guidance for Offsite Consequence Analysis. Appendix D.2.4 Releases Inside Buildings. April. Available online at: https://www.epa.gov/sites/production/files/2017-05/documents/oca-apds.pdf 6. Any material handling points controlled by a baghouse have their emissions reported at the control source. 5. Equipment specific information provided by Peak Minerals. 4. Control efficiencies were applied as follows: any sources with control source "uncontrolled, enclosed/outdoors" are assumed to be outdoor enclosed sources with a control efficiency of 70% consistent with TCEQ guidance, and any sources with control source "uncontrolled, enclosed/indoors" are assumed to be fully-enclosed indoor sources with a control efficiency of 90% consistent with TCEQ guidance. Any sources with control source "wet process, negligible" are assumed a control efficiency of 100% due to handling liquid streams and slurries. All other sources are assumed to be controlled by a baghouse that meets BACT requirements. 3. Emission factors are estimated using methodology in AP-42 Section 13.2.4. [E = k * 0.0032 * (U/5)1.3 / (M/2)1.4] PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 Mixed Salts Screen 3310-SN-101 0.12 0.038 Wet process, Negligible 100% 7,880 307 145 46 0000 Product Screen 3410-SN-001 0.12 0.038 Compaction Baghouse ---2 7,880 107 51 16 0000 Compaction Screen 3420-SN-010 0.12 0.038 Compaction Baghouse ---2 7,880 118 56 18 0000 Granular Product Glazing Screen 3430-SN-101 0.12 0.038 Compaction Baghouse ---2 7,880 39 18 5.8 0000 Notes: References: MDAQMD. 1999. Emissions Inventory Guidance. Available online at: http://www.mdaqmd.ca.gov/home/showdocument?id=768 1. Emission factors for PM 10 and PM2.5 are based on Mojave Desert Air Quality Management District (MDAQMD) Material Crushing and Screening Operations emission factors for dry screening. 4. Any screens controlled by a baghouse have their emissions reported at the control device. 3. Equipment specific information provided by Peak Minerals. 2. Control efficiencies were applied as follows: any sources with control source "wet process, negligible" are assumed to have neglible emissions per MDAQMD guidance (MDAQMD 1999). All other sources are controlled by a baghouse that is assumed to meet BACT requirements. Uncontrolled Annual Emissions (tpy) Controlled Annual Emissions4 (tpy) Controlled Daily Emissions4 (lb/day) Table 7 Fugitive Emissions - Processing Facility Screening Peak Minerals Inc. Delta, Utah Source Name Emission Factor1 (lb/ton)Control Source Control Efficiency2 Annual Hours of Operation3 Process Rate3 (tph) Equipment Number PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 PM10 PM2.5 Dryer Oversize Roll Crusher 3410-CR-001 0.11 0.0035 Compaction Baghouse ---2 7,880 20 9.0 0.28 0000 Compaction Flake Breaker 3420-CR-001 0.11 0.0035 Compaction Baghouse ---2 7,880 95 42 1.3 0000 Compaction Double Roll Crusher 3420-CR-002 0.11 0.0035 Compaction Baghouse ---2 7,880 25 11 0.34 0000 Notes: References: MDAQMD. 1999. Emissions Inventory Guidance. Available online at: http://www.mdaqmd.ca.gov/home/showdocument?id=768 4. Any crushers controlled by a baghouse have their emissions reported at the control device. Table 8 Fugitive Emissions - Processing Facility Crushers and Mills Peak Minerals Inc. Delta, Utah 3. Equipment specific information provided by Peak Minerals. 1. Emission factors for PM 10 and PM2.5 are conservatively based on Mojave Desert Air Quality Management District (MDAQMD) Material Crushing and Screening Operations emission factors for tertiary crushing. Controlled Daily Emissions4 (lb/day) Controlled Annual Emissions4 (tpy) Uncontrolled Annual Emissions (tpy) Process Rate3 (tph) Annual Hours of Operation3 2. All sources are controlled by a baghouse that is assumed to meet BACT requirements. Control Efficiency2Control SourceEquipment Number Emission Factor1 (lb/ton)Source Name PM10 PM2.5 PM10 PM2.5 Compaction Baghouse 35,000 0.0050 6.6 6.6 36 36 Main Dryer Baghouse 14,125 0.010 5.3 5.3 29 29 Glazing Dryer/Cooler Baghouse 6,769 0.010 2.5 2.5 14 14 Loadout Silo Bin Vent 1,500 0.0050 0.28 0.28 1.5 1.5 MOP Silo Bin Vent 1,900 0.0050 0.36 0.36 1.95 1.95 Bagging Plant Buffer Silo Bin Vent 1,500 0.0050 0.28 0.28 1.5 1.5 Quick Lime Silo Bin Vent 1,900 0.0050 0.357 0.357 1.95 1.95 50 Lb Bischofite Silo Bin Vent 1,900 0.0050 0.357 0.3567 1.95 1.95 1 Ton Bischofite Silo Vent 1,900 0.0050 0.357 0.3567 1.95 1.95 Notes: 1. Equipment specific information provided by Peak Minerals. 4. Baghouse and dust collector emissions are estimated based on an assumed BACT limits for exhaust grain loading for continuous operation at the air flow rate. Table 9 Particulate Emissions - Processing Facility Baghouses Peak Minerals Inc. Delta, Utah Source Name Air Flow1,2 (acfm) Exhaust Grain Loading3 (gr/scf) Annual Emissions4 (tpy) Daily Emissions4 (lb/day) 3. Baghouse and dust collector grain loading based on assumed BACT limit. 2. Flowrates for silo bin vents were estimated by Novopro. As these bin vents have not yet been finalized, Novopro recommends 10" vent nozzle diameters and an adequate air velocity of 20 m/s, which equates to 1,900 cfm. They specified 1,900 cfm as a conservative estimate. (MT/yr) NOx SOx CO VOC PM10 PM2.5 CO2 CH4 N2ONOx SOx CO VOC PM10 PM2.5 NOx SOx CO VOC PM10 PM2.5 CO2e Fire Pump 1 Tier 4 100 100 0.30 0.0039 3.7 0.15 0.015 0.014 590 0.0023 0.027 1.6 0.021 20 0.80 0.079 0.077 0.0033 4.3E-05 0.041 0.0017 1.6E-04 1.6E-04 6.0 Pond Mobile Pumps 3 Tier 4 20 1488 5.3 0.0054 4.9 0.30 0.30 0.29 590 0.0045 0.027 17 0.017 16 0.95 0.95 0.92 0.52 5.3E-04 0.48 0.029 0.029 0.028 53 Emergency Generators 2 Tier 4 1,342 100 0.50 0.0035 2.6 0.15 0.022 0.022 531 0.0023 0.025 3.0 0.021 15 0.90 0.13 0.13 0.15 0.0010 0.77 0.045 0.0066 0.0064 145 Notes: References: EPA. 2010. Conversion Factors for Hycrocarbon Emission Components, NR-002d. Available online at: https://nepis.epa.gov/Exe/ZyPDF.cgi?Dockey=P10081RP.pdf EPA. 2018. Inventory of U.S. Greenhouse Gas Emissions and Sinks: 1990-2016, Annex Part 3A, Table A-112. Available online at: https://www.epa.gov/ghgemissions/inventory-us-greenhouse-gas-emissions-and-sinks Table 10a Stationary Sources - Fire Pump, Operational Pumps, and Emergency Generators Peak Minerals Inc. Delta, Utah Equipment Description Equipment Quantity Engine Tier Level Engine (hp) Maximum Operating Hours per Year Maximum Annual Emissions 1. Criteria air pollutant emission factors for off-road equipment are based on EPA tiered emission limits. Criteria Air Pollutants and Greenhouse Gas Emissions 3. Total GHG (CO2e) emissions calculated based on CO2, CH4, and N2O emission factors along with global warming potentials from 40 CFR Part 98, Table A-1. 2. CO2 emission factors are based on MOVES-NONROAD methodology with default BSFC-based or operator provided fuel consumption estimates. CH4 emission factors are based on VOC emission factors and MOVES-NONROAD hydrocarbon conversions (EPA 2010). N2O emission factors are based on g/kg factor from the latest EPA GHG sinks inventory (EPA 2018) and default BSFC-based or operator provided fuel consumption estimates. Emission Factors1,2 (g/hp-hr) Maximum Daily Emissions (lb/day)(tpy) Fire Pump Pond Mobile Pumps Emergency Generators 132 100 20 1,342 Diesel Diesel Diesel 1241 100 1488 100 Acetaldehyde 7.7E-04 7.7E-04 2.5E-05 Acrolein 9.3E-05 9.3E-05 7.9E-06 Benzene 9.3E-04 9.3E-04 7.8E-04 1,3-Butadiene 3.9E-05 3.9E-05 -- Formaldehyde 0.0012 0.0012 7.9E-05 Naphthalene 8.5E-05 8.5E-05 1.3E-04 PAHs 1.7E-04 1.7E-04 2.1E-04 Toluene 4.1E-04 4.1E-04 2.8E-04 Xylenes 2.9E-04 2.9E-04 1.9E-04 Acetaldehyde 5.4E-04 0.0077 4.7E-04 Acrolein 6.5E-05 9.3E-04 1.5E-04 Benzene 6.5E-04 0.0094 0.015 1,3-Butadiene 2.7E-05 3.9E-04 0 Formaldehyde 8.3E-04 0.012 0.0015 Naphthalene 5.9E-05 8.5E-04 0.0024 PAHs 1.2E-04 0.0017 0.0040 Toluene 2.9E-04 0.0041 0.0053 Xylenes 2.0E-04 0.0029 0.0036 Acetaldehyde 2.7E-05 0.0058 2.4E-05 Acrolein 3.2E-06 6.9E-04 7.4E-06 Benzene 3.3E-05 0.0070 7.3E-04 1,3-Butadiene 1.4E-06 2.9E-04 0 Formaldehyde 4.1E-05 0.0088 7.4E-05 Naphthalene 3.0E-06 6.4E-04 1.2E-04 PAHs 5.9E-06 0.0013 2.0E-04 Toluene 1.4E-05 0.0031 2.6E-04 Xylenes 1.0E-05 0.0021 1.8E-04 Notes: References: 1. Fire pump and operational pump emission factors are based on AP-42 Section 3.3 (EPA 1996a). 2. Emergency generator emission factors are based on AP-42 Section 3.4 (EPA 1996b). EPA. 1996a. AP-42, Section 3.3, Gasoline and Diesel Industrial Engines. Available online at: https://www3.epa.gov/ttnchie1/ap42/ch03/final/c03s03.pdf. October. EPA. 1996b. AP-42, Section 3.4, Large Stationary Diesel and All Stationary Dual-Fuel Engines. Available online at: https://www3.epa.gov/ttnchie1/ap42/ch03/final/c03s04.pdf. October. Equipment Quantity Annual Emissions (tpy) Engine (hp) Fuel Type Operating Hours per Day Operating Hours per Year Emission Factors1,2 (lb/MMBtu) Daily Emissions (lb/day) Equipment Description Table 10b Stationary Sources - Fire Pump, Operational Pumps, and Emergency Generators Hazardous Air Pollutants Peak Minerals Inc. Delta, Utah (MT/yr) NOx SOx CO VOC PM10 PM2.5 CO2 CH4 N2ONOx SOx CO VOC PM10 PM2.5 NOx SOx CO VOC PM10 PM2.5 CO2e3 Drying and sizing fluid bed dryer 4.4 Propane 24 328 0.14 5.9E-04 0.082 0.012 -- -- 139 0.0066 0.0013 15 0.062 8.7 1.3 -- -- 2.5 MGC 1.4 0.21 -- -- 2,186 Glazing fluid bed dryer 2.0 Propane 24 328 0.14 5.9E-04 0.082 0.012 -- -- 139 0.0066 0.0013 6.8 0.028 3.9 0.58 -- -- 1.1 0.0046 0.65 0.095 -- -- 994 MgCl2 Steam Boiler 15 Propane 24 328 0.14 5.9E-04 0.082 0.012 0.0077 0.0077 139 0.0066 0.0013 50 0.21 29 4.2 2.7 2.7 8.2 0.034 4.7 0.70 0.44 0.44 7,305 Notes: References: Table 11a Stationary Source - Fluid Bed Dryers and Boilers Criteria Pollutants and Greenhouse Gases Peak Minerals Inc. Delta, Utah Annual Emissions 2. GHG emission factors are from 40 CFR Part 98, Subpart C, Tables C-1 and C-2 and are converted to CO2e emissions using the global warming potential values in 40 CFR Part 98, Subpart A, Table A-1. USEPA. 2008. AP-42 Section 1.5. Liquefied Petroleum Gas Combustion. Available online at: https://www3.epa.gov/ttnchie1/ap42/ch01/final/c01s05.pdf 1. Criteria air pollutant emissions are estimated using propane fired emission factors in AP-42 Section 1.5. Both dryers vent to the Main Dryer Baghouse - therefore, their PM emissions are negligible. Equipment Description Burner Design Capacity (MMBtu/hr) Fuel Type Operating Hours per Day Operating Days per Year 3. Total GHG (CO2e) emissions calculated based on CO2, CH4, and N2O emission factors along with global warming potentials from 40 CFR Part 98, Table A-1. (tpy) Emission Factors1,2 (lb/MMBtu) Daily Emissions (lb/day) Drying and sizing fluid bed dryer Glazing fluid bed dryer MgCl2 Steam Boiler 4.4 2.0 14.7 Propane Propane Propane 24 24 24 328 328 328 Acetaldehyde 4.4E-06 4.4E-06 4.4E-06 Acrolein 2.8E-06 2.8E-06 2.8E-06 Benzene 8.2E-06 8.2E-06 8.2E-06 Ethyl benzene 9.8E-06 9.8E-06 9.8E-06 Formaldehyde 1.7E-05 1.7E-05 1.7E-05 Hexane 6.5E-06 6.5E-06 6.5E-06 Naphthalene 3.1E-07 3.1E-07 3.1E-07 PAHs 1.0E-07 1.0E-07 1.0E-07 Toluene 3.8E-05 3.8E-05 3.8E-05 Xylenes 2.8E-05 2.8E-05 2.8E-05 Acetaldehyde 4.7E-04 2.1E-04 0.0016 Acrolein 2.9E-04 1.3E-04 0.0010 Benzene 8.7E-04 3.9E-04 0.0029 Ethyl benzene 0.0010 4.7E-04 0.0034 Formaldehyde 0.0018 8.4E-04 0.0062 Hexane 6.8E-04 3.1E-04 0.0023 Naphthalene 3.3E-05 1.5E-05 1.1E-04 PAHs 1.1E-05 4.9E-06 3.6E-05 Toluene 0.0040 0.0018 0.013 Xylenes 0.0030 0.0013 0.010 Acetaldehyde 7.6E-05 3.5E-05 2.6E-04 Acrolein 4.8E-05 2.2E-05 1.6E-04 Benzene 1.4E-04 6.5E-05 4.8E-04 Ethyl benzene 1.7E-04 7.7E-05 5.6E-04 Formaldehyde 3.0E-04 1.4E-04 0.0010 Hexane 1.1E-04 5.1E-05 3.7E-04 Naphthalene 5.3E-06 2.4E-06 1.8E-05 PAHs 1.8E-06 8.1E-07 5.9E-06 Toluene 6.5E-04 3.0E-04 0.0022 Xylenes 4.8E-04 2.2E-04 0.0016 Notes: References: San Joaquin Valley Air Pollution Control District (SJVAPCD). 2015. LPG-Fired External Combustion - HAP Emission Factors. May 11. Available online at: http://www.valleyair.org/busind/pto/emission_factors/Criteria/Toxics/External%20Combustion/LPG%20 External%20Combustion.xls. Table 11b Stationary Source - Fluid Bed Dryers and Boilers Hazardous Air Pollutants Peak Minerals Inc. Delta, Utah Operating Days per Year Emission Factors1 (lb/MMBtu) Daily Emissions (lb/day) Annual Emissions (tpy) Equipment Description Burner Design Capacity (MMBtu/hr) Fuel Type Operating Hours per Day 1. Emissions are estimated based on SJVAPCD emission factors for propane-fired external combustion sources. Source Name Saturation Factor1 Vapor Pressure2 (psia) Vapor Molecular Weight3 (lb/lb-mole) Temperature4 (degrees Rankine) Loading VOC Emission Factor5 (lb/1000 gal) Total Diesel Fuel Usage6 (gal/yr) VOC Emissions (tpy) VOC Emissions (lb/day) Diesel Dispensing Facility 0.60 0.020 130 560 0.035 459,688 0.0080 0.044 Notes: References: Table 12 Diesel Dispensing Facility Emissions Peak Minerals Inc. Delta, Utah 1. Used the saturation factor for submerged loading: dedicated normal service from AP-42, Section 5.2. 2. Conservatively used 0.02 psia for vapor pressure (reid vapor pressure of diesel fuel, which is the vapor pressure at 100 F). EPA. 2008. AP-42, Section 5.2, Transportation and Marketing of Petroleum Liquids. Available online at: https://www3.epa.gov/ttn/chief/ap42/ch05/final/c05s02.pdf. June. 3. Molecular weight of distillate fuel oil No. 2 from AP-42, Table 7.1-2. 4. Assume temperature of 100 degrees F. 5. Loading VOC emission factor calculated using loading loss equation in AP-42, Section 5.2. 6. Diesel fuel usage calculated conservatively calculated based on maximum hours of operation and expected fuel usage rates for off-road equipment, assuming all operational and construction equipment would operate during the same year. EPA. 2020. AP-42, Section 7.1, Organic Liquid Storage Tanks. Available online at: https://www.epa.gov/sites/default/files/2020-10/documents/ch07s01.pdf. June. Parameter Description1 Equation Taxed Diesel Tank Material Stored2 --Diesel Tank Type2 --Horizontal Location2 --Processing Facility Tank Shell Color2 ---- Paint Condition2 ---- Number of Tanks --2.0 Tank Volume (V), gal Facility specific 28,000 Tank Volume (V), ft3 V= gal / 7.48 gal/ft3 = π(D/2)2[4/3*(D/2)+a] where a = L-D 3,743 Tank Diameter (D), ft rearranging equation for V and assuming L=2D, D=(12*V/(π*5))1/3 14 Length of the Horizontal Tank (L), ft Assume that the length is twice the diameter 28 Effective Diameter (DE), ft Horizontal tanks: DE = (LD/(π/4))1/2 23 Effective Height (HE), ft Horizontal tanks: HE = (π/4)D 11 Vapor Space Outage (HVO), ft Horizontal tanks: HVO = HE/2 5.6 Vapor Space Volume (VV), ft3 VV =( (π/4)D2)*HVO 2,246 True Vapor Pressure (PVA)AP-42, Table 7.1-2 0.0065 Vapor Molecular Weight (MV), lb/lb-mole 130 Ideal Gas Constant (R), psia ft3/lb-mole R Constant 11 Daily Total Solar Insolation Factor3 (I), Btu/ft2 AP-42, Table 7.1-7 1,603 Tank Paint Solar Absorptance4 (α), dimensionless AP-42, Table 7.1-6 0.17 Vented Vapor Saturation Factor (KS), dimensionless KS = 1/(1 + 0.053PVAHVO)1.0 Daily Average Ambient Temperature (TAA), R TAA = (TAX + TAN)/2 511 Liquid Bulk Temperature, R TB = TAA + 6α - 1 511 Daily Average Liquid Surface Temperature (TLA), R TLA = 0.44TAA + 0.56TB + 0.0079 α I 513 Vapor Density (WV), lb/ft3 WV = MVPVA/RTLA 1.5E-04 Vapor Space Expansion Factor (KE)KE = 0.0018ΔTV = 0.0018 [0.72(TAX − TAN)+ 0 028αΙ]0.046 Standing Storage Losses (LS), lb/yr/tank LS = 365 VV WV KE KS 5.7 Maximum Annual Throughput (Q), gal/year Facility specific 67,558 Maximum Annual Throughput (Q), bbl/yr Throughput is in bbls (42 gal/bbl)1,609 Maximum Liquid Height (HLX), ft Assumed = 0.9HS 10 Tank Maximum Liquid Volume (VLX), ft3 VLX = π/4 D2HLX 4,043 Turnovers per period (N), dimensionless N = 5.614Q/VLX 2.2 Turnover Factor (KN), dimensionless For N ≤ 36 KN = 1, For N > 36 KN = (180 + N)/6N Working Loss Factor (KP), dimensionless For Organic Liquids, KP = 1 1.0 Working Losses (LW), lb/yr/tank LW = 0.0010MVPVAQKNKP 57 Total Uncontrolled Losses (LT), lb/yr TL = LS + LW 126 Total Uncontrolled Losses (LT), ton/yr 2,000 lb/ton 0.063 Notes: 1. Emissions calculated according to the methodology presented in AP-42, Section 7.1. 2. Tank parameters taken based on guidance from Peak Minerals used in the 2019 NOI inventory. 3. Meteorological data from AP-42, Table 7.1-7 for Salt Lake City, UT is used. 4. Paint solar absorptance from AP-42, Table 7.1-6. References: 1.0 EPA. 2020. AP-42, Section 7.1, Organic Liquid Storage Tanks. Available online at: https://www.epa.gov/sites/default/files/2020- 10/documents/ch07s01.pdf. June. Table 13 Processing Facility Tank Emissions Peak Minerals Inc. Delta, Utah Maximum Annual GHG Emissions PM10 PM2.5 NOx CO VOC SO2 CO2e Unpaved Road and Disturbed Area Travel (Fugitive Dust) 69 6.9 -- -- -- -- -- Off-Road Stationary Equipment (Exhaust) -- -- -- 15 -- -- -- Off-Road Equipment (Fugitive Dust) 16 4.9 -- -- -- -- -- Windblown Dust from Disturbed Areas (Fugitive Dust) 10 4.0 -- -- -- -- -- Processing Facility Operations 16 16 -- -- -- -- -- Combustion 0.5 0.5 12.47 0.0 1.07 0.040 10,689 Supporting Equipment1 --------0.071 ---- Total2 112 33 12 15 1.15 0.040 10,689 Notes: References: 2. Although PM10 emissions exceed 100 tpy, Title V is not triggered as the majority of PM10 emissions are fugitive dust sources. As per EPA (2003), emission units unlisted in source categories in 40 CFR §§ 51.165(a)(1)(iv)(c), such as unpaved road travel, are not included in determining major source applicability for Title V. Environmental Protection Agency (EPA). 2003. Clarification on Fugitive Emissions Policy. Available at: https://www.epa.gov/sites/default/files/2015- 08/documents/20030306.pdf Emissions Summary by Source Category - Annual Potential to Emit (tons/year) Table 14 Emissions Source Category Maximum Annual Emissions (tons/year) 3. Maximum annual Total HAP emissions represents the sum of maximum annual individual HAP emissions, which would not necessarily occur during the same year of Project Operation. 1. Supporting Equipment refers to the diesel dispensing facility and the processing facility tanks. Peak Minerals Inc. Delta, Utah Sevier Playa Potash Project # Table 15 Emissions Summary by Source Category - Maximum Daily Emissions (lb/day) Peak Minerals Inc. Sevier Playa Potash Project Delta, Utah PM10 PM2.5 NOx CO VOC SO2 Unpaved Road and Disturbed Area Travel (Fugitive Dust)466 47 -------- Off-Road Stationary Equipment (Exhaust)----0 119 0 -- Off-Road Equipment (Fugitive Dust)119 36 -------- Windblown Dust from Disturbed Areas (Fugitive Dust)401 160 -------- Processing Facility Operations 92 90 -- -- -- -- Combustion 3.9 3.8 93.3 0 8.7 0 Supporting Equipment1 --------0.39 -- Total 1,082 337 93 119 9 0.36 Notes: Emissions Source Category Maximum Daily Emissions (lb/day) 1.Supporting Equipment refers to the diesel dispensing facility and the processing facility tanks. Unpaved Road and Disturbed Area Travel (Fugitive Dust) Off-Road Stationary Equipment (Exhaust) Off-Road Equipment (Fugitive Dust) Windblown Dust from Disturbed Areas (Fugitive Dust) Processing Facility Operations1 Combustion Total 1 0 0.065 3.23 7.14 0 0 10 2 0 0.076 3.23 7.14 0 0 10 3 0 0 3.23 7.14 0 0 10 4 - 6 69 0 13 9.9 16 0.48 109 7 - 30 69 0 16 9.9 16 0.48 112 31 - 35 0 0 0 7.14 0 0.036 7.17 Notes: 1. Processing facility emissions conservatively represent maximum production capacity; in reality, production would ramp up from facility operation start in Project Year 6 to 100% production by Year 10. Project Years Annual Emissions (tpy) Table 16 PM10 Annual Emissions Summary Peak Minerals Inc. Delta, Utah Unpaved Road and Disturbed Area Travel (Fugitive Dust) Off-Road Stationary Equipment (Exhaust) Off-Road Equipment (Fugitive Dust) Windblown Dust from Disturbed Areas (Fugitive Dust) Processing Facility Operations1 Combustion Total 1 0 0.063 0.99 2.86 0 0 3.91 2 0 0.074 0.99 2.86 0 0 3.92 3 0 0 0.99 2.86 0 0 3.84 4 - 6 6.91 0 4.11 3.97 16 0.48 32 7 - 30 6.91 0 4.87 3.97 16 0.48 33 31 - 35 0 0 0 3.97 16 0.035 20 Notes: 1. Processing facility emissions conservatively represent maximum production capacity; in reality, production would ramp up from facility operation start in Project Year 6 to 100% production by Year 10. Project Years Annual Emissions (tpy) Table 17 PM2.5 Annual Emissions Summary Peak Minerals Inc. Delta, Utah Off-Road Stationary Equipment (Exhaust)Combustion Total 1 7.09 0 7.09 2 7.32 0 7.32 3000 4 - 30 0 12 12 31 - 35 0 0.67 0.67 Project Years Annual Emissions (tpy) Table 18 NOx Annual Emissions Summary Peak Minerals Inc. Delta, Utah Off-Road Stationary Equipment (Exhaust)Combustion Total 112012 215015 3000 4 - 30 0 8.10 8.10 31 - 35 0 1.30 1.30 Project Years Annual Emissions (tpy) Table 19 CO Annual Emissions Summary Peak Minerals Inc. Delta, Utah Off-Road Stationary Equipment (Exhaust) Supporting Equipment1 Combustion Total 1 0.58 0.071 0 0.65 2 0.70 0.071 0 0.77 3 0 0.071 0 0.071 4 - 30 0 0.071 1.07 1.15 31 - 35 0 0.071 0.076 0.15 Notes: Table 20 VOC Annual Emissions Summary Peak Minerals Inc. Delta, Utah 1. Supporting Equipment refers to the diesel dispensing facility and the processing facility tanks. Project Years Annual Emissions (tpy) Off-Road Stationary Equipment (Exhaust)Combustion Total 1 0.016 0 0.016 2 0.018 0 0.018 3000 4 - 30 0 0.040 0.040 31 - 35 0 0.0016 0.0016 Project Years Annual Emissions (tpy) Table 21 SO2 Annual Emissions Summary Peak Minerals Inc. Delta, Utah Off-Road Stationary Equipment (Exhaust)Combustion Total 1 1,747 0 1,747 2 2,135 0 2,135 3000 4 - 30 0 10,689 10,689 31 - 35 0 204 204 Project Years Annual Emissions (MT/year) Table 22 GHG (CO2e) Annual Emissions Summary Peak Minerals Inc. Delta, Utah Years 1 to 2 Years 4 - 30 Years 31 - 35 Pollutant Sources Fluid bed dryers 1.1E-04 Generator sets for pumps 0.010 Fire pump 2.7E-05 2.7E-05 Emergency generators 2.4E-05 2.4E-05 Pond mobile pumps 0.0058 0.0058 Propane Boiler 0.0E+00 MgCl2 Steam Boiler 2.6E-04 Total 0.01 0.0062 0.0058 Fluid bed dryers 7.0E-05 Generator sets for pumps 0.0012 Fire pump 3.2E-06 3.2E-06 Emergency generators 7.4E-06 7.4E-06 Pond mobile pumps 6.9E-04 6.9E-04 Propane Boiler 0.0E+00 MgCl2 Steam Boiler 1.6E-04 Total 0.001 0.0009 7.0E-04 Fluid bed dryers 2.1E-04 Generator sets for pumps 0.012 Fire pump 3.3E-05 3.3E-05 Emergency generators 7.3E-04 7.3E-04 Pond mobile pumps 0.0070 0.0070 Propane Boiler 0.0E+00 MgCl2 Steam Boiler 4.8E-04 Total 0.01 0.0084 0.0078 Fire pump 1.4E-06 1.4E-06 Generator sets for pumps 0.0005 Pond mobile pumps 2.9E-04 2.9E-04 Total 0.0005 2.9E-04 2.9E-04 Fluid bed dryers 2.5E-04 Propane Boiler 0.0E+00 MgCl2 Steam Boiler 5.6E-04 Total 0 0.0008 0 Fluid bed dryers 4.4E-04 Generator sets for pumps 0.015 Fire pump 4.1E-05 4.1E-05 Emergency generators 7.4E-05 7.4E-05 Pond mobile pumps 0.0088 0.0088 Propane Boiler 0.0E+00 MgCl2 Steam Boiler 0.0010 Total 0.02 0.010 0.0090 Table 23 HAP Annual Emissions Summary Peak Minerals Inc. Delta, Utah Acrolein Benzene Annual Emissions (tpy) 1,3Butadiene Ethyl benzene Formaldehyde Acetaldehyde Project Year Fluid bed dryers 1.6E-04 Propane Boiler 0.0E+00 MgCl2 Steam Boiler 3.7E-04 Total 0 5.4E-04 0.0E+00 Fluid bed dryers 7.8E-06 Generator sets for pumps 0.0011 Fire pump 3.0E-06 3.0E-06 Emergency generators 1.2E-04 1.2E-04 Pond mobile pumps 6.4E-04 6.4E-04 Propane Boiler 0.0E+00 MgCl2 Steam Boiler 1.8E-05 Total 0.001 7.9E-04 7.6E-04 Fluid bed dryers 2.6E-06 Generator sets for pumps 0.0022 Fire pump 5.9E-06 5.9E-06 Emergency generators 2.0E-04 2.0E-04 Pond mobile pumps 0.0013 0.0013 Propane Boiler 0.0E+00 MgCl2 Steam Boiler 5.9E-06 Total 0.002 0.0015 0.0015 Fluid bed dryers 9.5E-04 Generator sets for pumps 0.005 Fire pump 1.4E-05 1.4E-05 Emergency generators 2.6E-04 2.6E-04 Pond mobile pumps 0.0031 0.0031 Pond pumps 0.000 Propane Boiler 0.0000 MgCl2 Steam Boiler 0.0022 Total 0.005 0.0065 0.0033 Fluid bed dryers 7.0E-04 Generator sets for pumps 0.004 Fire pump 1.0E-05 1.0E-05 Emergency generators 1.8E-04 1.8E-04 Pond mobile pumps 0.0021 0.0021 Propane Boiler 0.0000 MgCl2 Steam Boiler 0.0016 Total 0.004 0.0047 0.0023 0.052 0.041 0.031 Hexane Naphthalene Total HAP emissions PAHs Toluene Xylenes Unpaved Road and Disturbed Area Travel (Fugitive Dust) Off-Road Stationary Equipment (Exhaust) Off-Road Equipment (Fugitive Dust) Windblown Dust from Disturbed Areas (Fugitive Dust) Processing Facility Operations1 Combustion Total 1 0 0.44 23 288 0 0 312 2 0 0.59 23 288 0 0 312 3 0 0 23 288 0 0 312 4 - 6 466 0 96 401 92 3.86 1,060 7 - 30 466 0 119 401 92 3.86 1,082 31 - 35 0 0 0 288 0 1.16 289 Notes: 1. Processing facility emissions conservatively represent maximum production capacity; in reality, production would ramp up from facility operation start in Project Year 6 to 100% production by Year 10. Table 24 PM10 Daily Emissions Summary Peak Minerals Inc. Delta, Utah Project Year Daily Emissions (lb/day) Unpaved Road and Disturbed Area Travel (Fugitive Dust) Off-Road Stationary Equipment (Exhaust) Off-Road Equipment (Fugitive Dust) Windblown Dust from Disturbed Areas (Fugitive Dust) Processing Facility Operations1 Combustion Total 1 0 0.42 7.18 115 0 0 123 2 0 0.57 7.18 115 0 0 123 3 0 0 7.18 115 0 0 122 4 -6 47 0 29 160 90 3.82 330 7 - 30 47 0 36 160 90 3.82 337 31 - 35 0 0 0 115 0 1.12 116 Notes: 1. Processing facility emissions conservatively represent maximum production capacity; in reality, production would ramp up from facility operation start in Project Year 6 to 100% production by Year 10. Project Years Daily Emissions (lb/day) Table 25 PM2.5 Daily Emissions Summary Peak Minerals Inc. Delta, Utah Off-Road Stationary Equipment (Exhaust)Combustion Total 151051 254054 3000 4 - 30 0 93 93 31 - 35 0 21 21 Table 26 NOx Daily Emissions Summary Peak Minerals Inc. Delta, Utah Project Years Daily Emissions (lb/day) Off-Road Stationary Equipment (Exhaust)Combustion Total 182082 2 119 0 119 3000 4 - 30 0 92 92 31 - 35 0 51 51 Project Years Daily Emissions (lb/day) Table 27 CO Daily Emissions Summary Peak Minerals Inc. Delta, Utah Off-Road Stationary Equipment (Exhaust) Supporting Equipment1 Combustion Total 1 3.86 0.39 0 4.25 2 5.38 0.39 0 5.77 3 0 0.39 0 0.39 4 - 30 0 0.39 8.74 9.12 31 - 35 0 0.39 2.65 3.04 Notes: 1. Supporting Equipment refers to the diesel dispensing facility and the processing facility tanks. Table 28 VOC Daily Emissions Summary Peak Minerals Inc. Delta, Utah Project Year Daily Emissions (lb/day) Off-Road Stationary Equipment (Exhaust)Combustion Total 10.1100.11 20.1400.14 3000 4 - 30 0 0.36 0.36 31 - 35 0 0.058 0.058 Project Year Daily Emissions (lb/day) Table 29 SO2 Daily Emissions Summary Peak Minerals Inc. Delta, Utah Years 1 to 2 Years 4 - 30 Years 31 - 35 Pollutant Sources Fluid bed dryers 6.8E-04 Generator sets for pumps 0.078 Fire pump 5.4E-04 5.4E-04 Emergency generators 4.7E-04 4.7E-04 Pond mobile pumps 0.0077 0.0077 Propane Boiler 0 MgCl2 Steam Boiler 0.0016 Total 0.078 0.011 0.0087 Fluid bed dryers 4.3E-04 Generator sets for pumps 0.0094 Fire pump 6.5E-05 6.5E-05 Emergency generators 1.5E-04 1.5E-04 Pond mobile pumps 9.3E-04 9.3E-04 Propane Boiler 0 MgCl2 Steam Boiler 0.0010 Total 0.0094 0.0026 0.0011 Fluid bed dryers 0.0013 Generator sets for pumps 0.095 Fire pump 6.5E-04 6.5E-04 Emergency generators 0.015 0.015 Pond mobile pumps 0.0094 0.0094 Propane Boiler 0 MgCl2 Steam Boiler 0.0029 Total 0.095 0.029 0.025 Fire pump 2.7E-05 2.7E-05 Generator sets for pumps 0.0040 Pond mobile pumps 3.9E-04 3.9E-04 Total 0.0040 4.2E-04 4.2E-04 Fluid bed dryers 0.0015 Propane Boiler 0 MgCl2 Steam Boiler 0.0034 Total 0 0.0049 0 Daily Emissions (lb/day) Acetaldehyde Acrolein Benzene 1,3Butadiene Ethyl benzene Project Year Table 30 HAP Daily Emissions Summary Peak Minerals Inc. Delta, Utah Fluid bed dryers 0.0027 Generator sets for pumps 0.12 Fire pump 8.3E-04 8.3E-04 Emergency generators 0.0015 0.0015 Pond mobile pumps 0.012 0.012 Propane Boiler 0 MgCl2 Steam Boiler 0.0062 Total 0.12 0.023 0.014 Fluid bed dryers 0.0010 Propane Boiler 0 MgCl2 Steam Boiler 0.0023 Total 0 0.0033 0 Fluid bed dryers 4.7E-05 Generator sets for pumps 0.0086 Fire pump 5.9E-05 5.9E-05 Emergency generators 0.0024 0.0024 Pond mobile pumps 8.5E-04 8.5E-04 Propane Boiler 0 MgCl2 Steam Boiler 1.1E-04 Total 0.0086 0.0035 0.0034 Fluid bed dryers 1.6E-05 Generator sets for pumps 0.017 Fire pump 1.2E-04 1.2E-04 Emergency generators 0.0040 0.0040 Pond mobile pumps 0.0017 0.0017 Propane Boiler 0 MgCl2 Steam Boiler 3.6E-05 Total 0.017 0.0058 0.0058 Fluid bed dryers 0.0058 Generator sets for pumps 0.042 Fire pump 2.9E-04 2.9E-04 Emergency generators 0.0053 0.0053 Pond mobile pumps 0.0041 0.0041 Propane Boiler 0 MgCl2 Steam Boiler 0.013 Total 0.042 0.029 0.010 Fluid bed dryers 0.0043 Generator sets for pumps 0.029 Fire pump 2.0E-04 2.0E-04 Emergency generators 0.0036 0.0036 Pond mobile pumps 0.0029 0.0029 Propane Boiler 0 MgCl2 Steam Boiler 0.010 Total 0.029 0.021 0.0067 0.40 0.13 0.075 Toluene Total HAP emissions Xylenes Formaldehyde Hexane Naphthalene PAHs Years 1 to 2 Years 4 - 30 Years 31 - 35 Pollutant Sources Fluid bed dryers 2.8E-05 Generator sets for pumps 0.0032 Fire pump 5.4E-04 5.4E-04 Emergency generators 4.7E-04 4.7E-04 Pond mobile pumps 3.2E-04 3.2E-04 Propane Boiler 0 MgCl2 Steam Boiler 0 Total 0.0032 0.0014 0.0013 Fluid bed dryers 1.8E-05 Generator sets for pumps3.9E-04 Fire pump 6.5E-05 6.5E-05 Emergency generators 1.5E-04 1.5E-04 Pond mobile pumps 3.9E-05 3.9E-05 Propane Boiler 0 MgCl2 Steam Boiler 4.1E-05 Total 3.9E-04 3.1E-04 2.5E-04 Fluid bed dryers 5.3E-05 Generator sets for pumps 0.0040 Fire pump 6.5E-04 6.5E-04 Emergency generators 0.015 0.015 Pond mobile pumps 3.9E-04 3.9E-04 Propane Boiler 0 MgCl2 Steam Boiler 1.2E-04 Total 0.0040 0.016 0.016 Fire pump 2.7E-05 2.7E-05 Generator sets for pumps1.7E-04 Pond mobile pumps 1.6E-05 1.6E-05 Total 1.7E-04 4.4E-05 4.4E-05 Fluid bed dryers 6.2E-05 Propane Boiler 0 0 MgCl2 Steam Boiler 1.4E-04 Total 0 2.1E-04 0 Fluid bed dryers 1.1E-04 Generator sets for pumps 0.0050 Fire pump 8.3E-04 8.3E-04 Emergency generators 0.0015 0.0015 Pond mobile pumps 5.0E-04 5.0E-04 Propane Boiler 0 MgCl2 Steam Boiler 2.6E-04 Total 0.0050 0.0032 0.0028 Fluid bed dryers 4.1E-05 Propane Boiler 0 MgCl2 Steam Boiler 9.5E-05 Total 0 1.4E-04 0 Table 31 HAP Hourly Emissions Summary Peak Minerals Inc. Delta, Utah Hourly Emissions (lb/hr) 1,3Butadiene Project Year Acetaldehyde Acrolein Benzene Ethyl benzene Formaldehyde Hexane Fluid bed dryers 2.0E-06 Generator sets for pumps3.6E-04 Fire pump 5.9E-05 5.9E-05 Emergency generators 0.0024 0.0024 Pond mobile pumps 3.6E-05 3.6E-05 Propane Boiler 0 MgCl2 Steam Boiler 4.5E-06 Total 3.6E-04 0.0025 0.0025 Fluid bed dryers 6.6E-07 Generator sets for pumps7.1E-04 Fire pump 1.2E-04 1.2E-04 Emergency generators 0.0040 0.0040 Pond mobile pumps 7.1E-05 7.1E-05 Propane Boiler 0 MgCl2 Steam Boiler 1.5E-06 Total 7.1E-04 0.0042 0.0042 Fluid bed dryers 2.4E-04 Generator sets for pumps 0.0017 Fire pump 2.9E-04 2.9E-04 Emergency generators 0.0053 0.0053 Pond mobile pumps 1.7E-04 1.7E-04 Propane Boiler 0 MgCl2 Steam Boiler 5.5E-04 Total 0.0017 0.0065 0.0057 Fluid bed dryers 1.8E-04 Generator sets for pumps 0.0012 Fire pump 2.0E-04 2.0E-04 Emergency generators 0.0036 0.0036 Pond mobile pumps 1.2E-04 1.2E-04 Propane Boiler 0 MgCl2 Steam Boiler 4.1E-04 Total 0.0012 0.0045 0.0039 0.017 0.039 0.039 Xylenes Total HAP emissions Naphthalene PAHs Toluene APPENDIX D BACT SUPPORTING DOCUMENTATION Table D-1 Inputs for Oxidation Control Cost Calculations Peak Minerals Inc. Delta, Utah Parameter Pump Generator Set 4 Engine1 Annual Hours of Operation (hrs/yr)8,760 Uncontrolled CO Emissions (tpy)5.0 Uncontrolled VOC Emissions (tpy)0.20 Oxidation CO Control Efficiency2 98.0% Oxidation VOC Control Efficiency2 99.0% Pollutant Removed (tpy)3 5.11 Engine Exhaust Gas Flow Rate (scfm)4 20 Control Equipment Life (yrs)5 2 Interest Rate6 4.25% Capital Recovery Factor (CRF)7 0.532 Notes: 2. Control efficiencies from EPA's Air Pollution Control Technology Fact Sheets for Regenerative Incinerators (EPA-452/F-03-021, https://nepis.epa.gov/Exe/ZyPURL.cgi?Dockey=P1008OH5.TXT) and Catalytic Incinerators (EPA-452/F-03-018, https://www3.epa.gov/ttnchie1/mkb/documents/fcataly.pdf). 1. Control cost effectiveness calculations were prepared for the largest non- emergency stationary engine (Pump Generator Set 4). 7. Calculated using Equation 2.8a of the USEPA's OAQPS Air Pollution Control Cost Manual, Section 1 - Introduction, Chapter 2 - Cost Estimation: Concepts and Methodology (Nov. 2017). 6. Per the example problem in Table 2.12 of the USEPA's OAQPS Air Pollution Control Cost Manual, 7th ed., Section 3.2 - VOC Destruction Controls, Chapter 2 - Incinerators and Oxidizers (Nov. 2017). 5. The stationary pump engines will be in operation for Project Years 1 and 2. 4. Calculated based on the stack diameter, exit velocity, and exit gas temperature from the model input files. 3. The total mass of pollutant removed is based on the combined quantities for CO and VOC emissions removed from the use of an oxidation control device. Parameter Pump Generator Set 4 Engine OAQPS Manual Equation1 Purchased Equipment Costs Incinerator + auxiliary equipment2 730 A Instrumentation 73 0.10 × A Sales taxes 22 0.03 × A Freight 37 0.05 × A Purchased Equipment Cost, PEC 861 B = 1.18 × A Direct Installation Costs Foundation & supports 69 0.08 × B Handling & erection 121 0.14 × B Electrical 34 0.04 × B Piping 17 0.02 × B Insulation for ductwork 9 0.01 × B Painting 9 0.01 × B Direct Installation Cost 258 C = 0.30 × B Indirect Costs Engineering 86 0.10 × B Construction & field expense 43 0.05 × B Contractor fees 86 0.10 × B Start-up 17 0.02 × B Performance test 9 0.01 × B Total Indirect Cost 241 D = 0.28 × B Contingencies 136 E = 0.10 × (B + C + D) Total Capital Investment 1,497 TCI = B + C + D + E Direct Annual Costs Operator labor3 14,618 F Supervisor labor 2,193 G = 0.15 × F Maintenance labor3 14,919 H Maintenance material 14,919 I = 1 × H Catalyst replacement4 0J Fuel5 39,589 K Electricity6 5,488 L Total Direct Annual Costs 91,727 DAC = F + G + H + I + J + K + L Indirect Annual Costs Overhead 27,990 M = 0.6 × (F + G + H + I) Administrative charges 30 N = 0.02 × TCI Property tax 15 O = 0.01 × TCI Insurance 15 P = 0.01 × TCI Capital recovery 797 Q = CRF × TCI Total Indirect Annual Costs 28,846 IAC = M + N + O + P + Q Total Annual Cost 120,573 TAC = DAC + IAC Pollutant Removed (tpy)5.11 Average Cost Effectiveness ($/ton) 23,615 $/ton = TAC / Pollutant Removed Notes: 6. Based on the electricity costs in the example problem in Table 2.12 of the Manual, Section 3.2, Chapter 2, multiplied by the ratio of the fuel costs calculated above for this operation to the fuel costs for the control device in the example problem. 3. Based on the labor costs in the example problem in Table 2.12 of the Manual, Section 3.2, Chapter 2, multiplied by the ratio of the hours of operation for the source to the hours of operation for the control device in the example problem. 4. Catalyst costs were conservatively set equal to zero for the purposes of this control cost evaluation. Table D-2 Oxidation Control Cost Calculations Peak Minerals Inc. Delta, Utah 1. Equations from Tables 2.10 and 2.12 of the USEPA's OAQPS Air Pollution Control Cost Manual, 7th ed., Section 3.2 - VOC Destruction Controls, Chapter 2 - Incinerators and Oxidizers (Nov. 2017). 2. Estimated based on the lower end of the range for equipment costs from EPA's Air Pollution Control Technology Fact Sheets for Regenerative Incinerators (EPA-452/F-03-021,https://nepis.epa.gov/Exe/ZyPURL.cgi?Dockey=P1008OH5.TXT) and Catalytic Incinerators (EPA-452/F-03-018, https://www3.epa.gov/ttnchie1/mkb/documents/fcataly.pdf). The cost was adjusted for inflation using the ratio of the consumer price index (CPI) values for 2023 to 1998, from the Federal Reserve Bank of Minneapolis: https://www.minneapolisfed.org/community/financial-and-economic-education/cpi-calculator- information/consumer-price-index-and-inflation-rates-1913 5. Calculated using the equation from the example problem in Table 2.12 of the Manual, Section 3.2, Chapter 2. Table D-3 Inputs for Baghouse, Scrubber, and Cyclone Control Cost Calculations Peak Minerals Inc. Delta, Utah Bagging Plant Transfer Conveyor Bagging Plant Accumulating Conveyor PM10 Emission Factor (lb/ton)2 5.0E-04 5.0E-04 Process Rate (tph)33 33 Annual Hours of Operation (hrs/yr)7,880 7,880 Uncontrolled PM10 Emissions (tpy)0.064 0.064 Baghouse Control Efficiency3 99.9% 99.9% Pollutant Removed by Baghouse (tpy)0.064 0.064 Scrubber Control Efficiency4 99% 99% Pollutant Removed by Scrubber (tpy)0.064 0.064 Cyclone Control Efficiency5 90% 90% Pollutant Removed by Cyclone (tpy)0.058 0.058 PM10 Inlet Grain Loading (gr/ft3) 6 0.1 0.1 Control Device Gas Flow Rate (cfm)20 20 Control Equipment Life (yrs)7 35 35 Interest Rate8 7% 7% Capital Recovery Factor (CRF)9 0.077 0.077 Notes: 2. See potential emissions calculations for additional details. 9. Calculated using Equation 2.8a of the USEPA's OAQPS Air Pollution Control Cost Manual, Section 1 - Introduction, Chapter 2 - Cost Estimation: Concepts and Methodology (Nov. 2017). 4. Conservative estimate for the PM10 design efficiency of a wet scrubber, per the USEPA's Air Pollution Control Technology Fact Sheet for Mechanically-Aided Scrubbers (EPA-452/F-03-013, https://www3.epa.gov/ttn/catc/dir1/fmechcal.pdf) and Venturi Scrubbers (EPA-452/F-03-017, https://www3.epa.gov/ttn/catc/dir1/fventuri.pdf). 5. Conservative estimate for the PM10 design efficiency of a cyclone, per the USEPA's Air Pollution Control Technology Fact Sheet for Cyclones (EPA-452/F-03-005, https://www3.epa.gov/ttncatc1/dir1/fcyclon.pdf). 1. Control cost effectiveness calculations were prepared for the two largest PM-emitting sources without baghouse controls nor enclosure at the processing facility. Parameter Processing Facility1 3. Conservative estimate for the design efficiency of a new fabric filter, per the USEPA's Air Pollution Control Technology Fact Sheet for Fabric Filter - Pulse-Jet Cleaned Type (EPA-452/F-03-025, https://www3.epa.gov/ttnchie1/mkb/documents/ff-pulse.pdf). 6. It was estimated that a control device for these sources would have a similar inlet grain loading to Peak's other material handling baghouses. 8. Per the example problem in Table 1.11 of the USEPA's OAQPS Air Pollution Control Cost Manual, 6th ed. (EPA-452/B-02-001), Section 6 - Particulate Matter Controls, Chapter 1 - Baghouses and Fabric Filters (Dec. 1998). 7. The sources will be in operation from Project Years 4-30. Parameter Bagging Plant Transfer Conveyor Bagging Plant Accumulating Conveyor OAQPS Manual Equation1 Purchased Equipment Costs Fabric filter + bags + auxiliary equipment2 60 60 A Instrumentation 6 6 0.10 × A Sales taxes 2 2 0.03 × A Freight 3 3 0.05 × A Purchased Equipment Cost, PEC 71 71 B = 1.18 × A Direct Installation Costs Foundation & supports 3 3 0.04 × B Handling & erection 35 35 0.50 × B Electrical 6 6 0.08 × B Piping 1 1 0.01 × B Insulation for ductwork 5 5 0.07 × B Painting 3 3 0.04 × B Direct Installation Cost 52 52 C = 0.74 × B Indirect Costs Engineering 7 7 0.10 × B Construction & field expense 14 14 0.20 × B Contractor fees 7 7 0.10 × B Start-up 1 1 0.01 × B Performance test 1 1 0.01 × B Contingencies 2 2 0.03 × B Total Indirect Cost 32 32 D = 0.45 × B Total Capital Investment 155 155 TCI = B + C + D Direct Annual Costs Operator labor3 34,002 34,002 E Supervisor labor 5,100 5,100 F = 0.15 × E Maintenance labor3 17,474 17,474 G Maintenance material 17,474 17,474 H = 1 × G Replacement parts, bags4 11 I Electricity5 66 J Compressed air5 55 K Total Direct Annual Costs 74,062 74,062 DAC = E + F + G + H + I + J + K Indirect Annual Costs Overhead 44,430 44,430 L = 0.6 × (E + F + G + H) Administrative charges 3 3 M = 0.02 × TCI Property tax 2 2 N = 0.01 × TCI Insurance 2 2 O = 0.01 × TCI Capital recovery 12 12 P = CRF × TCI Total Indirect Annual Costs 44,448 44,448 IAC = L + M + N + O + P Total Annual Cost 118,510 118,510 TAC = DAC + IAC Pollutant Removed (tpy)0.06 0.06 Average Cost Effectiveness ($/ton) 1,841,085 1,841,085 $/ton = TAC / Pollutant Removed Notes: 6. Per Section IV.D.2.b. of EPA's New Source Review Workshop Manual: Prevention of Significant Deterioration and Nonattainment Area Permitting (draft, October 1990). 3. Based on the labor costs in the example problem in Table 1.11 of the Manual, Section 6, Chapter 1, multiplied by the ratio of the hours of operation for the source to the hours of operation for the baghouse in the example problem. 4. The total cloth area (ft2) was estimated using an air-to-cloth ratio of 9 cfm/ft2, the typical value for a pulse jet baghouse controlling rock dust per Table 1.1 of the Manual, Section 6, Chapter 1. A bag price of $0.50/ft2 (1998$) was used as the lowest bag price for any type of pulse jet bag per Table 1.8. An annual CRF of 0.5531 was used per the example problem in Table 1.11, which assumes the bags are replaced every two years at a 7% inflation rate. Lastly, the cost was adjusted for inflation using the ratio of the consumer price index (CPI) values for 2023 to 1998, from the Federal Reserve Bank of Minneapolis: https://www.minneapolisfed.org/community/financial-and-economic-education/cpi-calculator-information/consumer-price-index-and-inflation-rates-1913 5. Calculated using the equations from the example problem in Table 1.11 of the Manual, Section 6, Chapter 1. A pressure drop of 3" H2O was assumed for each Table D-4 Baghouse Control Cost Calculations Peak Minerals Inc. Delta, Utah 1. Equations from Tables 1.9, 1.10, and 1.11 of the USEPA's OAQPS Air Pollution Control Cost Manual, 6th ed. (EPA-452/B-02-001), Section 6 - Particulate Matter Controls, Chapter 1 - Baghouses and Fabric Filters (Dec. 1998). 2. Estimated based on the materials cost for the smallest of the processing facility baghouses ($19,050 for the Glazing Dryer/Cooler Baghouse) multiplied by the ratio of the estimated exhaust gas flow rate for the source being evaluated to the exhaust gas flow rate for the Storage Baghouse (6,769 acfm). Parameter Bagging Plant Transfer Conveyor Bagging Plant Accumulating Conveyor OAQPS Manual Equation1 Purchased Equipment Costs Equipment costs2 70 70 A Instrumentation 7 7 0.10 × A Sales taxes 2 2 0.03 × A Freight 4 4 0.05 × A Purchased Equipment Cost, PEC 83 83 B = 1.18 × A Direct Installation Costs Foundation & supports 5 5 0.06 × B Handling & erection 33 33 0.40 × B Electrical 1 1 0.01 × B Piping 4 4 0.05 × B Insulation for ductwork 2 2 0.03 × B Painting 1 1 0.01 × B Direct Installation Cost 46 46 C = 0.56 × B Indirect Costs Engineering 8 8 0.10 × B Construction & field expense 8 8 0.10 × B Contractor fees 8 8 0.10 × B Start-up 1 1 0.01 × B Performance test 1 1 0.01 × B Contingencies 2 2 0.03 × B Total Indirect Cost 29 29 D = 0.35 × B Total Capital Investment 158 158 TCI = B + C + D Direct Annual Costs Operator labor3 59,100 59,100 E Supervisor labor 8,865 8,865 F = 0.15 × E Maintenance labor3 19,700 19,700 G Maintenance material 19,700 19,700 H = 1 × G Utilities4 00 I Operating materials4 00 J Wastewater disposal4 00 K Total Direct Annual Costs 107,365 107,365 DAC = E + F + G + H + I + J + K Indirect Annual Costs Overhead 64,419 64,419 L = 0.6 × (E + F + G + H) Administrative charges 3 3 M = 0.02 × TCI Property tax 2 2 N = 0.01 × TCI Insurance 2 2 O = 0.01 × TCI Capital recovery 12 12 P = CRF × TCI Total Indirect Annual Costs 64,437 64,437 IAC = L + M + N + O + P Total Annual Cost 171,802 171,802 TAC = DAC + IAC Pollutant Removed (tpy)0.064 0.064 Average Cost Effectiveness ($/ton)2,693,255 2,693,255 $/ton = TAC / Pollutant Removed Notes: 5. Per Section IV.D.2.b. of EPA's New Source Review Workshop Manual: Prevention of Significant Deterioration and Nonattainment Area Permitting (draft, October 1990). 3. Based on the labor costs in the example problem in Section 2.7 of the Manual, Section 6, Chapter 2, multiplied by the ratio of the hours of operation for the source to the hours of operation for the scrubber in the example problem. 4. Annual costs for utilities, operating materials, and wastewater disposal were conservatively set equal to zero for the purposes of this control cost evaluation. Table D-5 Scrubber Control Cost Calculations Peak Minerals Inc. Delta, Utah 1. Equations from Tables 2.8 and 2.9 of the USEPA's OAQPS Air Pollution Control Cost Manual, 6th ed. (EPA-452/B-02-001), Section 6 - Particulate Matter Controls, Chapter 2 - Wet Scrubbers for Particulate Matter (Jul. 2002). 2. Estimated based on the lower end of the range for equipment costs from EPA's Air Pollution Control Technology Fact Sheets for Mechanically-Aided Scrubbers (EPA-452/F-03-013, https://www3.epa.gov/ttn/catc/dir1/fmechcal.pdf) and Venturi Scrubbers (EPA-452/F- 03-017, https://www3.epa.gov/ttn/catc/dir1/fventuri.pdf). The cost was adjusted for inflation using the ratio of the consumer price index (CPI) values for 2018 to 2002, from the Federal Reserve Bank of Minneapolis: https://www.minneapolisfed.org/community/financial-and- economic-education/cpi-calculator-information/consumer-price-index-and-inflation-rates-1913 Parameter Bagging Plant Transfer Conveyor Bagging Plant Accumulating Conveyor OAQPS Manual Equation1 Purchased Equipment Costs Equipment costs2 120 120 A Instrumentation 12 12 0.10 × A Sales taxes 4 4 0.03 × A Freight 6 6 0.05 × A Purchased Equipment Cost, PEC 142 142 B = 1.18 × A Direct Installation Costs Foundation & supports 6 6 0.04 × B Handling & erection 71 71 0.50 × B Electrical 11 11 0.08 × B Piping 1 1 0.01 × B Insulation for ductwork 10 10 0.07 × B Painting 6 6 0.04 × B Direct Installation Cost 105 105 C = 0.74 × B Indirect Costs Engineering 14 14 0.10 × B Construction & field expense 28 28 0.20 × B Contractor fees 14 14 0.10 × B Start-up 1 1 0.01 × B Performance test 1 1 0.01 × B Contingencies 4 4 0.03 × B Total Indirect Cost 64 64 D = 0.45 × B Total Capital Investment 310 310 TCI = B + C + D Direct Annual Costs Annual Operating & Maintenance Cost2 237 237 DAC Indirect Annual Costs Overhead 142 142 D = 0.6 × DAC Administrative charges 6 6 E = 0.02 × TCI Property tax 3 3 F = 0.01 × TCI Insurance 3 3 G = 0.01 × TCI Capital recovery 24 24 H = CRF × TCI Total Indirect Annual Costs 178 178 IAC = D + E + F + G + H Total Annual Cost 415 415 TAC = DAC + IAC Pollutant Removed (tpy)0.058 0.06 Average Cost Effectiveness ($/ton) 7,158 7,158 $/ton = TAC / Pollutant Removed Total Annual Cost - Cyclone ($/yr)415 415 -- Total Annual Cost - Enclosure ($/yr)3 24 24 -- Controlled PM10 Emissions - Cyclone (tpy)0.01 0.01 -- Controlled PM10 Emissions - Enclosure (tpy)4 0.02 0.02 -- Incremental Cost Effectiveness ($/ton)5 30,352 30,352 (cyclone cost - enclosure cost) / (enclosure emissions - cyclone emissions) Notes: 3. The only costs associated with the conveyors are additional materials for the covering. The annualized capital recovery costs for these materials were conservatively assumed to be equal to the annualized capital recovery costs for a cyclone. 5. Per Section IV.D.2.b. of EPA's New Source Review Workshop Manual: Prevention of Significant Deterioration and Nonattainment Area Permitting (draft, October 1990). Table D-6 Cyclone Control Cost Calculations Peak Minerals Inc. Delta, Utah 1. Equations from Tables 1.9, 1.10, and 1.11 of the USEPA's OAQPS Air Pollution Control Cost Manual, 6th ed. (EPA-452/B-02-001), Section 6 - Particulate Matter Controls, Chapter 1 - Baghouses and Fabric Filters (Dec. 1998). 2. Capital costs and annual operating and maintenance costs for a cyclone per the USEPA's Air Pollution Control Technology Fact Sheet for Cyclones (EPA- 452/F-03-005, https://www3.epa.gov/ttncatc1/dir1/fcyclon.pdf). Per the Fact Sheet, "As a rule, smaller units controlling a waste stream with a low PM concentration will be more expensive (per unit volumetric flow rate and per quantity of pollutant controlled) than a large unit controlling a waste stream with a high concentration." As such, the higher end of the cost ranges provided were used. The costs were adjusted for inflation using the ratio of the consumer price index (CPI) values for 2023 to 2002, from the Federal Reserve Bank of Minneapolis: https://www.minneapolisfed.org/community/financial-and-economic- education/cpi-calculator-information/consumer-price-index-and-inflation-rates-1913 4. A control efficiency of 70% was applied for uncontrolled, enclosed sources, consistent with TCEQ guidance: https://www.tceq.texas.gov/permitting/air/nav/air_bact_mechsource.html Parameter Site Roads Uncontrolled PM10 Emissions (tpy)460 Paving Control Efficiency1 95% Operational Life (yrs)2 35 Interest Rate3 7% Capital Recovery Factor (CRF)4 0.077 Road Length (mi)21 Capital Cost per Mile Paved ($/mi)1,000,000 Total Capital Investment (TCI) 21,000,000 Total Annual Cost (TAC)5 1,621,913 Pollutant Removed (tpy)437.00 Average Cost Effectiveness ($/ton)6 3,711 Controlled PM10 Emissions - Paving, Vacuum Sweeping, and Watering (tpy)23.00 Controlled PM10 Emissions - Chemical Suppressant and Watering (tpy)7 69.00 Incremental Cost Effectiveness ($/ton)8 35,259 Notes: 7. Application of a chemical suppressant and watering results in an 85% control efficiency for fugitive dust from unpaved roads, per UDAQ's Emission Factors for Paved and Unpaved Haul Roads guidelines (Jan. 12, 2015). 8. It was assumed that the annual operating and maintenance costs are similar for paved roads with vacuum sweeping and watering as for unpaved roads with chemical suppressant application and watering. Therefore, the incremental cost effectiveness was calculated as: Incremental Cost Effectiveness ($/ton) = (TAC for Paving) / [Controlled PM10 Emissions from Chemical Suppressant and Watering (tpy) - Controlled PM10 Emissions from Paving, Vacuum Sweeping, and Watering (tpy)] 3. Per the example problem in Table 1.11 of the USEPA's OAQPS Air Pollution Control Cost Manual, 6th ed. (EPA-452/B-02-001), Section 6 - Particulate Matter Controls, Chapter 1 - Baghouses and Fabric Filters (Dec. 1998). 4. Calculated using Equation 2.8a of the USEPA's OAQPS Air Pollution Control Cost Manual, Section 1 - Introduction, Chapter 2 - Cost Estimation: Concepts and Methodology (Nov. 2017). Table D-7 Paved Roads Control Cost Calculations Peak Minerals Inc. Delta, Utah 1. Maximum control efficiency from paving, per UDAQ's Emission Factors for Paved and Unpaved Haul Roads guidelines (Jan. 12, 2015). 2. The site roads will be in operation from Project Years 1-35. 5. TAC = TCI × CRF 6. $/ton = TAC / Pollutant Removed APPENDIX E HAP SCREENING SUMMARY HAP Health Classification Minimum Threshold Value (lb/hr) Maximum Emissions (lb/hr) Exceed Threshold? Acetaldehyde Acute 1.71 0.0032 No Acrolein Acute 0.01 3.9E-04 No Benzene (incl.benzene for gas)A1 Carc. 0.08 0.016 No 1,3-Butadiene A2 Carc. 0.08 1.7E-04 No Ethyl benzene Chronic 4.43 2.1E-04 No Formaldehyde Acute/Carc. 0.01 0.0050 No Hexane Chronic 8.99 1.4E-04 No Naphthalene Chronic 2.67 0.0025 No Toluene Chronic 3.84 0.0065 No Xylenes (isomers and mixture)Chronic 22.14 0.0045 No Notes 1 Table E-1 HAP Screening Summary Peak Minerals Inc. Delta, Utah Minimum threshold values taken from UAC307-410-5. APPENDIX F DETAILED PROCESS FLOW DIAGRAMS EQUIPMENT SYMBOLOGY EQUIPMENT DESCRIPTION CODES M DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 0 0 0 0 - P R P F - 0 0 1 - L E G E N D . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 8 : 1 9 : 4 6 A M SA V E D : 1 3 1214 - 0000 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE LEGEND PROCESS FLOW DIAGRAM PEAK MINERALS INC. VERTICAL TURBINE PUMP SUMP PUMP POSITIVE DISPLACEMENT PUMP METERING DOSING PUMP AXIAL PUMP VACUUM PUMP CENTRIFUGAL PUMP FAN/BLOWER OIL SEPARATION FILTER BAGHOUSE FLUID BED DRYER CONED ROOF TANK ELECTRIC HEATING COIL STORAGE TANK (CLOSED) AIR RECEIVER VACUUM TANK CENTRIFUGAL COMPRESSOR AGITATOR SLIDE GATE CONDITIONING DRUM MAGNET PUMP BOX HOT WELL STORAGE TANK (OPEN) SLAKER FLAKING SYSTEM THICKENER/CLARIFIER DIVERTER BULK BAG DIESEL FILLING STATION TOTE SILO/HOOPER CAGE MILL HAMMER MILL FLAKE BREAKER ROLL CRUSHER FLEX CHUTE DEAERATOR STEAM BOILER 2 DECK SCREEN 1 DECK SCREEN / GRIZZLY FILTER PRESS HYDROCYCLONE / CYCLOPACK ROTARY VALVE PLATE HEAT EXCHANGER HEAT EXCHANGER SHELL AND TUBE HEAT EXCHANGER CYCLONE VACUUM BELT FILTER CENTRIFUGE APRON FEEDER BUCKET ELEVATOR SCREW CONVEYOR DRAG CONVEYOR BELT CONVEYOR BAG HOUSE FILTER BASKET FILTER AIR FILTER HOPPER COMPACTOR LOADOUT SILO BAROMETRIC CONDENSER BURNER DESICCANT AIR DRYER REFRIGERANT DRYER VACUUM KNOCKOUT POT FLOTATION CELL GENERATOR FALLING FILM / EVAPORATOR REACTOR CRYSTALLIZER PRESSURE VESSEL STACK COLUMN COOLER DREDGE COOLING TOWER DISTRIBUTOR WEIGH DEVICE MIXING PIT POND CHILLER STORAGE PILE DUMP STATION FRONT END LOADER FLAT BED TRUCK TANKER TRUCK DUMP TRUCK MOBILE PUMP FORKLIFT SAND FILTER TRUCK SCALE CRANE HOIST MONORAIL PADDLE MIXER DIAPHRAM PUMP PA 07 APR'23 YD AL JB MR INTERNAL REVIEW EXCAVATOR GRADER BULLDOZERTANDEM TRUCK AND TRAILER PB 19 MAY'23 CLIENT REVIEW ZOOM BOOM 2131-PP-101/102 S 1401 PLAYA BRINE 1310 2132-PP-400/410 S 2210-PRPF-001 3360-PRPF-001 PLAYA BRINE 2121-PP-101/111 S 1403 2620 DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 2 1 0 0 - P R P F - 0 0 1 - B R I N E E X T R A C T I O N . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 7 / 2 0 2 3 1 1 : 4 9 : 3 1 A M SA V E D : 1 3 1214 - 2100 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE BRINE EXTRACTION PROCESS FLOW DIAGRAM PEAK MINERALS INC. TO PLAYA BRINE PUMP BOX 3360-TK-001 TO PRE-CONCENTRATION POND P1 2211-PD-101 PA 06 APR'23 YD AL JB MR INTERNAL REVIEW NOTES: 1.WATER FROM RECHARGE NETWORK WILL SEEP THROUGH PLAYA AND FILL EXTRACTION NETWORK WITH BRINE. 2.EACH PUMP TO BE FLUSHED WITH 10 gpm FLOW FOR 1 HOUR PER DAY. FROM FLUSH WATER TRUCK FLUSH WATER NOTE-1 2121-PP-100/110 S 2121-PP-102/112 S FROM FLUSH WATER TANK 2220-TK-201 FLUSH WATER 2220-PRPF-001 2290 2621FROM FLUSH WATER TANK 2220-TK-202 FLUSH WATER 2220-PRPF-001 2622FROM FLUSH WATER TANK 2220-TK-203 FLUSH WATER 2220-PRPF-001 2121-PD-100 RECHARGE CANAL 2121-PP-101/111 S RECHARGE CANAL LIFT PUMP 2121-PP-102/112 S RECHARGE CANAL LIFT PUMP 2132-PP-400/410 S PLAYA BRINE PLANT FEED PUMP 2131-PP-101/102 S PLAYA BRINE FEED PUMP 2121-PD-1012121-PD-100 2121-PD-102 2121-PP-100/110 S RECHARGE CANAL LIFT PUMP 2121-PD-101 RECHARGE CANAL 2121-PD-102 RECHARGE CANAL 2121-PD-106 2121-PD-106 RECHARGE TRENCH NETWORK 2132-PD-400 BRINE EXTRACTION TRENCH NETWORK 2131-PD-101 BRINE EXTRACTION CANAL 2131-PD-1012132-PD-400 1399FROM SEVIER DIVERSION CANAL RECHARGE WATER 2131-TK-001 EXTRACTION CANAL FLUSH TANK 2132-TK-001 EXTRACTION TRENCH FLUSH TANK PB 19 MAY'23 CLIENT REVIEW 2131-TK-001 2132-TK-001 NOTE-2 2211-PP-101/102 S 2101 2105 2102 2106 2107 2211-PP-101/102 S 2101 2105 1401 2106 PLAYA BRINE 2107 2121 2131 2141 2124 2125 LE A K A G E SO L I D S EN T R A I N M E N T LE A K A G E LE A K A G E NOTES 1.ANNUAL FLOW AVAILABILITIES ARE AS FOLLOWS : PLAYA BRINE: 8322 HR/YR; POND TO POND BRINE FLOW, EVAPORATION, ENTRAINMENT 5110 HR/YR; LEAKAGE: 8760 HR/YR. 2.EVAPORATION RATES ARE CORRECTED FOR TOTAL ANNUAL PRECIPITATION (WHICH INCLUDES RAINFALL AND SNOWFALL). 3.SOLIDS DEPOSITED IN PRE-CONCENTRATION PONDS 1-3 ACCUMULATED OVER TIME. ENTRAINMENT REFERS TO ACCUMULATED BRINE LOSSES IN THESE SOLIDS. 4.NOMINAL VALUE REPRESENTS PUMP OPERATING POINT. 5.POND P1 PROVIDE STORAGE FOR PLAYA BRINE PUMPED DURING WINTER. 6.SINGLE DREDGE TO OPERATE IN PONDS P3 AND P4 AFTER 1 METER OF HALITE DEPOSITED. 7.CONNECTION POINT FOR THE NaCl SCOPING STUDY PROCESSING PLANT. NOT INCLUDED IN FEED DESIGN. 8.EACH PUMP TO BE FLUSHED WITH 10 gpm FLOW FOR 1 HOUR PER DAY. 2211-PP-111/112 S 2211-PP-111/112 S 2212-PP-131/132 S 2100-PRPF-001 PRE-CONCENTRATED BRINE 2220-PRPF-001 2109 2212-PP-121/122 S 2212-MB-101 NOTE 6 2151 NOTE 6 2152 NN F NN F 2153 2108 2110 2154 2134 SO L I D S 2135 SO L I D S 2212-PP-121 /122 S POND P3 SALT PAD BRINE PUMP DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 2 2 1 0 - P R P F - 0 0 1 - P R E - C O N P O N D S . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 7 / 2 0 2 3 1 1 : 5 6 : 1 5 A M SA V E D : 1 3 1214 - 2210 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE PRE-CONCENTRATION PONDS PROCESS FLOW DIAGRAM PEAK MINERALS INC. FROM PLAYA BRINE FEED PUMP 2132-PP-101 TO PLAYA BRINE TRANSFER CANAL 2220-PD-201 2144 EN T R A I N M E N T 2145 EN T R A I N M E N T PA 06 APR'23 YD AL JB MR INTERNAL REVIEW 2212-MB-101 POND P3/P4 DREDGE 2212-PP-131/132 S POND P4 SALT PAD BRINE PUMP 2123 LE A K A G E 2133 SO L I D S EN T R A I N M E N T 2143 FLUSH WATER 2211-TK-101 2211-TK-111 2211-TK-101 PUMP FLUSH WATER TANK POND P1 2212-TK-121 PUMP FLUSH WATER TANK POND P3 2211-TK-111 PUMP FLUSH WATER TANK POND P2 2212-TK-131 PUMP FLUSH WATER TANK POND P4 2212-TK-121 2212-TK-131 2161 2162 2163 2164 PRE-CONCENTRATION POND P2 PUMP PRE-CONCENTRATION POND P1 PUMP 2287 2230-PRPF-001 FROM FLUSH WATER TRUCK 0000-MB-003 DEFERRED CAPITAL DEFERRED CAPITAL DEFERRED CAPITAL 3805 POND BRINE 3820-PRPF-001 FROM RAW SALTS DEWATERING SCREEN 3821-SN-101 POND SALTS 3820-PRPF-001 3801 TO RAW SALTS DEWATERING SCREEN 3821-SN-101 2211-PD-101 2211-PD-101 PRE-CONCENTRATION POND P1 2211-PD-111 2211-PD-111 PRE-CONCENTRATION POND P2 2212-PD-121 2212-PD-121 POND P3 SALT PAD 2212-PD-131 2212-PD-131 POND P4 SALT PAD 2212-PD-122 PRE-CONCENTRATION POND P3 2212-PD-132 PRE-CONCENTRATION POND P4 2212-PD-122 2212-PD-132 SALT (NaCl) SCOPING STUDY SALT (NaCl) SCOPING STUDY LEGEND NaCl SCOPING STUDY NOTE 7 NOTE 7 PB 19 MAY'23 CLIENT REVIEW NOTE 8 2220-PP-201/211 S BRINE CANAL LIFT PUMP #1 PRE-CONCENTRATED BRINE 2230-PRPF-001 2601 2220-PD-201 PRE-CONCENTRATED BRINE 2210-PRPF-001 2220-PD-202 2220-PD-203 2109 2220-PP-202/212 S BRINE CANAL LIFT PUMP #2 2220-PP-203/213 S BRINE CANAL LIFT PUMP #3 NOTE 1 NOTES: 1.FLOW IS AVERAGED OVER SUMMER SEASON. 2.EACH PUMP TO BE FLUSHED WITH 10 gpm FLOW FOR 1 HOUR PER DAY. DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 2 2 2 0 - P R P F - 0 0 1 - T R A N S F E R C A N A L . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 7 / 2 0 2 3 1 1 : 5 5 : 2 2 A M SA V E D : 1 3 1214 - 2220 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE TRANSFER CANAL PROCESS FLOW DIAGRAM PEAK MINERALS INC. FROM PRE-CONCENTRATION POND P4 2212-PD-132 PA 06 APR'23 VB AL JB MR INTERNAL REVIEW 2220-TK-201 2220-TK-201 PUMP FLUSH WATER TANK 2220-TK-202 PUMP FLUSH WATER TANK 2220-TK-203 PUMP FLUSH WATER TANK 2220-TK-202 2220-TK-203 FLUSH WATER 2610 2611 2612 2100-PRPF-001 FLUSH WATER TO PLAYA RECHARGE CANAL PUMP 2121-PP-1002620 2100-PRPF-001 FLUSH WATER TO PLAYA RECHARGE CANAL PUMP 2121-PP-1012621 2100-PRPF-001 FLUSH WATER TO PLAYA RECHARGE CANAL PUMP 2121-PP-1022622 2230-PRPF-001 FROM FLUSH WATER TRUCK 0000-MB-001 2288 2220-PP-201/211 S 2220-PP-202/212 S 2220-PP-203/213 S 2220-PD-201 BRINE CANAL #1 2220-PD-202 BRINE CANAL #2 2220-PD-203 BRINE CANAL #3 PB 19 MAY'23 CLIENT REVIEW TO BRINE MIXING PIT #1/2 2232-PD-270/272 NOTE 2 2200 2220-PRPF-001 3380-PRPF-001 HEATED PROCESS RECYCLE BRINE 2601 5670 3310-PRPF-001 HARVEST SALT PRE-CONCENTRATED BRINE 2250 2232-PP-210/211 S 2232-PP-210/211 S NOTES 1.BRINE FLOWRATES ARE BASED ON 7 MONTH EVAPORATION PERIOD. 2.SOLID FLOWRATES ARE BASED ON PLANT DESIGN AVAILABILITY. 3.HARVEST EVERY THIRD YEAR. 4.HARVESTED DURING 5 MONTH WINTER PERIOD. 5.POND TO POND TRANSFER IS VIA OVERFLOW WEIR. 6.WATER TRUCK USED TO CLEAN WEIRS AND PUMPS. 7.THERE ARE (4) BACK-MIX PONDS ALIGNED IN SERIES. 8.ALL 3 PUMPS STATIONS ARE LOCATED IN BACK-MIX POND 4. 9.SAME MOBILE EQUIPMENT TO BE USED FOR BOTH BACK-MIX AND PRODUCTION PONDS, AND TO BE MANAGED AS A BUY-OWN (BOO) PACKAGE. 10.EACH PUMP TO BE FLUSHED WITH 10 gpm FLOW FOR 1 HOUR PER DAY. 2201 2230-PRPF-003 BACK MIX SALTS 2240 2212 LE A K A G E EVAPORATION 2210 PRB BUFFER POND PUMP 2230-PRPF-003 6001 TAILINGS BRINE 2211 LE A K A G E 2232-PP-224/225 S SO L I D S DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 2 2 3 0 - P R P F - 0 0 1 - B A C K - M I X I N G P O N D S . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 8 : 2 5 : 4 3 A M SA V E D : 1 3 1214 - 2230 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE BACK-MIXING PONDS PROCESS FLOW DIAGRAM PEAK MINERALS INC. FROM TAILINGS BRINE TRENCH PUMP 2234-PP-002 TO TAILINGS PILE 2234-PD-001 FROM BRINE TRANSFER CANAL LIFT PUMP #3 2220-PP-203 FROM PROCESS RECYCLE HEAT EXCHANGER 3380-HX-540 3510-PRPF-001 5114 PROCESS WATER FROM WATER TRUCK FILLING PUMP 3511-PP-750 NOTE 6 NOTE 4 2224 SO L I D S EVAPORATION 2209 INTERMITTENT PA 06 APR'23 YD AL JB MR INTERNAL REVIEW FLUSH WATER 2232-TK-210 2232-TK-220 NOTE 7 2232-PP-222/223 S 2232-PP-220/221 S NOTE 8 2232-TK-210 PUMP FLUSH WATER TANK 2232-TK-220 PUMP FLUSH WATER TANK 2232-PD-270/272 BRINE MIXING PIT 1/2 2230-PRPF-003 TO TAILINGS BRINE PUMP 2234-PP-002/102S FLUSH WATER 2283 2232-PP-224/225 S BACK-MIX POND #4 PUMP 2281 2282 2210-PRPF-001 TO FLUSH WATER TANKS FLUSH WATER 2287 2220-PRPF-001 TO FLUSH WATER TANKS FLUSH WATER 2288 2232-PP-222/223 S BACK-MIX POND #4 PUMP 2232-PP-220/221 S BACK-MIX POND #4 PUMP 2230-PRPF-002 2260 BITTERN BRINE FROM BITTERN PUMP 2233-PP-230/231 S 2232-PD-210 2232-PD-220/230/240/250 2230-PRPF-002 PRODUCTION POND FEED TO PRODUCTION POND H1 A/B/C 2231-PD-260/262/264 TO CRUSHING FEED HOPPER 3310-HP-101 2100-PRPF-001 TO FLUSH WATER TANK 2233-TK-2502290 2232-PD-210 PRB BUFFER POND 2232-PD-270/272 2232-PD-220/230/240/250 BACK-MIX POND 1,2,3,4 2230-MB-002 2230-MB-001 2230-MB-0032230-MB-004 BOO PACKAGE NOTE 9 0000-MB-003 0000-MB-003 WATER TRUCK 2230-MB-001 FRONT-END LOADER 2230-MB-002 GRADER 2230-MB-003 HAUL TRUCK CABS 2230-MB-004 HAUL TRUCK TRAILERS PB 19 MAY'23 CLIENT REVIEW FLUSH WATER 2230-PRPF-002 TO PUMP FLUSH WATER TANK 2233-TK-2502289 FLUSH WATER NOTE 10 2233-PP-230/231 S BITTERNS PUMP 2233-PP-230/231 S EVAPORATION 2205 2204 2222 HOPPER 3310-HP-101 3310-PRPF-001 2230 HARVEST SALTS TO CRUSHING FEED 2214 LE A K A G E NOTES 1.BRINE FLOWRATES ARE BASED ON 7 MONTH EVAPORATION PERIOD. 2.SOLID FLOWRATES ARE BASED ON PLANT DESIGN AVAILABILITY. 3.HARVEST EVERY THIRD YEAR. 4.HARVESTED DURING 5 MONTH WINTER PERIOD. 5.POND TO POND TRANSFER IS VIA OVERFLOW WEIR. 6.WATER TRUCK USED TO CLEAN WEIRS AND PUMPS. 7.THERE ARE (4) BACK-MIX PONDS ALIGNED IN SERIES. 8.ALL 3 PUMPS STATIONS ARE LOCATED IN BACK-MIX POND 4. 9.MOBILE PUMPS USED TO EMPTY PONDS FOR HARVESTING. 10.SAME MOBILE EQUIPMENT TO BE USED FOR BOTH BACK-MIX AND PRODUCTION PONDS, AND TO BE MANAGED AS A BUY-OWN (BOO) PACKAGE. 11.EACH PUMP TO BE FLUSHED WITH 10 gpm FLOW FOR 1 HOUR PER DAY. 2260 2230-PRPF-001 NOTE 5 2218 SO L I D S AC C U M U L A T I O N 2270 BI T T E R N IN T E R M I T T E N T IN T E R M I T T E N T SOLIDS DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 2 2 3 0 - P R P F - 0 0 2 - B I T T E R N P O N D S . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 8 : 2 6 : 3 8 A M SA V E D : 1 3 1214 - 2230 - PRPF - 002 PB SEVIER PLAYA POTASH PROJECT FEED PHASE PRODUCTION AND BITTERN PONDS PROCESS FLOW DIAGRAM PEAK MINERALS INC. TO BRINE MIXING PIT 1/2 2232-PD-270/272 NN F EVAPORATION 2273 PA 06 APR'23 YD AL JB MR INTERNAL REVIEW EVAPORATION 2217 2216 LE A K A G E 2272 SO L I D S 2271 LE A K A G E 2269 2233-TK-250 2233-TK-250 PUMP FLUSH WATER TANK 2231-PD-234/236/238 PRODUCTION PONDS H2 A/B/C 2284 2233-PD-230 BITTERN BRINE POND 2233-PD-232 BITTERNS WASTE POND 2230-PRPF-001 PRODUCTION POND FEED 2221 SOLIDS 2230-PRPF-001 2289 FLUSH WATER FROM FLUSH WATER TRUCK 0000-MB-003 FROM BACK-MIXING POND #4 2232-PD-250 2233-PD-230 2233-PD-232 2231-PD-234/236/238 2231-PP-241/242/243 MOBILE DEBRINING PUMP EVAPORATION 2203 2202 2231-PP-241/242/243 2213 LE A K A G E 2201 NOTE 5 NOTE 9 2274 2231-PD-260/262/264 PRODUCTION POND H1 A/B/C 2231-PD-260/262/264 BITTERN BRINE 2230-MB-001 FRONT-END LOADER 2230-MB-002 GRADER 2230-MB-003 HAUL TRUCK CABS 2230-MB-004 HAUL TRUCK TRAILERS 2230-MB-002 2230-MB-001 2230-MB-0032230-MB-004 BOO PACKAGE NOTE 10 2231-PD-200 EMERGENCY SALT STOCK PILE 2231-PD-200 PB 19 MAY'23 CLIENT REVIEW NOTE 11 3360-PRPF-002 TAILINGS 3641 2230-PRPF-001 BACK MIX SALTS 2240 2234-PP-002/102 S 2230-PRPF-001 2230-MB-005 TAILINGS BRINE DOZER TAILINGS BRINE 6001 DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 2 2 3 0 - P R P F - 0 0 3 - T A I L I N G S M A N A G E M E N T S Y S T E M . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 7 / 2 0 2 3 1 2 : 0 5 : 0 5 P M SA V E D : 1 3 1214 - 2230 - PRPF - 003 PB SEVIER PLAYA POTASH PROJECT FEED PHASE TAILINGS MANAGEMENT SYSTEM PROCESS FLOW DIAGRAM PEAK MINERALS INC. 6002 SALT ACCUMULATION PA 06 APR'23 YD AL JB MR INTERNAL REVIEW 2230-PRPF-001 FLUSH WATER 2283 FROM BACK MIX PONDS #1,2,3,4 2230-PRPF-220/230/240/250 FROM FLUSH WATER TRUCK FROM TEMPORARY TAILINGS PILE 3360-PD-001 TO PRB BUFFER POND 2232-PD-210 2234-TK-001 FLUSH TANK 2234-PD-001 TAILINGS PILE 2234-PD-002 TAILINGS BRINE TRENCH 2234-PP-002/102 S TAILINGS BRINE PUMP 2234-PD-001 2234-PD-002 PB 19 MAY'23 CLIENT REVIEW 2234-TK-001 NOTE 1 NOTES 1.EACH PUMP TO BE FLUSHED WITH 10 gpm FLOW FOR 1 HOUR PER DAY. 3320-PRPF-001 3101 3310-FD-101 3310-HP-101 3310-MG-101 3310-ML-101 CRUSHED MIXED SALTS SLURRY 2230-PRPF-002 HARVEST SALTS 3310-CV-101 3340-PRPF-001 3310-TK-102 3310-PP-102 3310-TK-102 3310-PP-102 3310-PP-910 3310-PP-910/911 3310-CV-101 3432 3102 3103 3104 2230 3146 NNF 3310-MG-101 3310-ML-101 3310-CR-101 3310-CR-101 DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 3 1 0 - P R P F - 0 0 1 - S A L T S C R U S H I N G . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 9 / 2 0 2 3 9 : 1 6 : 1 1 A M SA V E D : 1 3 1214 - 3310 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE MIXED SALTS CRUSHING AND SLURRYING PROCESS FLOW DIAGRAM PEAK MINERALS INC. LIC . M VSD WIC . FIC . FIC . FROM MOTHER LIQUOR PUMP 3340-PP-404 TO CONVERSION REACTOR STAGE 1 3320-CZ-201/211 FROM PRODUCTION PONDS H1 & H2 A/B/C 2231-PD-260/262/264 2231-PD-234/236/238 PA 06 APR'23 YD AL JB MR INTERNAL REVIEW 3500-PRPF-001 3144 STORM WATER/SPILLS TO STORM WATER POND 3106 3310-SN-101 3310-SN-101 3310-HP-101 3310-FD-101 LIC . M VSD 3310-AG-102 3113 3105 3310-TK-104 3310-AG-104 3310-PP-104 3310-AG-102 3310-TK-104 3310-AG-104 3310-PP-104 3310-CH-101 3310-CH-101 HAMMER MILL CHUTE MOTHER LIQUOR CRUSHING HAMMER MILL CRUSHING HAMMER MILL TANK CRUSHED MIX SALTS TANK MIXED SALTS SCREEN CRUSHING HAMMER MILL TANK AGITATOR CRUSHED MIX SALTS TANK AGITATOR CRUSHED MIX SALTS TANK PUMP 3310-PP-911 NNF 3143 3145 CRUSHING SUMP PUMP #1,2 CRUSHING FEED HOPPER CRUSHING APRON FEEDER CRUSHING BELT CONVEYOR MIXED SALTS ROLL CRUSHER CRUSHING MAGNET CRUSHING SLURRY TANK PUMP PB 19 MAY'23 CLIENT REVIEW 2230-PRPF-001 HARVEST SALTS 2224FROM PRB BUFFER POND 2232-PD-210 3310 3480-PRPF-001 3899FROM MOP BRINE PUMP 3480-PP-812 MOTHER LIQUOR NNF NOTE 1 NOTE 1.TRANSPORT LOSSES TAKEN INTO ACCOUNT IN THIS STREAM. 3320-PP-202/203 3330-PRPF-001 3220 CONVERSION SLURRY3320-CZ-201/211 3320-CZ-201/211 CONVERSION REACTOR STAGE 1 3320-PP-202/203 3320-CZ-202/212 3320-CZ-202/212 CONVERSION REACTOR STAGE 2 3310-PRPF-001 CRUSHED MIXED SALTS SLURRY 3101 3510-PRPF-001 PROCESS WATER 3320-AG-201/211 3320-AG-202/212 3320-AG-201/211 3320-AG-202/212 3370-PRPF-001RECOVERED BRINE/SLURRY 3500-PRPF-001 TO STORM WATER POND 3320-PP-920 3320-PP-920 3320-PP-921/922 3320-PP-921/922 STORM WATER/SPILLS 3242 3241 NNF NNF 3340-PRPF-001 MOTHER LIQUOR 3380-PRPF-001 CHILLED WATER SUPPLY 3380-PRPF-001 3380-XM-550/560 CHILLED WATER RETURN TO HEAT PUMPS 3320-HX-201/211 3320-VP-201/211 3320-TK-204/214 3320-TK-202 3320-HX-201/211 3320-PP-206 3320-TK-202 3320-TK-204/214 SEAL WATER SEPARATOR 3320-PP-206 3235 3270 3202 5132 3414 3205 3203 5690 3237 3320-VP-201/211 NOT FOR CONSTRUCTION PRELIMINARY DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 3 2 0 - P R P F - 0 0 1 - C O N V E R S I O N . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 7 / 2 0 2 3 1 0 : 5 1 : 5 6 A M SA V E D : 1 3 1214 - 3320 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE CONVERSION PROCESS FLOW DIAGRAM PEAK MINERALS INC. FIC . TIC . FIC . TIC . LIC . FIC . VSD 3370-PRPF-001 RECOVERED BRINE/SLURRY 3708FROM DUMP TANK PUMP 3370-PP-001 NNF VSD FROM HEAT PUMPS 3380-XM-550 FROM CRUSHED MIX SALTS PUMP 3310-PP-104 FROM PROCESS WATER PUMP 3511-PP-700/701S FROM SCHOENITE LEACH FILTRATE PUMP 3340-PP-404 TO FLOTATION CONDITIONING TANK 3330-TK-340 TO DUMP TANK 3370-TK-001 NNF PA 06 APR'23 YD AL JB MR INTERNAL REVIEW 3370-PRPF-001 3370-TK-001 RECOVERED BRINE/SLURRY 3243 NNF TO DUMP TANK 3320-PP-201/211 3320-PP-201/211 VENT AIR CONVERSION AREA SUMP PUMP CHILLED WATER RETURN PUMP 3340-PRPF-001 CHILLED WATER RETURN FROM SCHOENITE LEACH BAROMETRIC CONDENSER 3340-HX-411/412 3452 3206 3211 3340-PRPF-001 CHILLED WATER RETURN 3236 TO SCHOENITE LEACH REACTOR 3340-CZ-411/412 CONVERSION REACTOR STAGE 1 AGITATOR CONVERSION REACTOR STAGE 2 AGITATOR CONVERSION REACTOR STAGE 1 CONDENSER VACUUM PUMP CONVERSION REACTOR STAGE 1 BAROMETRIC CONDENSER CONVERSION REACTOR STAGE 1 SLURRY PUMP CONVERSION REACTOR STAGE 2 PUMP BAROMETRIC CONDENSER HOTWELL CONVERSION REACTORS DRAINING PUMP DRAIN PB 19 MAY'23 CLIENT REVIEW 3326 3325 3330-PRPF-002 3330-AG-340 COLLECTOR 3396 TO TAILINGS LEACH 3360-PRPF-001 3330-TK-340 FROTHER3330-PRPF-002 3330-PP-371/372 3330-TK-340 3330-AG-340 3330-FC-301/302 METERING PUMP TANK 3360-TK-601 FROM FROTHER 3330-FC-301/302 3330-FC-303/304 ROUGHER FLOTATION BANK 3330-PP-301 3330-TK-301 3330-TK-301 3330-PP-313 3330-TK-313 3330-TK-313 3330-FC-303/304 3330-PP-341 3330-PP-341 3330-PP-930 3330-PP-930 3340-PRPF-001FLOTATION CONCENTRATE SLURRY 3392 3301 3322 3350 FLOTATION TAILINGS SLURRY 3330-AG-341 3330-TK-341 TO STORM WATER 3500-PRPF-001 POND 3330-PRPF-002 EXTENDER 3398 3330-TK-341 3330-AG-341 3330-HS-301 3330-PP-931 3330-PP-931 3330-HS-301 FLOTATION HOIST 3330-AG-301/302 3330-AG-303/304 3330-PP-301 3330-AG-301/302 3330-AG-303/304 STORM WATER/SPILLS 3343 3345 3344 NNF NNF FLOTATION AREA 3302 3303 COLLECTION PITS DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 3 3 0 - P R P F - 0 0 1 - F L O T A T I O N . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 8 : 4 4 : 3 1 A M SA V E D : 1 3 1214 - 3330 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE FLOTATION PROCESS FLOW DIAGRAM PEAK MINERALS INC. LIC . LIC . LIC . K40 LIC . VSD VSD PA 06 APR'23 YD AL JB MR INTERNAL REVIEW 3330-PP-313 LIC . VSD LIC . 3350-PRPF-001 CRYSTALLIZER MOTHER LIQUOR SURGE PUMP 3350-PP-506 FROM SOP CRYSTALLIZER O/F VSD 3330-CY-301 3306 3330-TK-321 3330-PP-321 3330-CF-301 3330-PP-302 3330-AG-322 3330-TK-322 3552 3308 3307 3305 3304 3330-CY-301 3330-PP-321 3330-TK-321 3330-PP-302 3330-CF-3013330-TK-322 3330-AG-322 PACKAGE P-5020 VSD LIC . TO SCHOENITE LEACH REACTOR #1,2 3340-CZ-411/412 FROM KEROSENE METERING PUMP 3330-PP-381 FROM COLLECTOR METERING PUMP 3330-PP-362 FLOTATION CELLS COLLECTION PIT PUMP FLOTATION TAILINGS SLURRY PUMP BOX FLOTATION CONDITIONING TANK #1 FLOTATION CONDITIONING TANK #1 AGITATOR FLOTATION CONDITIONING TANK #2 FLOTATION CONDITIONING TANK #2 AGITATOR FLOTATION CONDITIONING TANK PUMP #1 CONVERSION SLURRY HYDROCYCLONE CONVERSION HYDROCYCLONE OVERFLOW TANK CONVERSION HYDROCYCLONE OVERFLOW PUMP ROUGHER CONCENTRATE PUMP BOX ROUGHER CONCENTRATE PUMP BOX PUMP ROUGHER FLOTATION BANK AGITATORS FLOTATION CONCENTRATE CENTRIFUGE TANK FLOTATION CONCENTRATE CENTRIFUGE TANK AGITATOR FLOTATION CONCENTRATE CENTRIFUGE FLOTATION CONCENTRATE SLURRY PUMP ROUGHER FLOTATION BANK #3,4 ROUGHER FLOTATION BANK AGITATORS #3,4 FLOTATION TAILINGS PUMP FLOTATION AREA SUMP PUMP 3320-PRPF-001 CONVERSION SLURRY STAGE 2 PUMP 3320-PP-202 3220FROM CONVERSION REACTOR 3370-PRPF-001 RECOVERED BRINE/SLURRY 3703 NNF FROM DUMP TANK PUMP 3370-PP-001 PB 19 MAY'23 CLIENT REVIEW 3331 3330 3332 3330-PP-360 5133 3510-PRPF-001 PROCESS WATER PUMP 3510-PP-700 TO FLOTATION CONDITIONING 3330-PRPF-001FROTHER 3330-AG-362 3392 3330-AG-363 3330-TK-363 3330-HE-363 TO FLOTATION CONDITIONING 3330-PRPF-001COLLECTOR 3396 3330-AG-362 3330-TK-3623330-PP-361 INTERMITTENT 3330-HE-362 3330-TK-361 3330-PP-360 3330-HE-361 3394 INTERMITTENT 3395 INTERMITTENT 3393 3330-HE-361 3330-TK-361 COLLECTOR BULK TANK 3330-HE-362 3330-TK-362 COLLECTOR DAY TANK #1 3330-AG-3633330-HE-363 3330-TK-363 COLLECTOR DAY TANK #2 3330-PP-371 TANK 3330-TK-340 TANK 3330-TK-340 COLLECTOR TO FLOTATION CONDITIONING 3330-PRPF-001EXTENDER 3398 3330-PP-381/382 3397 INTERMITTENT TANK 3330-TK-340 KEROSENE 3330-PP-361 3330-TK-381 KEROSENE STORAGE TANK 3330-PP-381/382 FROM PROCESS WATER TANK INTERMITTENT 3330-PP-362 3330-PP-362 3330-PP-372 TOTE FROTHER 3330-PP-371 TOTE FROTHER 3330-PP-372 3330-TK-381 DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 3 3 0 - P R P F - 0 0 2 - R E A G E N T S T O R A G E . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 7 / 2 0 2 3 1 2 : 1 1 : 2 7 P M SA V E D : 1 3 1214 - 3330 - PRPF - 002 PB SEVIER PLAYA POTASH PROJECT FEED PHASE REAGENT MIXING AND STORAGE PROCESS FLOW DIAGRAM PEAK MINERALS INC. TIC . TIC . TIC . FIC . FIC . PA 06 APR'23 YD AL JB MR INTERNAL REVIEW COLLECTOR BULK TANK PUMP COLLECTOR BULK TANK HEATER COLLECTOR MIXING TANK FEED PUMP COLLECTOR DAY TANK #1 HEATER COLLECTOR DAY TANK #1 AGITATOR COLLECTOR DAY TANK #2 HEATER COLLECTOR DAY TANK #2 AGITATOR COLLECTOR METERING PUMP #1 FROTHER METERING PUMP FROTHER METERING PUMP KEROSENE METERING PUMP #1 AND #2 OUT OF SCOPE FROM TANKER TRUCK OUT OF SCOPE FROM TANKER TRUCK PB 19 MAY'23 CLIENT REVIEW 3330-PP-363 3330-PP-363 COLLECTOR METERING PUMP #2 3340-CZ-411/412 3340-VP-414/415 3350 3330-PRPF-001 3340-PP-411/412 3340-PP-404 3350-PRPF-001 CRYSTALLIZER MOTHER LIQUOR 3320-PRPF-001 3350-PRPF-001SCHOENITE CAKE 3340-PP-404 MOTHER LIQUOR 3431 3414 3340-FL-401 3551 3340-CZ-411/412 CHILLED WATER RETURN CHILLED WATER SUPPLY 3340-HX-411/412 3340-AG-411/412 3340-AG-411/412 3340-HX-411/412 3340-VP-414/415 SEAL WATER SUPPLY 3340-PP-411/412 BELT FILTER FEED PUMP 3340-VP-401 3340-TK-401 3340-TK-402 AIR 3340-FL-401 3340-TK-414/415 3401 PACKAGE P-5027 3340-TK-402 3340-TK-401 3340-VP-401 3340-TK-414/415 3510-PRPF-001 PROCESS WATER 3510-PRPF-002 5680 3441 5101 3380-PRPF-001 3320-PRPF-001 VAPOR 3340-PP-402 3416 3340-PP-402 5134 3370-PRPF-001 RECOVERED BRINE/SLURRY 3704 NNF 3402 3443 3370-PRPF-001RECOVERED BRINE/SLURRY 3340-PP-431/432 NNF 3340-PP-431/432 NN F 3418 3448 3452 3403 3510-PRPF-002 3405 3406 AIR 3340-TK-403 VENT 3340-TK-403 VACUUM SEPARATOR 3340-CV-401/402 DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 3 4 0 - P R P F - 0 0 1 - S C H O E N I T E L E A C H . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 7 / 2 0 2 3 1 0 : 5 7 : 1 4 A M SA V E D : 1 3 1214 - 3340 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE SCHOENITE LEACH PROCESS FLOW DIAGRAM PEAK MINERALS INC. TIC . FIC . VSD LIC . LIC . LIC . VENT 3310-PRPF-001MOTHER LIQUOR 3432 3350-PRPF-001 FROM SEAL WATER LOOP HEAT EXCHANGER 3510-HX-701 TO BAROMETRIC CONDENSER HOTWELL 3320-TK-202 FROM EVAPORATOR 3380-XM-550 FROM PROCESS WATER TANK PUMP 3510-PP-700 FROM SOP CRYSTALLIZER O/F SURGE PUMP 3350-PP-506 FROM DUMP TANK PUMP 3370-PP-001 FROM CONCENTRATE SLURRY PUMP 3330-PP-302 TO MOP BRINE CONTROL VALVE TO SEAL WATER COLLECTION TANK 3510-TK-710 TO MIXED SALTS CRUSHING AND SLURRYING TO CONVERSION REACTOR STAGE 1 3320-CZ-201/211 TO DUMP TANK 3370-TK-001 M PA 06 APR'23 YD AL JB MR INTERNAL REVIEW 3499 SEAL WATER RETURN NNF LIC . 3340-TK-406 3340-PP-405 M VSD M VSD M VSD 3449 3340-PP-4053340-TK-406 FLOTATION CONCENTRATE SLURRY 3410 3407 NNF 3340-CV-401 3340-CV-402 TO SOP CRYSTALLIZER 3350-CZ-501 3340-CH-401 3340-CH-401 3462 NNF 3461 3320-PRPF-001 CHILLED WATER RETURN 3236 FROM BAROMETRIC CONDENSER HOTWELL 3320-TK-202 3340-HS-401 3340-HS-401 SCHOENITE LEACH BAROMETRIC CONDENSER SCHOENITE LEACH REACTOR SCHOENITE LEACH REACTOR AGITATOR LEACH REACTOR BRINE RECOVERY PUMPS SCHOENITE LEACH BELT FILTER SEAL WATER RECEIVER SCHOENITE LEACH BELT FILTER SCHOENITE LEACH BELT FILTER FILTRATE RECEIVER SCHOENITE LEACH BELT FILTER WASH BRINE RECEIVER SCHOENITE LEACH BAROMETRIC CONDENSER VACUUM PUMP SEAL WATER SEPARATOR SCHOENITE LEACH BELT FILTER VACUUM PUMP SCHOENITE LEACH BELT FILTER WASH BRINE PUMP SCHOENITE LEACH FILTRATE PUMP SCHOENITE CAKE SCREW CONVEYORS SEAL WATER RETURN PUMP SCHOENITE CAKE SCREW CONVEYOR CHUTE SCHOENITE LEACH HOIST DRAIN NN F PB 19 MAY'23 CLIENT REVIEW 33413340 3340-PP-4063340-TK-004 3340-TK-004 3340-PP-406 LEACH BUFFER TANK BRINE TANK PUMP 3350-PP-5123350-CZ-501 3340-PRPF-001 SCHOENITE CAKE 3350-PP-502 3431 3350-AG-501 3350-CZ-501 SOP CRYSTALLIZER 3350-AG-501 3350-PP-502 3350-TH-522 3350-PP-501 3350-TK-506 3350-PP-506 3350-AG-506 3350-AG-5063350-TK-502 3350-TK-5063350-PP-506 3350-PP-950/951 3502 3480-PRPF-001 MOP/SOP BRINE 3340-PRPF-001 3551 TO SCHOENITE LEACH AREA 3350-TK-502 3350-TH-522 3380-PRPF-001 HEATED PROCESS WATER 3561 3370-PRPF-001 3706 RECOVERED BRINE/SLURRY CRYSTALLIZER MOTHER LIQUOR NNF 3350-CZ-503 3350-AG-503 3350-PP-503 3504 3572 NNF 3350-CZ-503 3350-AG-503 SOP CRYSTALLIZER 3350-PP-503 SOP CRYSTALLIZATION PUMP DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 3 5 0 - P R P F - 0 0 1 - S O P C R Y S T A L L I Z A T I O N . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 9 / 2 0 2 3 9 : 2 1 : 1 8 A M SA V E D : 1 3 1214 - 3350 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE SOP CRYSTALLIZATION PROCESS FLOW DIAGRAM PEAK MINERALS INC. M VSD LIC . M VSD LIC . M VSD LIC . LIC . 3340-PRPF-001 FROM DUMP TANK PUMP 3370-PP-001 FROM MOP BRINE PUMP 3480-PP-812 FROM SCHOENITE CAKE SCREW CONVEYOR 3340-CV-401/402 FROM BELT FILTER FEED PUMP FLOW METER FROM PROCESS WATER HEAT EXCHANGER 3380-HX-560 PA 06 APR'23 YD AL JB MR INTERNAL REVIEW NNF NNF 3510 3500-PRPF-001 TO STORM WATER POND 3350-PP-950/951 STORM WATER/SPILLS 3542 NNF 3370-PRPF-001 3370-TK-001 RECOVERED BRINE/SLURRY 3543 NNF TO DUMP TANK 3330-PRPF-001 SLURRY TANK 3330-TK-3223552TO FLOTATION CONCENTRATE CRYSTALLIZER MOTHER LIQUOR 3550 3380-PRPF-001 5641 HOT SOP CENTRATE FROM SOP CENTRATE HEAT EXCHANGER 3380-HX-531 3512 3511 SOP CRYSTALLIZER THICKENER O/F PUMP SOP CRYSTALLIZER THICKENER O/F AGITATOR SOP CRYSTALLIZER THICKENER 3370-PRPF-001 TO SOP CENTRATE TANK 3370-TK-001 3410-PRPF-001 TO SOP SLURRY HYDROCYCLONE 3410-CY-5033501 3541 3503 SOP CRYSTALLIZER AGITATOR SOP CRYSTALLIZER AGITATOR SOP CRYSTALLIZER PUMP SOP CRYSTALLIZATION OVERFLOW PUMP BOX SOP CRYSTALLIZATION O/F PUMP SOP CRYSTALLIZER THICKENER O/F TANK CRYSTALLIZATION AREA SUMP PUMP 3410-PRPF-001 TO SOP CENTRATE TANK 3410-TK-508 3350-PP-507 M VSD 3350-PP-507 SOP CRYSTALLIZER THICKENER PUMP PB 19 MAY'23 CLIENT REVIEW 3350-AG-522 3350-AG-522 SOP CRYSTALLIZER THICKENER RAKE THICKENER UNDERFLOW NNF RECOVERY BRINE/SLURRY SOP SLURRY 3350-PP-512 MOTHER LIQUOR RECYCLING PUMP 3350-PP-501 3571 PLAYA BRINE 3360-TK-601 3360-AG-601 3360-PP-001 3360-PRPF-002 TAILINGS SLURRY 3360-TK-601 TAILINGS LEACH TANK 3360-AG-601 3360-TK-001 3360-TK-602 3360-AG-602 3330-PRPF-001 FLOTATION TAILINGS SLURRY 1403 3322 3601 TO STORM WATER POND 3360-PP-960 3360-PP-960 3370-PRPF-001 RECOVERED BRINE/SLURRY STORM WATER/SPILLS 36483702 NNF 3360-TK-602 TAILINGS LEACH TANK 3360-AG-602 3360-PP-6033360-TK-603 NNF 2100-PRPF-001 3360-PRPF-002 SECONDARY FILTRATE 3660 DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 3 6 0 - P R P F - 0 0 1 - T A I L I N G S L E A C H . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 7 / 2 0 2 3 1 1 : 4 1 : 4 8 A M SA V E D : 1 3 1214 - 3360 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE TAILINGS LEACH PROCESS FLOW DIAGRAM PEAK MINERALS INC. FIC . LIC . VSD FROM PLAYA BRINE PLANT FEED PUMP 2132-PP-400 FROM FLOTATION TAILINGS PUMP 3330-PP-313 FROM DUMP TANK PUMP 3370-PP-001 FROM TAILINGS FILTER VACUUM RECEIVER PUMP 3360-PP-629 TO TAILINGS HYDROCYCLONE 3360-CY-619 PA 06 APR'23 YD AL JB MR INTERNAL REVIEW 3500-PRPF-001 TAILINGS LEACH TANK AGITATOR TAILINGS LEACH TANK AGITATOR TAILINGS LEACH PUMP BOX TAILINGS LEACH SLURRY PUMP TAILINGS LEACH AREA SUMP PUMP PB 19 MAY'23 CLIENT REVIEW VSD LIC . 3360-TK-001 PLAYA BRINE PUMP BOX 3360-PP-001 PLAYA BRINE PUMP 3360-PRPF-001 3601 TAILINGS TAILINGS SLURRY 3640 3360-PP-961 3650 3360-VP-620 3360-PP-9613360-CY-619 3360-PP-618 2230-PRPF-003 3380-PRPF-001 PROCESS RECYCLE BRINE 3360-TK-622 TAILINGS FILTER VACUUM RECEIVER SEAL WATER SUPPLY 3360-CV-641 3360-CV-641 3360-TK-618 3510-PRPF-001 PROCESS WATER 3500-PRPF-001 STORM WATER/SPILLS TAILINGS FILTRATE PUMP BOX 3360-TK-618 5107 5105 3641 3510-PRPF-002 3649 3604 3360-CY-619 3360-PP-618 3360-FL-620 3360-TK-620 3621 3360-PP-628 TAILINGS FILTER VACUUM RECEIVER PUMP 3360-PP-629 TAILINGS FILTER VACUUM RECEIVER PUMP (SAFE LOCATION) VENT 3360-TK-632 3360-TK-632 VACUUM SEPARATOR SECONDARY FILTRATE 3660 3360-PRPF-001 DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 3 6 0 - P R P F - 0 0 2 - T A I L I N G S S - L S E P A R A T I O N . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 9 : 1 5 : 2 4 A M SA V E D : 1 3 1214 - 3360 - PRPF - 002 PB SEVIER PLAYA POTASH PROJECT FEED PHASE TAILINGS SOLID/LIQUID SEPARATION PROCESS FLOW DIAGRAM PEAK MINERALS INC. LIC . VSD FROM PROCESS WATER TANK 3510-TK-700 TO STORM WATER POND FROM TAILINGS LEACH SLURRY PUMP 3360-PP-603 FROM SEAL WATER HEAT EXCHANGER 3510-HX-701 TO PROCESS RECYCLE BRINE HEAT EXCHANGER 3380-HX-540 TO TAILINGS MANAGEMENT SYSTEM AREA TO TAILINGS LEACH TANK 3360-TK-601 PA 06 APR'23 YD AL JB MR INTERNAL REVIEW 3360-VP-620 3360-TK-620 3360-TK-622 3651 LIC . LIC . 3360-TK-624 3360-PP-626 M VSD VSD LIC . M VSD SEAL WATER RETURN 5106 3510-PRPF-002 TO SEAL WATER COLLECTION TANK 3511-TK-710 3360-FL-620 3360-PP-628 3360-PP-629 3605 3645 M 3360-TK-624 TAILINGS FILTER SEAL WATER VACUUM RECEIVER 3360-PP-626 SEAL WATER RETURN PUMP NNF 3611 PACKAGE P-5027 TAILINGS HYDROCYCLONE TAILINGS SLURRY BELT FILTER VACUUM PUMP TAILINGS BELT CONVEYOR TAILINGS FILTRATE PUMP TAILINGS FILTER FILTRATE VACUUM RECEIVER 3360-HS-620 3360-HS-620 TAILINGS LEACH HOIST TAILINGS SLURRY BELT FILTER TAILINGS FILTRATION AREA SUMP PUMP 3360-PD-001 3360-PD-001 TAILINGS TEMPORARY PILE 3000-MB-001 2230-MB-0042230-MB-003 BOO PACKAGE 3000-MB-001 FRONT-END LOADER 2230-MB-004 HAUL TRUCK CABS 2230-MB-003 HAUL TRUCK TRAILERS PB 19 MAY'23 CLIENT REVIEW 3370-TK-001 DUMP TANK 3370-PP-001 DUMP TANK PUMP 3340-PRPF-001 3360-PRPF-001 TANK 3360-TK-601 3330-PRPF-001 RECOVERED BRINE/SLURRY RECOVERED BRINE/SLURRY RECOVERED BRINE/SLURRY 3702 3703 3704 3350-PRPF-001 RECOVERED BRINE/SLURRY 3706 NNF NNF NNF NNF TO TAILINGS LEACH 3340-PRPF-001 RECOVERED BRINE/SLURRY 3418 3350-PRPF-001 RECOVERED BRINE/SLURRY 3541 NNF NNF 3370-TK-001 3370-PP-001 DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 3 7 0 - P R P F - 0 0 1 - S P I L L R E C O V E R Y . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 2 / 2 0 2 3 8 : 1 0 : 1 9 A M SA V E D : 1 3 1214 - 3370 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE SPILL RECOVERY PROCESS FLOW DIAGRAM PEAK MINERALS INC. LIC . 3320-PRPF-001 RECOVERED BRINE/SLURRY 3708 NNF 3320-PRPF-001 RECOVERED BRINE/SLURRY 3241 NNF VSD PA 06 APR'23 YD AL JB MR INTERNAL REVIEW 3320-PRPF-001 RECOVERED BRINE/SLURRY 3243 NNF 3350-PRPF-001 RECOVERED BRINE/SLURRY 3543 NNF FROM SCHOENITE LEACH REACTORS BRINE RECOVERY PUMPS 3340-PP-431/432 FROM SOP CRYSTALLIZER PUMP 3350-PP-503 FROM CONVERSION REACTORS DRAINING PUMP 3320-PP-921 FROM CONVERSION AREA SUMP PUMP 3320-PP-920-921 FROM CRYSTALLIZATION AREA SUMP PUMP 3350-PP-950/951 TO CONVERSION REACTOR 3320-CZ-201 TO SOP CRYSTALLIZER 3350-CZ-501 TO FLOTATION CONDITIONING TANK 3330-TK-340 TO SCHOENITE LEACH REACTOR 3340-CZ-411/412 PB 19 MAY'23 CLIENT REVIEW CHILLED WATER RETURN 3350-PRPF-001 HEATED PROCESS WATER 5135 3340-PRPF-001 3410-PRPF-001 CHILLED WATER SUPPLY MAKE-UP WATER 3380-XM-560 3510-PRPF-002 CHILLED WATER RETURN CHILLED WATER SUPPLY 3510-PRPF-0023380-PP-550/551 S 3380-PP-560/561 S 3380-HX-560/561 S 3380-HX-560/561 S 3510-PRPF-001 PROCESS WATER 3510-PRPF-001 5659 3591 5123 5193 5683 5680 3380-XM-550 3380-PP-550/551 S 3380-PP-560/561 S 5669 5686 5685 5687 CHILLED WATER SUPPLY CHILLED WATER SUPPLY 3410-PRPF-001 3420-PRPF-001 3420-PRPF-001 4282 M 5681 5682 CHILLED WATER RETURN CHILLED WATER RETURN 3480-PRPF-001 HEATED PROCESS WATER 3380-TK-560 3380-TK-5603380-TK-550 CHILLED WATER TANK 3380-XM-550/560 3320-PRPF-001 3235 M CHILLED WATER SUPPLY 3320-PRPF-001 5690 3380-HX-540/541 S 2230-PRPF-001 HEATED PROCESS RECYCLE BRINE PROCESS RECYCLE BRINE 3360-PRPF-002 3380-HX-540/541 S 3650 5684 5670 DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 3 8 0 - P R P F - 0 0 1 - P R O C E S S C H I L L E D W A T E R S Y S T E M . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 7 / 2 0 2 3 1 2 : 2 5 : 1 5 P M SA V E D : 1 3 1214 - 3380 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE PROCESS COOLING CIRCUIT PROCESS FLOW DIAGRAM PEAK MINERALS INC. TIC . FROM PROCESS WATER TANK 3511-TK-700 FROM SOP CENTRIFUGE 3410-CF-503 FROM COMPACTOR 3420-CM-001 FROM SEAL WATER LOOP HEAT EXCHANGER 3511-HX-701 FROM CHILLED WATER RETURN PUMP 3320-PP-206 FROM PROCESS WATER TANK 3510-TK-700 FROM TAILINGS FILTRATE PUMP BOX 3360-TK-618 TO SCHOENITE LEACH BAROMETRIC CONDENSER 3340-HX-411/412 TO SEAL WATER LOOP HEAT EXCHANGER 3511-HX-701 TO SOP CENTRIFUGE 3410-CF-503 TO COMPACTOR 3420-CM-001 TO CONVERSION REACTOR BAROMETRIC CONDENSER 3320-HX-201/211 TO SOP CRYSTALLIZER 3350-CZ-503 TO SOP/MOP MIXING TANK 3480-TK-810 TO PROCESS RECYCLE BRINE BUFFER POND 2232-PD-210 PA 06 APR'23 YD AL JB MR INTERNAL REVIEW LIC . 3380-TK-550 5692 5694 5691 5693 WATER TREATMENT PACKAGE WATER TREATMENT PACKAGE HEATED PROCESS WATER 5696 TO PROCESS WATER TANK 3511-TK-700 NNF 3380-HX-571/572 S PACKAGE P-5015 5672 5675 3380-HX-531/532 S 3350-PRPF-001HOT SOP CENTRATE SOP CENTRATE 3410-PRPF-001 3522 5641 FROM SOP CENTRATE TANK 3410-TK-508 TO SOP CRYSTALLIZER 3350-CZ-5015643 5642 3380-HX-531/532 S PROCESS WATER HEAT EXCHANGER PROCESS RECYCLE BRINE HEAT EXCHANGER SOP CENTRATE HEAT EXCHANGER HEAT PUMP CONDENSER PUMP 3420-PRPF-001 TO COMPACTOR PADDLE MIXER 3420-MX-001 HEATED PROCESS WATER 5697 HEAT PUMP EVAPORATOR PUMP HEAT PUMP #1,2HEATED WATER EXPANSION TANK HEAT PUMP HEAT EXCHANGER 3380-XM-500 HEAT EXCHANGER ACID WASH MOBILE SKID 3510-PRPF-001 3380-HX-571/572 S 3380-XM-500 CONDENSER EVAPORATOR CONDENSER EVAPORATOR 3380-PP-580/581 S 3380-PP-580/581 S HEAT PUMP CONDENSER PUMP 5678 5665 5667 5674 5677 5666 TIC . 5695 3410-PRPF-001 TO SOP CENTRIFUGE 3410-CF-503 3561 3380-TK-580 3380-TK-590 HEATED PROCESS WATER 5698 3380-XM-580 CHILLED WATER TREATMENT PACKAGE 3380-XM-590 HOT WATER TREATMENT PACKAGE PB 19 MAY'23 CLIENT REVIEW 3410-PP-508 3410-TK-508 3410-PRPF-002SOP CAKE 3410-CF-503 3410-CY-503 3410-AG-508 3410-CV-503 3515 3513 3531 3480-PRPF-001 3380-PRPF-001 HEATED PROCESS WATER 3380-PRPF-001 CHILLED WATER SUPPLY 5681 3380-PRPF-001CHILLED WATER RETURN 3591 3566 3564 HYD 3521 3501 NNF DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 4 1 0 - P R P F - 0 0 1 - S O P S O L I D - L I Q U I D S E P A R A T I O N . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 7 / 2 0 2 3 1 2 : 2 6 : 1 4 P M SA V E D : 1 3 1214 - 3410 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE SOP SOLID LIQUID SEPARATION PROCESS FLOW DIAGRAM PEAK MINERALS INC. VSD LIC . 3350-PRPF-001 FROM MOP BRINE PUMP 3480-PP-812 FROM SOP CRYSTALLIZER PUMP 3350-PP-503 FROM PROCESS WATER HEAT EXCHANGER 3380-HX-560 FROM HEAT PUMPS #1, 2 3380-XM-550/560 TO CHILLED WATER TANK 3380-TK-550 TO SOP FLUID BED DRYER 3410-DY-001 NNF PA 06 APR'23 YD AL JB MR INTERNAL REVIEW 3565 3490-PRPF-001OFF-SPEC SOP CAKE TO OFF-SPEC PRODUCT PILE 3490-PD-0013581 3350-PRPF-001 FROM SOP CRYSTALLIZER PUMP 3350-PP-507 3380-PRPF-001SOP CENTRATE TO SOP CENTRATE HEAT EXCHANGER 3380-HX-531 M 3522 3410-CV-504 3410-CY-503 SOP SLURRY HYDROCYCLONE 3410-CV-503 SOP CENTRIFUGE SCREW CONVEYOR 3410-AG-508 SOP CENTRATE TANK AGITATOR 3410-CF-503 SOP CENTRIFUGE 3410-TK-508 SOP CENTRATE TANK 3410-PP-508 SOP CENTRATE RECYCLE PUMP 3410-CV-504 OFF-SPEC BELT CONVEYOR 3503 3505 3410-PD-001 3410-PD-001 OFF-SPEC PRODUCT PILE 3000-MB-001 BOO PACKAGE 3000-MB-001 FRONT-END LOADER SOP SLURRY THICKENER UNDERFLOW MOP/SOP BRINE 5698 3410-DT-503 3410-DT-503 OFF-SPEC DIVERTER PB 19 MAY'23 CLIENT REVIEW 3410-FN-002 3410-DY-001 3410-BU-001 3410-CV-001 3410-BE-001 3410-DT-001 3410-BU-001 3410-DY-001 FLUID BED DRYER 3410-BE-001 3410-MG-001 3410-CR-001 3410-SN-0013410-CV-001 4002 4101 4111 3420-PRPF-001 3410-PRPF-001 AIR PROPANE 3410-FN-002 3410-FN-003 3500-PRPF-001 3410-FN-001 PRODUCT SCREEN SOP CAKE GRANULAR SOP 3470-PRPF-001EXHAUST AIR / DUST 4090 3531 3410-HS-001 3410-HS-001 3500-PRPF-001 TO STORM WATER POND 3410-PP-001 3410-PP-001 AIR 3410-FN-001 AIR FROM ATMOSPHERE 3410-FN-003 4189 3460-PRPF-001 WATER SOLUBLE SOP 3410-SN-001 3410-CR-001 3410-MG-001 4186 3410-DT-001 4105 4147 4033 3470-PRPF-001 FINES 4141 STORM WATER/SPILLS AIR FILTER 5011 FROM ATMOSPHERE FROM ATMOSPHERE NOTES: 1.DRY PLANT INCLUDES 2% RECOVERABLE LOSSES INCORPORATED OUT OF THE DRYER. 2.DRY PLANT INCLUDES 0.5% UNRECOVERABLE LOSSES INCORPORATED OUT OF THE DRYER. 3.ALL STACKS FEATURE AIR EMISSION SAMPLING PORTS. DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 4 1 0 - P R P F - 0 0 2 - D R Y I N G . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 8 / 2 0 2 3 2 : 1 2 : 5 8 P M SA V E D : 1 3 1214 - 3410 - PRPF - 002 PB SEVIER PLAYA POTASH PROJECT FEED PHASE DRYING PROCESS FLOW DIAGRAM PEAK MINERALS INC. FROM COMPACTION BAGHOUSE BELT CONVEYOR 3470-CV-021 FROM SOP CENTRIFUGE SCREW CONVEYOR 3410-CV-503 FROM LPG TANK 3522-VE-010 TO COMPACTION BAGHOUSE 3470-BG-001 TO UNDERSIZE BELT CONVEYOR 3420-CV-301 TO WATER SOLUBLE SOP BELT CONVEYOR 3460-CV-601 PA 06 APR'23 YD AL JB MR INTERNAL REVIEW 3410-DT-002 3410-DT-002 NNF 3410-SM-001 3410-SM-001 PRODUCT SAMPLER DUST PICK-UP POINTS OV E R S I Z E ON S I Z E UN D E R S I Z E DRY AREA HOIST DRYING AREA SUMP PUMP FLUID BED DRYER AIR SUPPLY FAN FLUID BED DRYER COMBUSTION FAN FLUID BED DRYER COOLER FAN FLUID BED DRYER GAS BURNER DRY PRODUCT DRAG CONVEYOR OVERSIZE PRODUCT MAGNETIC CHUTE DRYER OVERSIZE ROLL CRUSHER SCREEN FEED BUCKET ELEVATOR SOLUBLE/GRANULAR PRODUCT DIVERTER SOLUBLE/GRANULAR PRODUCT DIVERTER 3410-BG-001 3410-RV-020 3410-FN-004 3410-CV-020 3410-XM-001 TO ATMOSPHERE NOTE 3 4784 4102 PLANT AIR 3570-VE-002 3500-PRPF-001 FROM DRY AIR RECEIVER 4041 PACKAGE P-5011 3410-BG-0013410-CV-020 3410-FN-004 3410-RV-020 3410-XM-001 MAIN DRYER BAGHOUSE SCREW CONVEYOR MAIN DRYER BAGHOUSE EXHAUST FAN MAIN DRYER BAGHOUSE MAIN DRYER BAGHOUSE ROTARY VALVE MAIN DRYER BAGHOUSE STACK PB 19 MAY'23 CLIENT REVIEW 3420-BE-101 4250 HEATED PROCESS WATER GRANULAR SOP 3420-CV-401 3420-BE-101 3420-CM-001 3420-MX-001 UNDERSIZE 3420-CR-002 3420-SN-010 3420-CV-003 3420-CV-002 3420-CV-001 3420-BE-201 3420-CV-005 3420-CV-301 3420-MG-101 3420-CV-101 3420-SI-101 3420-RV-101 3420-MG-101 COMPACTOR MAGNET 3420-CV-101 3420-MX-001 3420-CM-001 COMPACTOR 3420-CV-001/002 3420-CR-001 3420-CV-003 3420-BE-201 OVERSIZE GRANULAR SOP UN D E R S I Z E 3420-CV-401 3420-FN-001 AIR 3420-FN-001 3420-SN-010 COMPACTION SCREEN 3420-CV-301 3420-CR-002 3420-CV-005 3420-SI-101 3420-RV-101 5697 4317 4111 3430-PRPF-001 3410-PRPF-002 4232 4201 4210 4221 4225 4227 4231 4240 3430-PRPF-001 3420-CV-004 3420-CV-004 TO ATM. 3380-PRPF-001 FROM ATMOSPHERE 3420-FL-001 3420-FL-001 CURING AIR FILTER 3420-HS-001 3420-HS-001 COMPACTOR HOIST 3420-HS-0113420-HS-010 3420-HS-010 3420-HS-011 SCREEN HOIST 3420-PP-001 3420-PP-001 EXHAUST AIR / DUST CHILLED WATER SUPPLY 5682 3380-PRPF-001 CHILLED WATER RETURN 3380-PRPF-001 4282 3500-PRPF-001 3470-PRPF-001 4200 4290 4212 STORM WATER/SPILLS 4280 4233 NN F DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 4 2 0 - P R P F - 0 0 1 - C O M P A C T I O N . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 9 : 2 8 : 2 2 A M SA V E D : 1 3 1214 - 3420 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE COMPACTION PROCESS FLOW DIAGRAM PEAK MINERALS INC. 3430-PRPF-001 FROM PROCESS WATER HEAT EXCHANGER 3380-HX-560 FROM HEAT PUMP 3380-XM-550/560 FROM GLAZING SCREEN 3430-SN-101 FROM SOLUBLE/GRANULAR PRODUCT DIVERTER 3410-DT-002 TO COMPACTION BAGHOUSE 3470-BG-001 TO CHILLED WATER TANK 3380-TK-550 TO GLAZING DRUM 3430-CD-001 TO PROCESS WATER CONTROL VALVE PA 06 APR'23 YD AL JB MR INTERNAL REVIEW NNF OVERSIZE PRODUCT 3430-PRPF-001 FROM GLAZING SCREEN OVERSIZE BELT CONVEYOR 3430-CV-004 4316 DUST PICK-UP POINTS ONSIZE TO STORM WATER POND 3420-CR-001 COMPACTION FEED BUCKET ELEVATOR CURING CONVEYOR AIR BLOWER COMPACTION FEED DRAG CONVEYOR BUCKET ELEVATOR FEED DRAG CONVEYOR COMPACTOR PADDLE MIXER CURING DRAG CONVEYORS 1,2 COMPACTION FLAKE BREAKER GRANULAR PRODUCT BELT CONVEYOR BUCKET ELEVATOR FEED BELT CONVEYOR COMPACTION DOUBLE ROLL CRUSHER SCREEN FEED BUCKET ELEVATOR COMPACTION SUMP PUMP UNDERSIZE BELT CONVEYOR ROLL CRUSHER BELT CONVEYOR #1 COMPACTION SURGE BIN ROTARY VALVE COMPACTION SURGE BIN COMPACTOR ROLL CRUSHER HOIST PB 19 MAY'23 CLIENT REVIEW 3420-PD-0013420-CV-009 3000-MB-001 3420-CV-009 MOBILE CONVEYOR 3420-PD-001 OFF-SPEC PILE 3000-MB-001 ROLL CRUSHER BELT CONVEYOR #1 3510-PRPF-001 PROCESS WATER 3430-FN-001 5143 FROM ATMOSPHERE AIR PROPANE 3430-DY-0013430-BU-001 3430-CV-002 OVERSIZE UN D E R S I Z E ONSIZE3430-SN-101 FROM ATMOSPHERE AIR 3430-FN-002 3430-CD-001 3430-FN-003 3430-BE-101 3430-CV-001 3430-FN-002 3430-CV-0013430-CD-001 3430-DY-0013430-BU-001 3430-CV-002 3430-BE-101 3430-SN-101 4250 4310 3420-PRPF-001 4350 4315 4317 4301 3500-PRPF-001 3420-PRPF-001 4011 GRANULAR SOP UNDERSIZE 3522-VE-010 PACKAGE P-5011 GRANULAR PRODUCT 3440-PRPF-001 3500-PRPF-001 TO STORM WATER POND 3430-PP-001 3430-PP-001 FILTERED AIR 3430-FN-001 3430-FN-003 NNF 4390 5010 STORM WATER/SPILLS FROM ATMOSPHERE DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 4 3 0 - P R P F - 0 0 1 - P O S T - C O M P A C T I O N . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 7 / 2 0 2 3 1 2 : 2 8 : 5 4 P M SA V E D : 1 3 1214 - 3430 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE POST-COMPACTION PROCESS FLOW DIAGRAM PEAK MINERALS INC. 3420-PRPF-001 FROM GRANULAR PRODUCT BELT CONVEYOR WEIGH SCALE FROM PROCESS WATER TANK 3510-TK-700 FROM GRANULAR PRODUCT BELT CONVEYOR 3420-CV-004 TO LOADOUT FEED BELT CONVEYOR 3440-CV-101 TO UNDERSIZE BELT CONVEYOR 3420-CV-301 FROM LPG TANK PA 06 APR'23 YD AL JB MR INTERNAL REVIEW 4316 OVERSIZE PRODUCT 3420-PRPF-001 TO COMPACTION DOUBLE ROLL CRUSHER 3420-CR-002 GRANULATION SUMP PUMP GRANULAR PRODUCT GLAZING SCREEN GLAZED PRODUCT BUCKET ELEVATOR GLAZED PRODUCT DRAG CONVEYOR GLAZING DRYER GAS BURNER GLAZING FLUID BED DRYER/COOLER GLAZING DRYER FEED BELT CONVEYOR GLAZING DRUMGLAZING DRYER COOLER FAN GLAZING DRYER COMBUSTION FAN GLAZING DRYER AIR SUPPLY FAN FROM ATMOSPHERE AIR 3430-FN-005 3430-CV-003 3430-CV-003 GLAZING SCREEN OVERSIZE BELT CONVEYOR 3430-FN-005 GLAZING DRYER FLUIDIZING FAN 3430-CV-020 3430-FN-004 3430-BG-001 3430-RV-020 4783 3430-XM-001 TO ATMOSPHERE NOTE 1 3500-PRPF-001 PLANT AIR 4042FROM DRY AIR RECIEVER 3570-VE-002 3430-RV-020 3430-FN-004 3430-CV-020 3430-XM-0013430-BG-001 GLAZING DRYER/COOLER BAGHOUSE GLAZING BAGHOUSE ROTARY VALVE GLAZING BAGHOUSE EXHAUST FAN GLAZING BAGHOUSE SCREW CONVEYOR GLAZING BAGHOUSE STACK NOTE 1.ALL STACKS FEATURE AIR EMISSION SAMPLING PORTS. PB 19 MAY'23 CLIENT REVIEW EXHAUST AIR / DUST 3470-PRPF-001 4399 TO COMPACTION BAGHOUSE 3470-BG-001 DUST PICK-UP POINTS GRANULAR PRODUCT 3440-SI-001 3440-SC-001 3440-BG-001 3440-RC-002 3440-CC-002 3440-SM-001 GRANULAR PRODUCT 3440-SM-001 SAMPLING STATION 3440-BG-001 3440-SI-001 LOADOUT SILO 3440-CC-001/002 3440-RC-001/002 3440-SC-0013440-CV-101 4420 4350 3430-PRPF-001 4411 4401 4414 3440-PP-003 3440-PP-003 3500-PRPF-001 TO STORM WATER POND4490 NNF STORM WATER/SPILLS 3440-FN-001 TO ATM. (SAFE LOCATION) 3440-FN-001 DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 4 4 0 - P R P F - 0 0 1 - L O A D O U T . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 9 : 3 0 : 4 6 A M SA V E D : 1 3 1214 - 3440 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE LOADOUT PROCESS FLOW DIAGRAM PEAK MINERALS INC. FROM GRANULAR PRODUCT GLAZING SCREEN 3430-SN-101 PA 06 APR'23 YD AL JB MR INTERNAL REVIEW NOTE: 1.0.5% TRANSPORT AND LOGISTIC LOSSES ARE INCLUDED IN TRUCK HAULAGE THROUGHPUT. 5100-PRPF-001 TO ATM. (SAFE LOCATION) 3440-RC-001 3440-CC-001 TO SOP DISCHARGE HOPPER 5100-HP-101 3440-CV-101 LOADOUT SILO BAGHOUSE LOADOUT SILO BAGHOUSE FAN LOADOUT SILO DUST FILTER CYCLONE LOADOUT SILO RETRACTABLE CHUTES LOADOUT FEED BELT CONVEYOR LOADOUT SILO TRUCK SCALE LOADOUT AREA SUMP PUMP 3400-MB-0013400-MB-002 BOO PACKAGE 3400-MB-001 SOP/MOP HAUL TRACK 3400-MB-002 TANDEM TRAILERS PB 19 MAY'23 CLIENT REVIEW 3460-CV-601 EMPTY BAGS/PALLETS 3460-CV-601 3460-BE-602 3460-CV-606 WATER SOLUBLE SOP 3410-PRPF-002 NOTES: BAGGING PLANT INCLUDES: -NET SCALER UNIT/MEASURING HOPPER; -UNROLLING UNIT; -AUTOMATIC BAG PLACER; -AUTOMATIC BAG FILLING; -AUTOMATIC BAG SEALING; -AUTOMATIC BAG LIFTING; -AUTOMATIC LABEL PRINTING. PACKAGE P-5045 FROM STORAGE 3460-BF-605 4189 3460-BE-602 3460-SI-6053460-RV-605 3460-BF-605 BAG FILLING STATION 3460-CV-605 4601 IN T E R M I T T E N T 3460-BG-605 3460-BG-605 3460-CV-605 3460-CV-606 BAGGING PLANT BUFFER SILO VENT FILTER TO ATM. (SAFE LOCATION) DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 4 6 0 - P R P F - 0 0 1 - B A G G I N G P L A N T . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 9 / 2 0 2 3 9 : 3 9 : 5 2 A M SA V E D : 1 3 1214 - 3460 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE BAGGING PLANT PROCESS FLOW DIAGRAM PEAK MINERALS INC. PA 06 APR'23 YD AL JB MR INTERNAL REVIEW 3460-SM-601 3460-SM-601 TO RAIL LOADOUT AREA 5300-PRPF-001 4603 FROM SOLUBLE/GRANULAR PRODUCT DIVERTER 3410-DT-002 WATER SOLUBLE SOP BELT CONVEYOR SAMPLING STATION WATER SOLUBLE SOP BUCKET ELEVATOR BUFFER SILO ROTARY VALVE BAGGING PLANT BUFFER SILO (100 st) 3460-CV-603 3460-CV-603 BAGGING SILO FEED CONVEYOR 3460-SI-605 3460-RV-605 BAGGING PLANT TRANSFER CONVEYOR BAGGING PLANT ACCUMULATING CONVEYOR BAGGED SOLUBLE SOP 3400-MB-0013400-MB-004 BOO PACKAGE 3400-MB-003 3400-MB-004 ZOOM BOOM 3400-MB-001 HAUL TRUCK CABS 3400-MB-003 HAUL TRUCK TRAILERS PB 19 MAY'23 CLIENT REVIEW COMPACTION BAGHOUSE 3470-RV-020 3470-FN-003 FROM DUST PICKUP POINTS 4033 3470-BG-001 3470-FN-003 3470-BG-001 3470-RV-020 PLANT AIR 3570-VE-002 3470-XM-001 3470-XM-001 3500-PRPF-001 FINES 4090 TO ATMOSPHERE 3410-PRPF-002 3410-PRPF-002 PACKAGE P-5012 EXHAUST AIR/DUST 3470-CV-022 3470-CV-021 3470-CV-021 FROM DUST PICKUP POINTS 3420-PRPF-001 EXHAUST AIR/DUST 4200 FROM DRY AIR RECEIVER CONVEYOR 3410-CV-001 TO DRY PRODUCT DRAG 4785 NOTE 1 DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 4 7 0 - P R P F - 0 0 1 - D U S T C O L L E C T I O N . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 9 / 2 0 2 3 9 : 3 6 : 0 7 A M SA V E D : 1 3 1214 - 3470 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE DUST COLLECTION PROCESS FLOW DIAGRAM PEAK MINERALS INC. PA 06 APR'23 YD AL JB MR INTERNAL REVIEW 3470-CV-022 NOTE 1.ALL STACKS FEATURE AIR EMISSION SAMPLING PORTS. COMPACTION BAGHOUSE STACK COMPACTION BAGHOUSE ROTARY VALVE COMPACTION BAGHOUSE BELT CONVEYOR COMPACTION BAGHOUSE SCREW CONVEYOR COMPACTION BAGHOUSE EXHAUST FAN PB 19 MAY'23 CLIENT REVIEW FROM DUST PICKUP POINTS 3430-PRPF-001 EXHAUST AIR/DUST 4399 4040 3350-PRPF-001 3380-PRPF-001 HEATED PROCESS WATER 5669 3480-CV-801 3480-HP-801 3480-SI-804 3480-TK-810 3480-AG-810 3480-CV-803 3480-PP-812 3480-HP-801 3480-CV-801 3480-BE-802 3480-BE-802 3480-SI-804 3480-TK-810 3480-AG-810 3480-PP-812 MOP BRINE PUMP 8706 3870 MOP/SOP BRINE 3480-BG-804 3480-CV-802 3480-BG-8043480-CV-802 3480-CV-803 MOP BRINE OIL SEPARATOR 3480-FL-811 3480-FL-811 3490-PRPF-001 3968 3860 3480-PP-811 3480-PP-811 OIL REMOVAL PUMP 3480-PP-980 3500-PRPF-001 TO STORM WATER POND STORM WATER/SPILLS 3880 3480-PP-980 PACKAGE P-5060 MOP SILO NNFOFF-SPEC PRODUCT OIL3869 DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 4 8 0 - P R P F - 0 0 1 - M O P A D D I T I O N . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 9 / 2 0 2 3 9 : 1 9 : 5 4 A M SA V E D : 1 3 1214 - 3480 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE MOP ADDITION PROCESS FLOW DIAGRAM PEAK MINERALS INC. VSD M LIC . FROM OFF-SPEC PRODUCT DRAG CONVEYOR 3490-CV-901 TO SOP CRYSTALLIZER 3350-CZ-503 FROM PROCESS WATER HEAT EXCHANGER 3380-HX-560 PA 06 APR'23 YD AL JB MR INTERNAL REVIEW INTERMITTENT 3490-PRPF-001 FROM OFF-SPEC SCREW CONVEYOR 3490-CV-901 WIT . NNF 3480-PP-813 SLUDGE3868 3480-PP-813 SLUDGE REMOVAL PUMP TO ATM. FROM DUST PICK-UP POINTS DUMPSTER 3892 PACKAGE P-5012 TO ATMOSPHERE 3480-XM-820 3480-RV-820 3480-CV-820 3480-BG-820 3480-FN-820 3480-BG-820 3480-CV-820 3480-FN-820 3480-XM-820 MOP BAGHOUSE BLOWER 3480-RV-820 MOP FEED HOPPER MOP FEED CONVEYOR MOP BUCKET ELEVATOR MOP BELT FEEDER MOP SILO VENT FILTER SOP/MOP MIXING TANK SOP/MOP MIXING TANK AGITATOR MOP BRINE COALESCING FILTER MOP DRAG CONVEYOR MOP ADDITION AREA SUMP PUMP BAGHOUSE SCREW CONVEYOR MOP ADDITION AREA BAGHOUSE MOP AREA STACK BAGHOUSE FINES ROTARY VALVE 3410-PRPF-001MOP/SOP BRINE TO SOP CENTRATE TANK 3410-TK-508 3504 3505 5400-PRPF-001 FROM SOP/MOP HAUL TRUCKS 3400-MB-001 NNF PB 19 MAY'23 CLIENT REVIEW NOTE 1 NOTE 1.DRYER RECOVERABLE LOSSES TAKEN INTO ACCOUNT IN THIS STREAM. 3480-HS-802 3480-HS-802 BUCKET ELEVATOR HOIST 3310-PRPF-001MOP/SOP BRINE TO CRUSHING HAMMER MILL TANK 3310-TK-102 NNF 3899 3480-PRPF-001 3480-TK-810 TO SOP/MOP MIXING TANK 3490-CV-901 3490-HP-901 3490-HP-901 3490-CV-901 3968 NNF OFF-SPEC PRODUCT DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 4 9 0 - P R P F - 0 0 1 - O F F - S P E C R E T U R N . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 9 : 4 1 : 4 9 A M SA V E D : 1 3 1214 - 3490 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE OFF-SPEC RETURN PROCESS FLOW DIAGRAM PEAK MINERALS INC. PA 06 APR'23 YD AL JB MR INTERNAL REVIEW 8207 5200-PRPF-001 FINES 8711 5400-PRPF-002 FROM RAIL FACILITY MOP DUST COLLECTION AREA NNF FROM RAIL LOADOUT SCREENING AREA OFF-SPEC PRODUCT WIT .3480-PRPF-001 TO HEATED PROCESS WATER CONTROL VALVE 3410-PRPF-001 FROM OFF-SPEC PRODUCT PILE 3410-PD-001 OFF-SPEC SOP CAKE 3581 OFF-SPEC PRODUCT DRAG CONVEYOR OFF-SPEC PRODUCT HOPPER 3490-PD-001 OFF-SPEC PRODUCT PILE 3490-PD-001 3000-MB-001 3000-MB-001 FRONT-END LOADER PB 19 MAY'23 CLIENT REVIEW DIESEL TO ATMOSPHERE 3521-TK-001/002 3521-PP-001 3521-TK-001/002 DIESEL TANK 3521-PP-001 DIESEL TANK PUMP 3521-FS-001/002 3521-FS-001/002 FUEL DISPENSER PUMP 3522-VE-010 3522-VE-010 LPG TANK PROPANE DIESEL 3592-XM-001 3592-XM-001 5011 5002 5003 PROPANE 3570-CP-001 3570-CP-002 3570-VE-001 INSTRUMENT AIR PLANT AIR TO HEADER TO HEADER 5701 5702 3570-FL-002 3570-DY-002 3592-PP-001/011 FROM BUILDINGS SANITARY WATER REJECT STREAM TO OFF SITE WASTE TREATMENT 3512-XM-020 POTABLE WATER TO USERS 3512-PP-910 3512-TK-025 3512-PP-025/026 S PROCESS WATER RE J E C T PACKAGE P-5051 5195 5008 STORM WATER 3570-VE-001 WET AIR RECEIVER 3570-CP-001/002 AIR COMPRESSOR 3570-FL-002 PRE-FILTER 3592-PP-001/011 3570-DY-002 DESICCANT AIR DRYER 3512-XM-020 3512-TK-025 3512-PP-025/026 S 3512-PP-910 5005 5004 5007 3510-PRPF-001 3592-PP-002 FROM WAREHOUSE BUILDING SANITARY WATER 5006 3592-PP-002 5009 3410-PRPF-002 5010 PROPANE 3430-PRPF-001 OVERFLOW TO ENVIRONMENT 5700 5015 5016 5017 DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 5 0 0 - P R P F - 0 0 1 - U T I L I T I E S . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 9 : 4 3 : 2 2 A M SA V E D : 1 3 1214 - 3500 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE UTILITIES AND SERVICES PROCESS FLOW DIAGRAM PEAK MINERALS INC. FROM PLANT SUMP PUMPS FROM PROCESS WATER TANK 3510-TK-700 TO GLAZING DRYER BURNER 3430-BU-001 TO MAIN DRYER BURNER 3410-BU-001 PA 07 APR'23 YD AL JB MR INTERNAL REVIEW PACKAGE P-5024 ST R E A M 5012 3570-VE-002 3570-VE-002 DRY AIR RECEIVER 5021 SANITARY WATER LIFT PUMP RAIN WATER SUMP PUMP SANITARY WATER TREATMENT SYSTEM POTABLE WATER TREATMENT SYSTEM POTABLE WATER HOLDING TANK POTABLE WATER DISTRIBUTION PUMP WATER TREATMENT SYSTEM SUMP PUMP 3593-PD-001 STORM WATER POND 3593-PD-001 FROM MARKET FROM MARKET 3509 DIESEL TO USERS SOLID WASTE 0000-MB-002 3521-GE-001 3521-GE-001 DIESEL GENERATOR 0000-MB-002 FUEL TANKER TRUCK STORM WATER / SPILLS FROM STORM WATER RECOVERY CIRCUIT 3570-DY-003 3570-DY-003 DESICCANT AIR DRYER PB 19 MAY'23 CLIENT REVIEW 3511-TK-700 PROCESS WATER TANK 3511-PP-700/701 S PROCESS WATER PUMP 3511-PP-700/701 S PROCESS WATER RAW WATER 3511-TK-700 5001 5111 5134 PROCESS WATER PROCESS WATER 5133 5135 3340-PRPF-001 3330-PRPF-002 3380-PRPF-001 MAKE-UP WATER 5193 3380-PRPF-001 TO PROCESS COOLING CIRCUIT AREA PROCESS WATER 5005 3500-PRPF-001 PROCESS WATER 5143 3430-PRPF-001 TO GLAZING DRUM 3430-CD-001 INTERMITTENT 5103 3514-PP-720 3514-PP-730 3514-PP-740 FIRE WATER TO FIRE WATER LOOP 3514-PP-720 3514-PP-730 3514-PP-740 3511-PP-704/705 S FLUSHING 3511-PP-704/705 S FLUSHING PUMP PROCESS WATER 5107 3360-PRPF-002 5104 5120 MAKE-UP SEAL WATER TO SEAL WATER TANK 3511-TK-710 3510-PRPF-002 4100-PRPF-001 DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 5 1 0 - P R P F - 0 0 1 - P R O C E S S W A T E R . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 7 / 2 0 2 3 1 1 : 4 2 : 4 6 A M SA V E D : 1 3 1214 - 3510 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE PROCESS WATER PROCESS FLOW DIAGRAM PEAK MINERALS INC. FROM RAW WATER PUMPS 4100-PP-001/002 TO TAILINGS SLURRY BELT FILTER 3360-FL-620 TO WATER TREATMENT SYSTEM 3512-XM-020 TO SCHOENITE LEACH AREA TO COLLECTOR MIXING TANK 3330-TK-362/363 TO CHILLED WATER TANK 3380-TK-550 3511-PP-750 3511-PP-750 PROCESS WATER 5132 3320-PRPF-001 TO CONVERSION AREA PA 07 APR'23 YD AL JB MR INTERNAL REVIEW FLUSH WATER TO POND SYSTEM5114 HEATED PROCESS WATER 5696 3380-PRPF-001 FROM PROCESS WATER HEAT EXCHANGER 3380-HX-560 WATER TRUCK FILLING PUMP FIRE WATER PUMP FIRE WATER DIESEL PUMP FIRE WATER JOCKEY PUMP 0000-MB-003 0000-MB-003 WATER TANKER TRUCK NNF NNF NNF NNF TO USERS PB 19 MAY'23 CLIENT REVIEW 3511-PP-710/711 S CHILLED WATER RETURN SEAL WATER RETURN 3511-TK-710 SEAL WATER SEPARATION AREA 3380-PRPF-001 CHILLED WATER SUPPLY 3380-PRPF-001 3511-HX-701 5120 5106 5683 5123 5105 SEAL WATER RETURN 3403FROM SCHOENITE LEACH AREA 3340-PRPF-001 3360-PRPF-002 3340-PRPF-001 5101 3360-PRPF-002 5121 5127 TO AGITATOR SEALS 3511-TK-710 SEAL WATER TANK 3511-PP-710/711 S 3511-HX-701 MAKE-UP SEAL WATER 3510-PRPF-001 FROM PROCESS WATER TANK 3510-TK-700 SEAL WATER SEAL WATER DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 3 5 1 0 - P R P F - 0 0 2 - S E A L W A T E R . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 9 : 4 5 : 5 7 A M SA V E D : 1 3 1214 - 3510 - PRPF - 002 PB SEVIER PLAYA POTASH PROJECT FEED PHASE SEAL WATER PROCESS FLOW DIAGRAM PEAK MINERALS INC. LIC . TIC .TO SCHOENITE LEACH AREA PA 07 APR'23 YD AL JB MR INTERNAL REVIEW TO TAILINGS SOLID/LIQUID 5124 TO PUMP SEALS SEAL WATER SEAL WATER RETURN 5126FROM PLANT AGITATORS SEAL WATER RETURN 5125FROM PLANT PUMPS FROM HEAT PUMP #1,2 3380-XM-550/560 FROM TAILINGS SOLID/LIQUID SEPARATION AREA VACUUM SEAL WATER PUMP SEAL WATER LOOP HEAT EXCHANGER TO CHILLED WATER TANK 3380-TK-550 PB 19 MAY'23 CLIENT REVIEW TO PROCESS WATER 3510-PRPF-001 TANK 3510-TK-700 RAW WATER 4100-PP-001/002 RAW WATER PUMP 4100-PP-001/002 5001 DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 4 1 0 0 - P R P F - 0 0 1 - W A T E R W E L L S . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 9 : 4 9 : 2 9 A M SA V E D : 1 3 1214 - 4100 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE RAW WATER SUPPLY PROCESS FLOW DIAGRAM PEAK MINERALS INC. PA 07 APR'23 YD AL JB MR INTERNAL REVIEW 4100-PD-001 RAW WATER WELLS 4100-PD-001 PB 19 MAY'23 CLIENT REVIEW NOT FOR CONSTRUCTION TO ATM.TO ATM. 8103 8104 8101 NOT FOR CONSTRUCTION DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 5 1 0 0 - P R P F - 0 0 1 - R A I L L O A D I N G D O M E S T O R A G E . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 9 : 5 0 : 3 4 A M SA V E D : 1 3 1214 - 5100 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE RAIL LOAD OUT FACILITY - SOP STORAGE PROCESS FLOW DIAGRAM PEAK MINERALS INC. GRANULAR PRODUCT 4420 3440-PRPF-001 5200-PRPF-001 ELEVATOR 5200-BE-201 TO SCREENING BUCKET8110 GRANULAR SOP PLANT AIR 8402 5500-PRPF-001 5200-PRPF-001FINES 5100-HP-101 SOP DISCHARGE HOPPER 5100-CV-102 SOP TRANSFER BELT CONVEYOR 5100-HP-101 5100-CV-102 5100-BE-101 5100-CV-103 5100-BE-101 SOP STORAGE BUILDING BUCKET ELEVATOR 5100-CV-103 SOP STORAGE BELT TRIPPER CONVEYOR 5100-CV-101 5100-CV-101 SOP DISCHARGE BELT CONVEYOR 5100-DM-101 5100-BG-101 5100-FN-101 5100-DM-101 SOP STORAGE BUILDING 5100-BG-101 SOP STORAGE BUILDING BAGHOUSE 5100-FN-101 BAGHOUSE EXHAUST FAN 5100-CV-105 5100-CV-105 SOP STORAGE RECLAIM CONVEYOR 8108 8109 5100-DM-102 5100-BG-102 5100-FN-102 5100-CV-106 5100-CV-107 5100-DM-102 SOP STORAGE BUILDING 5100-BG-102 SOP STORAGE BUILDING BAGHOUSE 5100-FN-102 BAGHOUSE EXHAUST FAN 5100-RC-101 SOP STORAGE BUILDING RETRACTABLE CHUTE 5100-CV-107 SCREENING FEED BELT CONVEYOR 8105 8106 5100-CV-106 SOP STORAGE RECLAIM CONVEYOR PA 07 APR'23 YD AL JB MR INTERNAL REVIEW 8111 PACKAGE T-4005 DUST PICK-UP POINTS TO SCREENING BAGHOUSE 5200-BG-207 FROM DRY AIR RECEIVER 5500-VE-403 FROM LOADOUT SILO TRUCK SCALE 3440-SC-001 5100-RC-101 8102 5100-RC-102 5100-RC-102 SOP STORAGE BUILDING RETRACTABLE CHUTE DEFERRED CAPITAL PB 19 MAY'23 CLIENT REVIEW 5200-CR-201 OVERSIZE ROLL CRUSHER 5200-BE-201 SCREENING BUCKET ELEVATOR DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 5 2 0 0 - P R P F - 0 0 1 - R A I L L O A D I N G S C R E E N I N G . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 9 : 5 1 : 3 6 A M SA V E D : 1 3 1214 - 5200 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE RAIL FACILITY - SCREENING PROCESS FLOW DIAGRAM PEAK MINERALS INC. TO OFF-SPEC PRODUCT PILE 3490-PD-001 OFF-SPEC PRODUCT 8207 FROM SCREENING FEED BELT CONVEYOR 5100-CV-107 GRANULAR SOP FROM DUST PICK-UP POINTS ONSIZE OVERSIZE 8201 8203 8204 8202 8205 DUMPSTER PLANT AIR 8403 5500-PRPF-001 8209 PACKAGE P-5012 5100-PRPF-001 TO LOADOUT FEED BUCKET ELEVATOR 5300-BE-202 GRANULAR SOP 8208 5300-PRPF-001 FROM DRY AIR RECEIVER 5500-VE-403 5200-CR-201 5200-CV-201 5200-BE-201 5200-CV-202 5200-CV-201 SCREEN OVERSIZE BELT CONVEYOR 5200-CV-202 SCREEN FEED BELT CONVEYOR 5200-SN-201 5200-CV-204 5200-SN-201 LOADING SCREEN 8206 5200-RV-207 5200-CV-207 5200-BG-207 5200-FN-207 5200-RV-207 BAGHOUSE FINES ROTARY VALVE 5200-CV-207 BAGHOUSE FINES SCREW CONVEYOR 5200-BG-207 SCREENING BAGHOUSE 5200-FN-207 BAGHOUSE FAN 8110 8212 8211 PA 07 APR'23 VB AL JB MR INTERNAL REVIEW 5200-CV-203 SCREEN UNDERSIZE BELT CONVEYOR 3490-PRPF-001 FINES 8111 5100-PRPF-001 FROM SOP STORAGE BUILDINGS DUST PICK-UP POINTS 5200-MG-201 5200-MG-201 LOADING SCREEN MAGNET UN D E R S I Z E 5200-CV-203 5200-CV-204 SCREEN ONSIZE BELT CONVEYOR 5200-XM-207 TO ATM 5200-XM-207 SCREENING BAGHOUSE STACK 3400-MB-0015000-MB-002 3400-MB-003 5000-MB-002 ZOOM BOOM 3400-MB-001 HAUL TRUCK CABS 3400-MB-003 HAUL TRUCK TRAILERS PB 19 MAY'23 CLIENT REVIEW NNF 5200-PRPF-001 8208 GRANULAR SOP GRANULAR SOP PRODUCT TO DISTRIBUTION DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 5 3 0 0 - P R P F - 0 0 1 - R A I L C A R L O A D I N G . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 9 : 5 3 : 0 2 A M SA V E D : 1 3 1214 - 5300 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE RAIL FACILITY - LOADOUT PROCESS FLOW DIAGRAM PEAK MINERALS INC. 5300-BE-202 LOADOUT FEED BUCKET ELEVATOR FROM SCREEN ONSIZE BELT CONVEYOR 5200-CV-204 5300-CV-206 5300-SI-201 LOADOUT SILO 5300-BE-202 5300-CV-206 LOADOUT FEED BELT CONVEYOR 5300-SI-201 5300-CC-201/202/203 LOADOUT SILO MULTI-CYCLONE DUST COLLECTOR 1/2/3 5300-CC-201/202/203 5300-FD-201 LOADOUT SILO WEIGH FEEDER 5300-FD-201 5300-RC-201/202/203 LOADOUT SILO RETRACTABLE CHUTE 1/2/3 5300-RC-201/202/203 5300-BG-201 8221 RAILCAR 8223 8222 5300-BG-201 LOADOUT SILO VENT FILTER PA 07 APR'23 YD AL JB MR INTERNAL REVIEW 3460-PRPF-001 FROM SOP FLAT BED TRUCKS 3400-MB-001/003 WATER SOLUBLE SOP BAGS TO DISTRIBUTION 4603 RAILCAR 8227 WIT . 5300-PP-001 5300-TK-001 8232 8233 5300-TK-001 5300-PP-001 ANTI DUSTING REAGENT TANK ANTI DUSTING REAGENT METERING PUMP TO ATM. WATER SOLUBLE SOP IN BAGS NOTES: 1.RAILCARS OUT OF SCOPE. NOTE 1 NOTE 1 5000-MB-002 5000-MB-002 ZOOM BOOM 8231 ANTI-DUSTING REAGENT FROM MARKET INTERMITENT PB 19 MAY'23 CLIENT REVIEW TO ATM. (SAFE LOCATION) 8703 8704 8707 8705 NOT FOR CONSTRUCTIONNOT FOR CONSTRUCTION DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 5 4 0 0 - P R P F - 0 0 1 - M O P R A I L U N L O A D I N G . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 9 : 5 4 : 0 5 A M SA V E D : 1 3 1214 - 5400 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE RAIL FACILITY - MOP UNLOADING AND STORAGE PROCESS FLOW DIAGRAM PEAK MINERALS INC. 3480-PRPF-001 8706 MOP PLANT AIR 8405 5500-PRPF-001 5400-PRPF-002 BAGHOUSE 5400-BG-703 TO MOP HANDLING FINES 5400-CV-701 5400-CV-701 MOP UNLOADING MOBILE CONVEYOR 8701 5400-BE-701 5400-BE-701 MOP STORAGE BUILDING FEED BUCKET ELEVATOR 5400-CV-703 5400-DM-701 5400-FN-701 5400-BG-701 5400-CV-703 MOP STORAGE BUILDING FEED BELT TRIPPER CONVEYOR 5400-DM-701 MOP STORAGE BUILDING 5400-BG-701 MOP STORAGE BUILDING BAGHOUSE 5400-FN-701 MOP STORAGE BUILDING EXHAUST FAN 5400-BE-702 5400-CV-704 MOP STORAGE RECLAIM CONVEYOR 5400-BE-702 MOP BUCKET ELEVATOR 5400-RC-702 5400-RC-703 5400-SI-702 5400-BG-702 5400-FN-702 5400-BG-702 MOP LOADING BAGHOUSE 5400-FN-702 MOP LOADING EXHAUST FAN 5400-SI-702 MOP LOADING SILO 5400-RC-702/703 MOP LOADING RETRACTABLE CHUTE 8708 TO ATM. (SAFE LOCATION) 5400-CC-702 5400-CC-703 RAILCAR 5400-CC-702/703 MOP LOADING DUST FILTER CYCLONE NOTE 1 8702 PA 07 APR'23 YD AL JB MR INTERNAL REVIEW MOP FROM MARKET 5400-HP-701 5400-CV-704 5400-HP-701 MOP LOADING HOPPER 5400-CV-704 MOP LOADING BELT CONVEYOR 8709 5400-SC-001 5400-SC-001 PRODUCT WEIGH SCALE PACKAGE T-4005 NOTE 1.PRODUCT WEIGH SCALE TO BE SHARED WITH THE SOP TRUCKS. 2.RAILCARS OUT OF SCOPE. AIR AIR FROM DUST PICK-UP POINTS FROM DRY AIR RECEIVER 5500-VE-403 TO MOP FEED HOPPER 3480-HP-801 NOTE 2 5000-MB-001 3400-MB-0013400-MB-002 3400-MB-001 SOP/MOP HAUL TRACK 3400-MB-002 TANDEM TRAILERS 5000-MB-001 FRONT-END LOADER PB 19 MAY'23 CLIENT REVIEW DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 5 4 0 0 - P R P F - 0 0 2 - R A I L L O A D I N G D U S T C O L L E C T I O N . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 9 : 5 5 : 1 0 A M SA V E D : 1 3 1214 - 5400 - PRPF - 002 PB SEVIER PLAYA POTASH PROJECT FEED PHASE RAIL FACILITY - MOP DUST COLLECTION PROCESS FLOW DIAGRAM PEAK MINERALS INC. 8710 PACKAGE P-5012 PLANT AIR 5500-PRPF-001 DUMPSTER FROM DRY AIR RECEIVER 5500-VE-403 FINES TO OFF-SPEC PRODUCT PILE 3490-PD-001 8406 FROM MOP STORAGE DUST PICK-UP POINTS 5400-PRPF-001 5400-BG-703 MOP HANDLING BAGHOUSE 5400-CV-705 MOP BAGHOUSE SCREW CONVEYOR 5400-RV-701 MOP SCREW CONVEYOR ROTARY VALVE 5400-FN-703 EXHAUST FAN 5400-BG-703 5400-FN-703 5400-CV-705 5400-RV-701 8711 8709 3490-PRPF-001 PA 07 APR'23 YD AL JB MR INTERNAL REVIEW FINES 5400-XM-703 TO ATM 5400-XM-703 HANDLING BAGHOUSE STACK 3400-MB-0015000-MB-002 3400-MB-003 5000-MB-002 ZOOM BOOM 3400-MB-001 HAUL TRUCK CABS 3400-MB-003 HAUL TRUCK TRAILERS PB 19 MAY'23 CLIENT REVIEW PLANT AIR 8408 FIRE WATER PACKAGE P-5051 8421 DIESEL 8407 AIR FILTER AIR N.N.F. NOT FOR CONSTRUCTION TO USERS DRAWING NO. REFERENCE DRAWINGS APPROVALS 1 2 3 4 5 6 REVISION INFORMATION PROJECT AREA SUBJECT NUMBER REV 87 9 10 11 PA T H : : CLIENT: FRAME: ANSI D C 0 4 INCHES REVISION BY CHECKED ENG. MAN.PROJ.MAN.DATE SCALE : DRAWING TITLE. A P: \ 1 2 1 4 - P E A K F E E D \ C A D \ P R \ P F _ P R O C E S S F L O W \ 1 2 1 4 - 5 5 0 0 - P R P F - 0 0 1 - R A I L L O A D I N G U T I L I T I E S . D W G B C D E F CLIENT THIS DOCUMENT HAS BEEN PREPARED BY NOVOPRO PROJECT Inc. AS PART OF ITS MANDATE FOR SEVIER PLAYA POTASH PROJECT. ANY UNAUTHORIZED REPRODUCTION OF THIS DOCUMENT IN WHOLE OR IN PART IS STRICTLY PROHIBITED. 5/ 1 1 / 2 0 2 3 1 0 : 0 0 : 2 7 A M SA V E D : 1 3 1214 - 5500 - PRPF - 001 PB SEVIER PLAYA POTASH PROJECT FEED PHASE RAIL FACILITY - UTILITIES PROCESS FLOW DIAGRAM PEAK MINERALS INC. 8416 DIESEL 8409 PROCESS WATER TO USERS 8402 TO SOP BAGHOUSES 8403 TO SCREENING TOWER BAGHOUSE 5200-BG-207 8405 TO MOP UNLOADING AND STORAGE AREA BAGHOUSES 5550-DY-402 5550-CP-401 5550-FL-4015550-VE-402 5550-FL-401 5550-VE-402 5550-CP-401 AIR COMPRESSOR PRE-FILTER DESICCANT AIR DRYER WET AIR RECEIVER 5510-TK-401 5513-PP-401 5510-TK-401 PROCESS WATER TANK 5513-PP-402 5513-PP-403 5511-PP-404/405 S 5513-PP-401 5513-PP-402 FIREWATER PUMP FIREWATER DIESEL PUMP 5513-PP-403 5511-PP-404/405 S FIREWATER JOCKEY PUMP PROCESS WATER PUMP 5521-TK-404 5521-PP-407 5521-TK-4045521-PP-407 DIESEL TANKDIESEL PUMP 5100-PRPF-001 5200-PRPF-001 540-PRPF-001 8406 TO HANDLING BAGHOUSE 5400-BG-703 5400-PRPF-002 PLANT AIR PLANT AIR PLANT AIR TO USERS INSTRUMENT AIR INTERMITTENT 5550-DY-402 5550-FL-403 5550-FL-403 POST FILTER 8401 PA 07 APR'23 YD AL JB MR INTERNAL REVIEW WATER 5550-VE-403 5550-VE-403 DRY AIR RECEIVER 5521-FS-001 8415 5521-FS-001 RAIL LOADOUT FUEL DISPENSER POWER GENERATOR EMERGENCY POWER TO ATMOSPHERE FROM MUNICIPALITY WATER LINE FROM MARKET 5521-GE-001 5521-GE-001 DIESEL GENERATOR PB 19 MAY'23 CLIENT REVIEW APPENDIX G EPA 1998 DETERMINATION OF NON-APPLICABILITY OF POTASH PROCESSING OPERATIONS TO 40 CFR 60 SUBPARTS OOO AND UUU